UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15 (d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended December 31, 2001
Registrant, State of Incorporation, Address of Commission File Principal Executive Offices and Telephone I.R.S. employer State of Number Number Identification Number Incorporation 1-8788 SIERRA PACIFIC RESOURCES 88-0198358 Nevada P.O. Box 10100 (6100 Neil Road) Reno, Nevada 89520-0400 (89511) (775) 834-4011 1-4698 NEVADA POWER COMPANY 88-0045330 Nevada 6226 West Sahara Avenue Las Vegas, Nevada 89146 (702) 367-5000 0-508 SIERRA PACIFIC POWER COMPANY 88-0044418 Nevada P.O. Box 10100 (6100 Neil Road) Reno, Nevada 89520-0400 (89511) (775) 834-4011 (Title of each class) (Name of exchange on which registered) Securities registered pursuant to Section 12(b) of the Act: Securities of Sierra Pacific Resources: -------------------------------------- Common Stock, $1.00 par value New York Stock Exchange Common Stock Purchase Rights New York Stock Exchange Securities of Nevada Power Company and subsidiaries: ---------------------------------------------------- 8.2% Cumulative Quarterly Income New York Stock Exchange Preferred Securities, Series A, issued by NVP Capital I 7 3/4% Cumulative Quarterly Trust Issued New York Stock Exchange Preferred Securities, issued by NVP Capital III Securities registered pursuant to Section 12(g) of the Act: Securities of Sierra Pacific Power Company: ------------------------------------------ Class A Preferred Stock, Series I, $25 stated value |
Indicate by check mark whether registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
State the aggregate market value of the voting stock held by non-affiliates. As of March 15, 2002: $ 1,665,622,642
Indicate the number of shares outstanding of each of the issuer's classes of
Common Stock, as of the latest practicable date.
Common Stock, $1.00 par value, of Sierra Pacific Resources Outstanding at
March 15, 2002: 102,110,536 Shares
Sierra Pacific Resources is the sole holder of the 1,000 shares of outstanding
Common Stock, $1.00 stated value, of Nevada Power Company.
Sierra Pacific Resources is the sole holder of the 1,000 shares of outstanding
Common Stock, $3.75 par value, of Sierra Pacific Power Company.
DOCUMENTS INCORPORATED BY REFERENCE:
Portions of Sierra Pacific Resources' definitive proxy statement to be filed in connection with the annual meeting of shareholders, to be held May 6, 2002, are incorporated by reference into Part III hereof.
SIERRA PACIFIC RESOURCES
ANNUAL REPORT ON FORM 10-K
CONTENTS
PART I ...................................................................................................... 3 Item 1. Business .......................................................................................... 3 Sierra Pacific Resources .... ............................................................................ 3 Nevada Power Company ........ ............................................................................ 5 Sierra Pacific Power Company ............................................................................. 14 Item 2. Properties ........................................................................................ 32 Item 3. Legal Proceedings ................................................................................. 33 Item 4. Submission Of Matters To A Vote Of Security Holders ............................................... 33 PART II ..................................................................................................... 34 Item 5. Market For The Registrant's Common Stock And Related Stockholder Matters .......................... 34 Item 6. Selected Financial Data ........................................................................... 36 Item 7. Management's Discussion And Analysis Of Financial Condition And Results Of Operations ............. 38 Sierra Pacific Resources ................................................................................. 43 Nevada Power Company ..................................................................................... 50 Sierra Pacific Power Company ............................................................................. 57 Item 7A. Quantitative and Qualitative Disclosures About Market Risk ...................................... 79 Item 8. Financial Statements and Supplementary Data ....................................................... 82 Notes to Financial Statements ............................................................................ 100 Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure .............. 148 PART III .................................................................................................... 149 Item 10. Directors and Executive Officers of the Registrant .............................................. 149 Item 11. Executive compensation .......................................................................... 155 Item 12. Security Ownership of Certain Beneficial Owners and Management .................................. 161 Item 13. Certain Relationships and Related Transactions .................................................. 162 PART IV ..................................................................................................... 166 Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K ................................. 166 Signatures .................................................................................................. 168 |
FORWARD LOOKING STATEMENTS
The discussion of forward looking statements in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operation, is incorporated herein by reference.
PART I
Item 1. BUSINESS
Sierra Pacific Resources, hereafter known as SPR, was incorporated under Nevada law on December 12, 1983. SPR's mailing address is P.O. Box 30150 (6100 Neil Road), Reno, Nevada 89520-3150 (89511).
SPR has eight primary, wholly owned subsidiaries: Nevada Power Company (NPC), Sierra Pacific Power Company (SPPC), Tuscarora Gas Pipeline Company (TGPC), Sierra Pacific Communications (SPC), Sierra Energy Company, dba e. three (e. three), Sierra Pacific Energy Company (SPE), Lands of Sierra (LOS) and Nevada Electric Investment Company (NEICO). NPC and SPPC are referred to together in this report as the "Utilities".
AN EXPLANATION OF THE REPORTING FORMAT
The merger between SPR and NPC on July 28, 1999 was treated for accounting purposes as a reverse acquisition and deemed to have occurred on August 1, 1999. As a result, for financial reporting and accounting purposes, NPC was considered the acquiring entity under Accounting Principles Board Opinion No. 16, Business Combinations, even though SPR became the legal parent of NPC. Because of this accounting treatment, the financial information for the year ended December 31, 1999 reflects the acquisition of SPR by NPC on August 1, 1999. Therefore, the results of operations for that year reflect twelve months of information for NPC and five months of information for SPR and its pre-merger subsidiaries. This presentation is carried forward to the notes to the financial statements.
The discussion in this report has been divided wherever possible to highlight the activities of the major subsidiaries of SPR. Parenthetical references are included after each major section title to identify the specific entity addressed in the section. References to SPR refer to the consolidated entity, except for the section related to debt financing in which SPR debt is discussed separately from that of its subsidiaries.
Electric Utility Trends
The year 2001 was challenging and unpredictable for the electric utility industry, marked by volatile and uncharacteristic power prices, deterioration in the credit quality of a number of utilities and power merchants, bankruptcy of a major California utility and a major Houston based energy trading company, and increased involvement and oversight by government and regulators.
Dramatic increases in wholesale power prices that began in 2000 continued into the first half of 2001, particularly in the West. Rolling blackouts occurred in California. Wholesale energy prices in the West peaked in the spring at levels up to four times what they were in the prior year. While continuing blackouts and high power prices were predicted in the second half of the year, they did not materialize. Instead, power prices moderated largely because of mild weather across the United States, lower natural gas prices, conservation in California, and the imposition by the FERC of federal price caps in California and eleven western states,
including Nevada (see Regulation and Rate Proceedings, FERC Matters in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations). Remaining as a result of this energy price volatility is a long list of policy, regulatory, business and financial issues, many of which are being addressed at both state and federal levels.
California continues to influence the region. In California, continued high prices during the first half of the year and the lack of adequate rate relief led to an inability to purchase energy, and credit problems and defaults for the state's three largest utilities. In April 2001, Pacific Gas & Electric Company filed for bankruptcy. The State of California took on the role of energy buyer through its Department of Water Resources and funded billions of dollars for short and long-term energy purchases which it plans to fund through the issuance of bonds. While California's regulatory and policy issues are specific to California, the state's problems exacerbated western energy problems and left a mark throughout the region as western states continue to struggle with the question of who should pay large fuel and purchased power balances.
Like other utilities in the West, the Utilities, which operate principally in Nevada, have been significantly impacted by increased wholesale prices. High fuel and power costs have led to large financing requirements, liquidity constraints and depressed earnings. In Nevada, emergency legislation, Assembly Bill (AB) 369, was enacted in April 2001 to control volatility in the price of retail electricity in Nevada and to ensure the Utilities the financial resources to provide adequate and reliable electric service. To achieve these purposes, AB 369 allows the Utilities to recover in future periods their costs for wholesale power and fuel, subject to regulatory review for prudency. NPC filed for recovery of deferred energy balances on December 1, 2001 and SPPC filed for recovery of deferred energy balances on February 1, 2002. The businesses of SPR, NPC, and SPPC are substantially dependent upon the outcomes of these proceedings. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for further legislative and regulatory discussions. Also in December, the Utilities filed an action under Section 206 of the Federal Power Act seeking a rollback of wholesale power prices and refunds.
High energy prices, power shortages, and a push at state and federal levels for increased supply resulted in an unprecedented number of new power plant project announcements nationally and in Nevada - mostly unregulated and mostly natural gas-fired. Some power plants have been built or are under construction. NPC is constructing transmission facilities to interconnect new merchant plants being built in southern Nevada (see Nevada Power Company, Transmission, for a discussion of the Centennial Plan). Towards year-end, a weakening economy, lower demand, and a decline in energy prices have caused power plant builders to reconsider planned projects. Some have announced downsizings or cancellations. In addition, falling energy prices and pressure from the major credit rating agencies have caused the announcement of a number of asset sales.
In Nevada, the Utilities' divestiture of generation assets, which the PUCN had previously ordered, was halted by the provisions of AB 369 that prohibit the sale of generation assets until July 2003. Additionally, in April 2001, SPR and Enron Corporation (Enron) mutually agreed to the termination of their agreement for SPR's purchase of Enron's wholly owned subsidiary, Portland General Electric (PGE), headquartered in Portland, Oregon.
National energy policy is also undergoing change due to the events of 2000 and 2001. The President's National Energy Policy Report was issued in May 2001. Recently, Senate Bill (SB) 517 addressed the Public Utility Holding Company Act (PUHCA) repeal and the Public Utility Regulatory Policies Act (PURPA) reform, some FERC provisions, reliability, utility mergers, open access transmission, net metering and interconnection. Senate action on the bill is pending.
Regulation and Electric Restructuring
The transition to retail competition continues to be highly uncertain, driven by the development of a relatively young wholesale market and the different approaches to retail competition taken by state regulators and legislators. Rising wholesale prices, the western energy crisis, and the recent bankruptcy filings of Pacific Gas & Electric Company and Enron have led many states to review or revise restructuring plans.
While deregulation has been suspended in some states, in other states, the process has slowed. In Nevada, AB 369, which became law in April 2001, repealed all statutes authorizing retail competition in Nevada's electric utility industry and voided any license issued to alternative sellers in connection with retail competition. AB 661, passed in July 2001, enables large customers with demand of one megawatt (MW) or more to choose a new energy supplier beginning mid-2002 with permission from the PUCN upon meeting public interest tests.
Remaining committed to regional transmission organization development and power competition, FERC plans to propose electric market design rules and issue a final ruling by year-end 2002. Also, FERC recently approved the nation's first regional transmission organization in the Midwest.
NPC is a Nevada corporation organized in 1921. NPC became a wholly owned subsidiary of SPR on July 28, 1999. Its mailing address is 6226 West Sahara Avenue, Las Vegas, Nevada 89146.
NPC is a public utility engaged in the distribution, transmission, generation, purchase and sale of electric energy in Clark County in southern Nevada. It provides electricity to approximately 639,000 customers in the communities of Las Vegas, North Las Vegas, Henderson, Searchlight, Laughlin and adjoining areas. Service is also provided to Nellis Air Force Base and the Department of Energy at Mercury and Jackass Flats at the Nevada Test Site.
Business and Competitive Environment
NPC's electric business contributed 100% of its 2001 operating revenues of $3.025 billion. The system has an annual load factor of approximately 49.0%, which is slightly lower than the industry norm of 50% to 55%.
Summer peak loads are driven by air conditioning demand. NPC's peak load increased an average of 5.8% annually over the past five years, reaching 4,412 MW on July 2, 2001. NPC's total electric megawatt-hour (MWh) sales have increased an average of 5.8% annually over the past five years. Winter peak loads are low relative to the summer peak. Winter load above the base amount is driven by air handling in forced air furnaces.
NPC's service territory continues to be one of the fastest growing areas in the nation. A significant part of the growth in NPC's electric sales has resulted from new residential, industrial, and gaming customers.
NPC's electric customers by class contributed the following toward 2001 and 2000 MWh sales:
MWh Sales (Billed and Unbilled) 2001 2000 ------------------------ ------------------------- Residential 7,208,540 25.5% 7,035,488 36.2% Office 1,986,752 7.1% 1,896,111 9.7% Gaming/Recreation/Restaurants 3,903,478 13.8% 3,963,286 20.4% Wholesale 11,051,000 39.1% 2,675,484 13.8% Other Retail 825,882 2.9% 783,467 4.0% All Other & Unclassified 3,276,724 11.6% 3,101,564 15.9% ----------- ------ ------------ ------ TOTAL 28,252,376 100.0% 19,455,400 100.0% =========== ====== ============ ====== |
Tourism and gaming remain southern Nevada's premier industries. Over 35 million tourists visited Las Vegas in 2001, infusing approximately $19.8 billion into the local economy during the year. Currently, Las Vegas is the home of 18 of the world's 20 largest hotels. No mega-resort properties are scheduled to open during 2002. Hotel room growth is expected to be just 0.8% during 2002.
The Las Vegas Convention Center has recently completed a $150 million expansion project, adding 918,000 square feet of exhibit space and 90,000 square feet of meeting space. The Las Vegas Convention Center now has more than 3.2 million square feet of total space, and features approximately 2 million square feet of net exhibit space, and 380,000 square feet of net meeting room space, accommodating 170 meeting rooms with seating capacities from 20 to 7,500. In 2001, more than 4.0 million convention and trade show delegates traveled to Las Vegas, generating more than $4.8 billion in non-gaming revenue.
Shortly after the terrorist attacks of September 11, 2001, an estimated 12,000-15,000 gaming industry employees were laid off due to an expected decrease in tourism revenue. In October 2001, many of these employees were recalled, although some of them only on a part-time or on-call basis. Although tourist traffic is not back to its previous levels, an upward trend has been realized since early October 2001.
During 2001, firm and non-firm sales to wholesale customers comprised 39.1% of total energy sales, an increase of 310.0% over the prior year. Wholesale customers consist of other utilities or municipalities that sell power to end users, marketing entities and others that exchange power with NPC.
Wholesale MWh Sales 2001 2000 ----------------------- --------------------- Firm Sales 159,707 1.45% 283,480 10.52% Non-Firm Sales 10,891,293 98.55% 2,412,442 89.48% ---------- ------ --------- ------ Total 11,051,000 100.00% 2,695,922 100.00% ========== ====== ========= ====== |
NPC's increase in wholesale MWh sales from last year was a result of market conditions and NPC's power procurement activities. See Purchased Power Procurement in Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of the Utilities' purchased power procurement strategies.
Construction Program
NPC's construction program and estimated expenditures are subject to continuing review, and are revised from time to time due to various factors, including the rate of load growth, escalation of construction
costs, availability of fuel types, the number and status of proposed independent generation projects, the need for additional transmission capacity in southern Nevada, changes in environmental regulations, adequacy of rate relief, and NPC's ability to raise necessary capital.
Gross construction expenditures for 2001, including allowance for funds used during construction (AFUDC) and contributions in aid of construction, were 200.9 million, and for the period 1997 through 2001, were $1,155.6 million. Estimated construction expenditures for 2002 and the period from 2003 to 2006 are as follows (dollars in thousands):
2002 2003-2006 Total 5-Year ------------- ---------------- ----------------- Total construction expenditures $ 328,435 $ 862,661 1,191,096 AFUDC (8,699) (20,813) (29,512) Net salvage, including cost of removal (1,034) (4,140) (5,174) Net customer advances and contributions in aid of construction (7,602) (30,408) (38,010) ------------- -------------- ------------- Total cash requirements $ 311,100 $ 807,300 1,118,400 ============= ============== ============= |
Total construction expenditures estimated for 2002 and the 2003-2006 period consist of the following (dollars in thousands):
Total 2002 2003-2006 5-Year ----------------------------------------------- Electric Facilities: Distribution $128,436 $543,543 $ 671,979 Generation 26,027 53,392 79,419 Transmission 156,220 225,575 381,795 Other 17,752 40,151 57,903 --------------------------------------------- $328,435 $862,661 $1,191,096 ============================================= |
The River Mountain Project is a 230kV (kilovolt) joint transmission project with the Colorado River Commission. Total project costs incurred through December 31, 2001, were approximately $34.0 million. Actual costs for 2001 were $7.7 million. This project was completed in 2001 and was in service in June of 2001.
The Centennial Plan was approved in NPC's 2001 Refiled Resource Plan. This plan, consistent with its tariff and FERC pricing policies, involves the following 500 kV lines (1) the Harry Allen substation to Crystal substation 500 kV lines, (2) the Harry Allen substation to Northwest substation 500 kV line, and (3) the Harry Allen substation to Mead substation 500 kV line. Additional facilities include a new 500 kV substation at Harry Allen, 500/230 kV transformer at Mead and Northwest substation, phase shifting transformer at Crystal substation, and several other sub-transmission upgrades and additions. Total estimated cost of the project is $296.2 million. Total project actual costs incurred through December 31, 2001, were $20.1 million. Estimated costs for 2002 are $131.1 million, which may be financed utilizing internally generated cash and/or the proceeds from various forms of debt. See Transmission, later, for additional information about the Centennial Plan.
Facilities and Operations
Total System
NPC maintains a wide variety of resources in its generation system. The availability of alternate resources allows NPC to dispatch its electric generation system in a more cost-effective manner under varying operating and fuel market conditions, while maintaining system integrity. NPC also supplies its customers' electric power needs using a combination of firm and interruptible resources to maximize operating flexibility, while minimizing cost. During 2001, NPC generated 33.9% of its total electric energy requirements in its own plants, purchasing the remaining 66.1% as shown below:
Megawatt- Percent Hours of Total ----------------- --------------- NPC Company Generation ---------------------- Gas/Oil 4,206,728 14.4% Coal 5,692,467 19.5% ----------------- --------------- Total Generated 9,899,195 33.9% ----------------- --------------- Purchased Power --------------- Hydro 544,772 1.9% Non-Firm Purchases 274,278 0.9% Short Term Firm and Spot Purchases 16,058,378 55.1% Non-Utility Purchases 2,390,877 8.2% ----------------- --------------- Total Purchased 19,268,305 66.1% ----------------- --------------- Total 29,167,500 100.0% ================= =============== |
NPC's decision to purchase short-term and spot energy in lieu of its own generation is based on the economics of purchasing "as-available" energy when it is less expensive than its own generation.
NPC's 2001 company generation of 9,899,195 MWh is down 7.9% from NPC's 2000 company generation of 10,744,466 MWh due to decreased generation late in 2001 when the cost of purchased power was more economical than generation. NPC's 2001 purchased power of 19,268,305 MWh is up 99.5% from NPC's 2000 purchased power of 9,659,118 MWh.
Risk Management
See Item 7A, Quantitative and Qualitative Disclosures About Market Risk.
Load and Resources Forecast
NPC's electric customer growth rate was 4.5% in 2001, 5.1% in 2000, and 5.9% in 1999. Retail electricity sales were 17.2 million MWh in 2001, which represents an increase of 2.4% over 2000 retail electricity sales of 16.8 million MWh. Wholesale electricity sales reached 11.1 million MWh in 2001, which represents an increase of 313% over 2000 wholesale electricity sales of 2.7 million MWh. Overall, annual system electricity sales reached 28.3 million MWh in 2001, which represents an increase of 45% over 2000 system electricity sales of 19.5 million MWh. The bulk of the 45% increase is attributed to wholesale sales. Changes in the wholesale market have dramatically increased the amount of purchases and sales of wholesale
power. See Purchased Power Procurement in Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of the Utilities' purchased power procurement strategies. NPC's peak electric demand rose to 4,412 MW in 2001 from 4,325 MW in 2000.
The forecasted peak energy demand for 2002 and 2003 below reflects, among others, five key assumptions:
. Southern Nevada experiences normal weather conditions, based on historical 20-year averages.
. No adjustments have been made to incorporate the potential loss of customers leaving for alternative providers under the provisions of AB 661 or Senate Bill 211, which allows the Colorado River Commission to sell electricity to its purveyors of water for water pumping electric-related loads only. However, four large commercial customers of NPC have filed an application under the provisions of AB 661 to procure energy from an alternative source other than the Utility and one large commercial customer has filed a letter of intent to file an application to procure energy from an alternative source. The combined peak load of AB 661 notice of intent customers and SB 211 eligible customers is less than 10% of NPC's retail load.
. Retail electric rates are set at the levels requested in NPC's most recent general and deferred energy rate case filings.
. The southern Nevada economy recovers from the effects of the September 11, 2001, terrorist attacks by the fourth quarter of 2002.
. Concerns over power outages in California subside by summer 2002 resulting in reduced conservation efforts by NPC's customers.
Sales and peak energy demand will vary from forecasted levels to the extent that actual experience varies from the above assumptions and to the extent that other factors affect sales and demand.
NPC's actual total system capability and peak loads for 2001, and as estimated for summer peak demand for 2002 and 2003 are shown below:
Capacity at 2001 Peak Forecast Summer Peak (2) ------------------------------------------------------------------ MW % 2002 2003 ------------------------------------------------------------------ NPC Company Generation: Existing 1,559 32% 1,937 1,937 ------------------------------------------------------------------ Purchases Long/Short-Term Firm (1) 2,492 51% 2,022 1,572 Non-Utility Generators (2) 504 10% 515 515 Wholesale (3) (107) (2%) (114) (119) ------------------------------------------------------------------ Subtotal 2,889 59% 2,423 1,968 ------------------------------------------------------------------ Additional Required (4) 449 9% 889 1,557 Total System Capacity 4,897 100% 5,249 5,462 ================================================================== Net System Peak (5) 4,412 90% 4,687 4,877 Planning Reserves 485 10% 562 585 ------------------------------------------------------------------ Total Requirement 4,897 100% 5,249 5,462 ================================================================== Growth over previous year 7.2% 4.1% |
(1) Long-term purchases include NPC's allotment of Hoover Dam energy. Values
are net of losses.
(2) Includes Sunpeak units.
(3) On peak wholesale commitment to Silver State Power Pool (SSPP). Generation
and purchases are reduced by the amount of load serving SSPP to show
remaining resources to meet the system peak.
(4) Includes potential short-term firm purchases that are not under contract.
Values shown represent purchases within existing transmission system
limits.
(5) The system peak shown for 2001 is the actual system peak of 4,412 MW, which
occurred on July 2, 2001.
NPC plans its system capacity needs in accordance with the Western Systems Coordinating Council (WSCC) reliability criteria, which recommends planning reserves in excess of required operating reserves. "Additional Required" represents the additional, uncommitted capacity needed in order to maintain adequate reserve margin consistent with the WSCC planning reserve criteria. These additional reserves will be met, if needed, with short-term purchases through 2003 to the extent available.
Generation
The following is a list of NPC's share of generation plants (except Reid Gardner No. 4, see note (2) below), including the MW summer net capacity, the type and fuel used to generate, and the year(s) that the unit(s) was (were) installed.
Number of MW Name Type Fuel Units Capacity Years(s) Installed ----------------------------------------------------------------------------------------------------------- Clark Station Steam Gas/Oil 3 175 1955, 1957, 1961 Combustion Turbine Gas/Oil 1 50 1973 Combined Cycles (1) Gas/Oil 6 462 1979, 1979, 1980, 1982, 1993, 1994 ----------------------- Total Clark Station 10 687 Reid Gardner (2) Steam Coal 4 605 1965, 1968, 1976, 1983 Navajo (3) Steam Coal 3 255 1974 Mohave (4) Steam Coal 2 196 1971 Sunrise Steam Gas/Oil 1 80 1964 Combustion Turbine Gas/Oil 1 69 1974 ----------------------- Total Sunrise 2 149 ----------------------- Harry Allen Combustion Turbine Gas/Oil 1 72 1995 ----------------------- Grand Total NPC 22 1964 ======================= |
(1) The combined cycles at Clark Station each consist of one steam turbine and two combustion turbines for a total of six generating units.
(2) Reid Gardner Unit No. 4 is jointly owned by the California Department of Water Resources ("CDWR") (67.8%) and NPC (32.2%). NPC is the operating agent. Contractually, NPC is entitled to receive 24 MW of base load capacity and 226 MW of peaking capacity. NPC is entitled to use 100% of the unit's peaking capacity for 1,500 hours each year and is entitled to 9.6% of the first 250 MW of capacity and associated energy.
(3) This represents NPC's 11.3% undivided interest in the Navajo Generating Station as tenant in common without right of partition with five other non-affiliated utilities.
(4) This represents NPC's 14% undivided interest in the Mohave Generating Station as tenant in common without right of partition with three other non-affiliated utilities, less operating restrictions.
Purchased Power
NPC utilizes and maintains a diverse portfolio of resources with the objective of minimizing its net average system operating costs while providing reliable service. This portfolio consists of contracted and spot market supplies, as well as its own generation. During the past several years, including the first half of 2001, NPC experienced a dramatic increase in the market price of energy. Some of this increase reflects an overall increase in electricity costs throughout the country, the changing of regulatory environments, and the opening of new and/or deregulated markets. However, costs for contracted and spot market energy supplies fell dramatically in the second half of 2001 and limited NPC's ability to mitigate previous purchase power costs by selling any short-term excess energy because it limited the price at which NPC could sell surplus energy during market shortages. Some of NPC's purchased power contracts are also at price levels above which NPC is permitted to recover in current rates. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, for a discussion of deferred energy accounting and legislation.
NPC is a member of the Western Systems Power Pool and the Southwest Reserve Sharing Group (SRSG). NPC's membership in the SRSG has allowed it to network with other utilities in an effort to use its resources more efficiently in the sharing of responsibilities for reserves.
NPC purchases both forward firm energy (typically in blocks) and spot market energy based on economics, operating reserve margins and unit availability. NPC seeks to manage its growing loads efficiently by utilizing its generation resources in conjunction with buying and selling opportunities in the market.
NPC purchases Hoover Dam power pursuant to a contract with the State of Nevada which became effective June 1, 1987, and will continue through September 30, 2017. NPC's allocation of hydro-electric capacity is 235 MW.
NPC has a contract to purchase 222 MW from Nevada Sunpeak Limited Partnership, an independent power producer. The contract became effective June 8, 1991 and will continue through May 31, 2016.
According to the regulations of the PURPA, NPC is obligated, under certain conditions, to purchase the generation produced by small power producers and cogeneration facilities at costs determined by the appropriate state utility commission. Generation facilities that meet the specifications of the regulations are known as qualifying facilities (QFs). As of December 31, 2001, NPC had a total of 305 MW of contractual firm capacity under contract with four QFs. All QF contracts currently delivering power to NPC at long-term rates have been approved by the PUCN and have QF status as approved by the FERC. The QFs are as follows:
Net Qualifying Facility Contract Contract Capacity Start End (MW) ----------------------------------------------------------------- Saguaro Power Company 10/17/91 04/30/22 90 Nevada Cogeneration Associates #1 06/18/92 04/30/23 85 Nevada Cogeneration Associates #2 02/01/93 04/30/23 85 Las Vegas Cogeneration Limited Partnership 05/10/94 05/31/24 45 ------------ Total 305 ============ |
Energy purchased by NPC from the QFs constituted 29.1% of the net purchased power requirements (excluding wholesale purchases), and 13.2% of the net system requirements during 2001. All of the QFs are cogenerators providing steam for various products and businesses.
Transmission
NPC's existing transmission lines are primarily confined within Clark County, Nevada. Four 230kV transmission lines connect NPC to the Western Area Power Administration's transmission facilities at Henderson and Mead Substations. Three 230 kV lines connect NPC to the Los Angeles Department of Water and Power's transmission facilities at McCullough Substation. A 345 kV line connects NPC to PacifiCorp at the Utah-Nevada state line. Also, NPC has two 500/230 kV transformers that connect NPC to the Navajo Transmission System at the Crystal Substation. Finally, NPC also has ownership rights in two 500 kV transmission lines that allow for the transmittal of NPC's share of power from its interests in the Mohave and Navajo Generating Stations to NPC's systems.
The River Mountain Project is a transmission project developed in partnership with the Colorado River Commission of Nevada that was placed in service in June 2001. NPC's portion of the project consists of two 230 kV transmission lines built along separate transmission corridors between the Mead Substation and NPC's new Equestrian Substation. In addition, to facilitate the ability to deliver power scheduled between Mead Substation and Equestrian Substation, NPC built a 230 kV transmission line between the Equestrian Substation and the Faulkner Substation. The project increased import capability by 350 MW. The completed project costs were approximately $34.0 million.
NPC received approval from the PUCN to construct two transmission projects proposed in NPC's 2001 Refiled Resource Plan. The Faulkner Substation to Tolson Substation 230 kV project and the Tolson Substation to Arden Substation 230 kV upgrade project are both internal, NPC reinforcements with 2003 and 2004 in-service dates, respectively. Due to independent power producer (IPP) transmission service requests, the Arden-Tolson 230 kV upgrade project will be advanced one year for an in-service date of June 2003. The Faulkner-Tolson 230 kV project will increase NPC's import capability by 300 MW. The total estimated project costs are $8.29 million.
Due to the supply shortage in the western United States, several IPP's have proposed the construction of new generating plants in southern Nevada, and have requested transmission service from NPC. NPC has committed to construct this transmission infrastructure in furtherance of its on-going business plan. NPC has proposed the Centennial Plan to address transmission service requests from these IPP's. The Centennial Plan was approved in NPC's 2001 Refiled Resource Plan. This plan, consistent with its tariff and FERC pricing policies, involves the following lines (1) the Harry Allen substation to Crystal substation 500 kV line, (2) the Harry Allen substation to Northwest substation 500 kV line, (3) the Harry Allen substation to Mead substation 500 kV line and (4) Two Bighorn-Arden 230 kV lines. Additional facilities include a new 500 kV substation at Harry Allen, 500/230 kV transformers at Mead and Northwest substation, a phase shifting transformer at Crystal substation, and several other sub-transmission upgrades and additions.
See Regulation and Rate Proceedings, FERC Matters in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for a discussion of regional transmission issues.
Fuel Availability
NPC's 2001 fuel requirements for electric generation were provided by natural gas, coal and oil. The average costs of coal, gas and oil for energy generation per million British thermal units (MMBtu) for the years 1997 - 2001, along with the percentage contribution to total fuel requirements were as follows:
Average Consumption Cost & Percentage Contribution to Total Fuel Requirements
Gas Coal Oil --- ---- --- $/MMBtu Percent $/MMBtu Percent $/MMBtu Percent ------- ------- ------- ------- ------- ------- 2001 5.34 42.6% 1.26 57.3% 7.14 0.1% 2000 4.93 42.6% 1.22 57.2% 7.33 0.1% 1999 2.27 40.6% 1.15 59.3% 4.01 0.1% 1998 2.35 33.0% 1.39 67.0% 3.96 * 1997 2.25 33.0% 1.39 67.0% 3.35 * |
For a discussion of the change in fuel costs, see Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Coal delivered to the Reid Gardner Station originates from various mines in the Utah coalfields and is delivered to the station via the Union Pacific Railroad. Partial requirements for coal supplies are under contract for various terms up to 2007, with the remainder of 2001's requirements purchased from the spot market under four one-year contracts. NPC's long-term coal supply agreement with RAG Coal Sales of America, Inc. is supplied from its Willow Creek Mine in Carbon County, Utah, which experienced an explosion and fire on July 31, 2000, and is currently under an ongoing force majeure. No deliveries under this agreement were scheduled for 2001 and NPC replaced these volumes with spot market purchases.
The mine remains sealed and NPC does not anticipate that deliveries will resume before the contract terminates.
The Union Pacific Rail Transportation contract provides for deliveries from the Provo, Utah interchange as well as various mines in the Price, Utah area to the Reid Gardner Station in Moapa, Nevada. This contract was effective January 1, 1996 and has been extended through December 31, 2004. The Utah Railway contract originates the remainder of NPC's Price, Utah area supplies. This contract has been extended through December 31, 2002. All of NPC's rail transportation contracts contain certain tonnage requirements and railroad service criteria.
Coal for both the Mohave and Navajo Stations is obtained from surface mining operations conducted by Peabody Coal Company on portions of the Black Mesa in Arizona within the Navajo and Hopi Indian reservations. The supply contracts with Peabody extend to December 31, 2005 for Mohave and to June 1, 2011 for Navajo, each contract having an option to extend for an additional 15 years.
NPC purchases natural gas on a firm, fixed and indexed price basis from the Rocky Mountain, San Juan or Permian Supply Basins.
Natural gas is transported to the Clark and Sunrise stations via El Paso Natural Gas Company from the San Juan and Permian Basins and by Kern River Gas Transmission Company from the Rocky Mountain Basin. NPC has entered into a summer seasonal transportation contract for 50,000 decatherms (Dth)/day and an annual contract for 75,000 Dth/day of Kern River Pipeline capacity. This service is scheduled for delivery in May 2003 and will run for a period of 15 years. NPC also responded to an open season for shorter term service in the Kern River California Emergency Expansion and was awarded 29,600 Dth/day for the period July 2001 to April 2002 and 5,600 Dth/day for the period May 2002 to April 2003. The Emergency Expansion service does not carry any renewal rights.
Local natural gas transportation service to Clark and Sunrise Stations is provided under a 32-year transportation services contract with Southwest Gas Company signed in 1995. This contact provides firm service and contains certain operating and nominating provisions. The Harry Allen Station is directly connected to Kern River Pipeline.
Oil provides a secondary fuel for Clark, Sunrise and Harry Allen Stations and is used in the igniters at Reid Gardner.
Regulation and Rate Proceedings
See Regulation and Rate Proceedings in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
SPPC is a Nevada corporation organized in 1965 as a successor to a Maine corporation organized in 1912. SPPC became a wholly owned subsidiary of Sierra Pacific Resources on May 31, 1984. Its mailing address is Post Office Box 10100 (6100 Neil Road), Reno, Nevada 89520-0024.
SPPC is a public utility primarily engaged in the distribution, transmission, generation, purchase and sale of electric energy. It provides electricity to approximately 315,000 customers in a 50,000 square mile service area in western, central and northeastern Nevada, including the cities of Reno, Sparks, Carson City, Elko, and a portion of eastern California, including the Lake Tahoe area. In 2001, electric revenues were 90.6% of SPPC's revenue.
SPPC also provides natural gas service in Nevada to approximately 119,500 customers in an area of about 600 square miles in Reno/Sparks and environs. In 2001, natural gas revenues were 9.4% of SPPC's revenues.
On June 11, 2001, SPPC completed the sale of its water business to the Truckee Meadows Water Authority (TMWA) for $341 million. SPPC recorded a $25.8 million gain on the sale, net of income taxes of $18.2 million. Transfer of the hydroelectric facilities included in the contract of sale for an additional $8 million will require action by the California Public Utility Commission (CPUC). The sale agreement contemplates a second closing for the hydroelectric facilities to accommodate the CPUC's review of the transaction. See "Sale of Water Business," later, for further discussion.
SPPC has three primary, wholly owned subsidiaries: GPSF-B, Pinon Pine Corp. (PPC) and Pinon Pine Investment Co. (PPIC). GPSF-B, PPC and PPIC, collectively, own Pinon Pine Company, L.L.C., which was formed to take advantage of federal income tax credits available under (S)29 of the Internal Revenue Code associated with the alternative fuel (syngas) produced by the coal gasifier located at the Pinon Pine facility. (See Note 5 to the Financial Statements.)
Business and Competitive Environment
In 2001, SPPC's electric business contributed $1,399 million (90.6%) in revenues from continuing operations. The electric system peak typically occurs in the summer, while the winter peak runs nearly as high. The system has an annual load factor of approximately 71%, which is higher than the industry norm of 50% to 55%.
Winter peak loads are primarily driven by increased demand for space heating, demand for air movement (with forced air gas and oil furnaces), and ski resort demands (hotels, lifts, etc.). Summer peak loads are primarily driven by cooling equipment demand (including air conditioning demand) and irrigation pumping. SPPC's peak load increased an average of 4.6% annually over the past five years, reaching 1,529 MW on August 7, 2001. SPPC's total electric MWh sales have increased an average of 10.3% annually over the past five years. The mining and wholesale sectors comprise the majority of this growth.
SPPC's electric customers by class contributed the following toward 2001 and 2000 MWh sales:
MWh Sales 2001 2000 -------------------------- ---------------------------- Residential 2,069,140 16.1% 2,042,704 16.4% Commercial and Industrial: Mining 2,662,763 20.7% 2,720,018 21.9% Offices/Schools/Government 1,141,861 8.9% 1,108,988 8.9% Resorts & Recreation 689,861 5.4% 780,526 6.3% Manufacturing/Warehouse 769,053 5.9% 795,728 6.4% Wholesale 4,123,513 32.1% 3,613,996 29.1% All Other 1,408,456 10.9% 1,372,701 11.0% ----------- ------ ------------ ------ Total 12,864,647 100.0% 12,434,661 100.0% =========== ====== ============ ====== |
According to the Nevada Division of Minerals, the State led the nation in the production of gold in 2001, as it has for many years. Nevada's gold production in 2001 reached 8.1 million ounces. However, in 2001 the industry continued to be challenged by low gold prices and numerous financial, environmental, and regulatory hurdles. It responded to these pressures by continuing to pursue mergers and consolidations, streamlining
operations, cutting overhead costs, and closing down less efficient and uneconomic properties. These actions led to SPPC seeing a small decrease in total MWh sales to the mining industry during 2001.
SPPC has long-term power sales agreements with seven of its major mining customers for terms ranging from 5 to 15 years. The final contract expires in 2011. These agreements secure over 265 MW of present and future mining load, or approximately $96 million in annual revenues, which is 6.9% of 2001 electric operating revenues. The agreements require that customers maintain minimum demand and load factor levels, and include termination charge provisions to recover all of SPPC's customer-specific facilities investment.
The resorts and recreation customer segment consists of hotels, casinos and ski resorts which comprise 5.4% of the total electric system retail MWh sales. Overall MWh sales are slightly down from 2000 due to implementation of energy conservation efforts at most of the large casino hotels and a winter that has provided an increase in precipitation. The snowfall has decreased the need for the ski resorts to use their snowmaking equipment which is a large component of their energy consumption.
Tourism and gaming were affected by the decrease in flight schedules and the economy downturn last September. Northern Nevada casinos have also seen some impact from Indian gaming in northern California. Though the tourism and gaming segment faced challenges in 2001, northern Nevada continues to be a strong player in the entertainment industry. Northern Nevada casino hotels are continuously focusing on competitive strategies by packaging entertainment value, customer comfort and reasonable pricing with the natural attraction of the Sierra Nevada geographical location which has proven to be a successful model. Many of the larger casinos have also remodeled their facilities to provide for an increased demand for conventions.
The manufacturing and warehousing customer segment overall continues to grow at a steady pace. Several manufacturing customers have suffered large order reductions and production losses due to the economic slowdown, which has had an impact on the rapid growth projections. At the same time, there has been growth in the sector as the result of manufacturers relocating out of the California market and expanding their Nevada presence. Northern Nevada continues to show promise as a destination of choice for the high-technology industry, which should result in a continued increase in sales to the manufacturing and warehousing customer segment. In 2001, SPPC solidified working relationships within the business community recruiting industries in targeted sectors such as plastic manufacturers and hi-technology companies.
The 2001 session of the Nevada State legislature saw the passage of AB 661. One provision of this bill allows commercial customers with an average annual load of one megawatt or more to file a letter of intent and application with the PUCN to buy electricity from another provider beginning in mid-2002. This provision was part of a package of legislation passed by the 2001 Legislature to ensure the continued creditworthiness of the Utilities and protect consumers from unexpected rate hikes. During 2001, a number of SPPC's large commercial customers indicated they would be filing applications to pursue alternative supplier options. See Regulation and Rate Proceedings in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for further discussion.
SPPC's MWh sales to wholesale customers have increased 14.1% over the past year. During 2001, firm and non-firm sales to wholesale customers comprised 32.1% of total energy sales. Wholesale customers consist of other utilities or municipalities that sell power to end users, marketing entities and others that exchange power with SPPC.
Wholesale MWh Sales 2001 2000 --------------------------- --------------------------- Firm Sales 4,085,097 99.1% 3,365,783 93.1% Non-Firm Sales 38,416 0.9% 248,213 6.9% ---------- ------ ---------- ------ Total 4,123,513 100.0% 3,613,996 100.0% ========== ====== ========== ====== |
SPPC's increase in wholesale MWh sales from last year was a result of market conditions and SPPC's power procurement activities. See Purchased Power Procurement in Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of the Utilities' purchased power procurement strategies.
Construction Program
SPPC's construction program and estimated expenditures are subject to continuing review, and are revised from time to time due to various factors, including the rate of load growth, escalation of construction costs, availability of fuel types, the number and status of proposed independent generation projects, the need for additional transmission capacity in northern Nevada, changes in environmental regulations, adequacy of rate relief, and SPPC's ability to raise necessary capital.
Gross construction expenditures for 2001, including AFUDC and contributions in aid of construction, were $133.6 million, and for the period 1997 through 2001, were $762.4 million. Estimated construction expenditures for 2002 and the period 2003-2006 are as follows (dollars in thousands):
Total 2002 2003-2006 5-Year --------------------------------------------- Electric facilities $ 132,875 $ 382,096 $ 514,971 Gas facilities 9,751 48,420 58,171 Common facilities 6,669 26,660 33,329 --------------------------------------------- Total construction expenditures 149,295 457,176 606,471 --------------------------------------------- AFUDC (5,682) (15,056) (20,738) Net salvage, including cost of removal (120) (400) (520) Net customer advances and contributions in aid of construction (3,942) (15,320) (19,262) --------------------------------------------- Total cash requirements $ 139,551 $ 426,400 $ 565,951 ============================================= |
Total construction expenditures estimated for 2002 and the 2003-2006 period, for each segment of SPPC's business, consist of the following (dollars in thousands):
Total 2002 2003-2006 5-Year ---- --------- ------ Electric Facilities: Distribution $ 48,386 $ 256,387 $ 304,773 Generation 5,335 21,100 26,435 Transmission 69,709 83,599 153,308 Other 9,445 21,010 30,455 ------------------------------------------ 132,875 382,096 514,971 ------------------------------------------ Gas Facilities: Distribution 8,819 44,680 53,499 Other 932 3,740 4,672 ------------------------------------------ 9,751 48,420 58,171 ------------------------------------------ Common Facilities 6,669 26,660 33,329 ------------------------------------------ TOTAL $ 149,295 $ 457,176 $ 606,471 ========================================== |
The Falcon to Gonder Transmission Project is a 345kV transmission line within northern Nevada with a planned in-service date of June 2003. Total project costs incurred through December 31, 2001, were $11.5 million. Actual costs incurred in 2001 were $5.9 million. Estimated costs for 2002 are $54.5 million.
Facilities and Operations
Total System
SPPC maintains a wide variety of resources in its generation system. The availability of alternate resources allows SPPC to dispatch its electric generation system in a more cost-effective manner under varying operating and fuel market conditions, while maintaining system integrity. SPPC also supplies its customers' electric power needs using a combination of firm and interruptible resources to maximize operating flexibility and reliability, while minimizing cost. During 2001, SPPC generated 44.6% of its total electric energy requirements in its own plants, purchasing the remaining 55.4% as shown below:
Megawatt- Percent Hours of Total ----------- ---------- SPPC Company Generation ----------------------- Gas/Oil 4,090,757 30.3% Coal 1,870,909 13.9% Hydro 50,993 0.4% ----------- -------- Total Generated 6,012,659 44.6% ----------- -------- Purchased Power --------------- Utility Purchases: Long-Term Firm 454,589 3.4% Short-Term Firm 6,164,555 45.7% Spot Market 30,910 .2% Non-Utility Purchases: Geothermal 702,616 5.2% Other 125,988 .9% Transmission & Balancing 5,071 0.0% ----------- -------- Total Purchased 7,483,729 55.4% ----------- -------- Total 13,496,388 100.0% =========== ======== |
As a supplement to its own internal generation, SPPC purchases both firm and non-firm energy to meet its customer demand requirements. See Purchased Power Procurement in Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of the Utilities' purchased power procurement strategies. In 2001, most of SPPC's non-utility generation came from QFs, except for 21,730 MWh, which came from two small power producers.
Risk Management
See Item 7A, Quantitative and Qualitative Disclosures About Market Risk.
Load and Resources Forecast
SPPC's electric customer growth rate was 1.9% in 2001, 2.6% in 2000, and 2.6% in 1999. Annual retail electricity sales were 8.7 million MWh in 2001, which represents a decrease of 1% compared to 2000 retail electricity sales of 8.8 million MWh. Annual wholesale electricity sales reached 4.1 million MWh in 2001, which represents an increase of 14% over 2000 wholesale electricity sales of 3.6 million MWh. Overall, annual system electricity sales reached 12.9 million MWh in 2001, which represents an increase of 3.5% over 2000 system electricity sales of 12.4 million MWh. The 2001 peak electric demand was 1,529 MW compared to a weather-adjusted peak of 1,531 MW for 2000. The lack of growth in the peak is mainly attributable to demand-reduction efforts by customers due to the power issues in the West.
The forecasted peak energy demand for 2002 and 2003 below reflects, among others, five key assumptions:
. Northern Nevada experiences normal weather conditions, based on
historical 20-year averages.
. No adjustments have been made to incorporate the potential loss of
customers leaving for alternative providers under the provisions of
AB661. However, one large commercial customer of SPPC has filed an
application under the provisions of AB 661 to procure energy from an
alternative source other than the Utility. The customer, SPPC, and
PUCN staff are negotiating a stipulation regarding settlement of the
terms and conditions under which this customer will be permitted to
procure energy from an alternative source other than SPPC. The terms
and conditions of the stipulation are expected to comply with the
provisions of AB 661 in that SPPC and
its remaining customers will not be negatively impacted by the
customer's departure. A hearing on the stipulation has been set for
March 20, 2002.
. Retail electric rates are set at the levels requested in SPPC's most
recent general and deferred energy rate case filings.
. SPPC continues to be a summer peaking utility.
. Concerns over power outages in California subside by summer 2002
resulting in reduced conservation efforts by SPPC's customers.
Sales and peak energy demand will vary from forecasted levels to the extent that actual experience varies from the above assumptions and to the extent that other factors affect sales and demand.
SPPC's actual total system capability and peak loads for 2001, and as estimated for summer peak demand for 2002 and 2003 are shown below:
Capacity at 2001 Peak Forecast Summer Peak ----------------------------------------------------- MW % 2002 2003 ----------------------------------------------------- SPPC Company Generation: Existing (1) 1,026 58% 1,045 1,062 ----------------------------------------------------- Purchases: Long/Short-Term Firm (2) 475 27% 500 525 Interruptible/Wheeling/Losses (3) 176 10% 5 7 Non-Utility Generators 93 5% 85 85 ----------------------------------------------------- Subtotal 744 42% 590 617 ----------------------------------------------------- Additional Required 0 0% 176 165 Total System Capacity 1,770 100% 1,811 1,844 ===================================================== Net System Peak Demand (4) 1,529 90% 1,621 1,654 Planning Reserve 177 10% 190 190 ----------------------------------------------------- Total Requirement 1,706 100% 1,811 1,844 ===================================================== Growth over previous year 6.2% 1.8% |
(1) The Clark Mountain Gas Turbine (G.T.) and Winnemucca G.T. were both
unavailable during the time of the 2001 system peak. Assumes Pinon
Pine duct burner modification occurs in the fall 2002, adding 17 MW of
net capacity.
(2) Value is net of losses and includes committed short-term firm block
purchases. Values shown represent purchases within existing
transmission system limits. No economy (non-firm) energy purchases
(only firm power purchases) occurred during the 2001 peak.
(3) Includes net wheeling from the Naniwa power station during the 2001
peak of 132 MW, which was retained in SPPC's system.
(4) The system peak shown for 2001 occurred on August 7, 2001, at 5:00
p.m.
SPPC plans its system capacity needs in accordance with the WSCC reliability criteria, which recommends planning reserves in excess of required operating reserves. "Additional Required" represents the additional, uncommitted capacity needed in order to maintain adequate reserve margin consistent with the WSCC planning reserve criteria. These additional reserves will be met, if needed, with short-term purchases through 2003 to the extent available. At the time of the 2001 system peak, SPPC had purchased firm capacity
under long-term contracts with other utilities and qualifying facilities equal to 10% of total peak hour capacity. Short-term firm block purchases comprised 26% of the peak, with no economy (non-firm) purchases transacted (only firm power purchases).
Generation
The following is a list of SPPC's share of generation plants including the MW summer net capacity, the type and fuel used to generate, and the year(s) that the unit(s) was (were) installed.
Number of MW Name Type Fuel Units Capacity Years(s) Installed ----------------------------------------------------------------------------------------------------------------------- Valmy (1) Steam Coal 2 266 1981, 1985 Tracy Steam Gas/Oil 3 244 1963, 1965, 1975 Pinon (2) Combined Cycle (3) Gas 1 89 1996 Clark Mtn. CT's Combustion Turbine Gas/Oil 2 138 1994 Ft. Churchill Steam Gas/Oil 2 226 1968, 1971 Other (4) Gas Turbine, Hydro Gas/Oil, Propane 33 82 1899-1970 -------- ---------- Grand Total SPPC 43 1045 ======== ========== |
(1) SPPC is the operator and owns an undivided 50 percent interest in the Valmy plant. Idaho Power Company owns the remainder. The capacities shown above for the Valmy plant represent SPPC's share only. SPPC owns 100 percent of all of its remaining electric generation plants.
(2) Pinon is part of the Pinon Pine Integrated Coal Gasification Combined Cycle power plant. This project was part of the Department of Energy's Clean Coal Demonstration Program. Although the coal gasification portion of the facility is in the start-up phase, the unit has been operating on natural gas since 1996.
(3) The combined cycle at Pinon consists of one combustion turbine and one steam turbine.
(4) The 4 hydro generating units were to be included in the sale of SPPC's water business in June 2001. However, the California Legislature has mandated that the sale of these units (as well as any other units serving California markets) be postponed until 2006 due to uncertainty in the California power markets. See sale of Water Business, later.
Purchased Power
SPPC continues to manage a diverse portfolio of contracted and spot market supplies, as well as its own generation, with the objective of minimizing its net average system operating costs. During 2001, SPPC experienced a dramatic increase in the price of market energy compared to previous years. Some of this increase is reflective of the overall increase in electricity costs throughout the western United States. See Industry and Regional Problems Affecting the Utilities, earlier. Some of SPPC's purchased power contracts are at price levels above which SPPC is permitted to recover in current rates. See Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations, for a discussion of deferred energy accounting and legislation.
SPPC is a member of the Northwest Power Pool and Western Systems Power Pool. These pools have provided SPPC further access to spot market power in the Pacific Northwest and the Southwest. In turn, SPPC's generation facilities provide a backup source for other pool members who rely heavily on hydroelectric systems.
SPPC purchases hydroelectric and thermal generation spot market energy, by the hour, based upon economics and system import limits. Also purchased during peak load periods is firm energy as required to supply load and maintain adequate operating reserve margins. As off-system energy costs increase, SPPC
supplies a higher percentage of its native load utilizing its fossil fuel generation but is still required to buy peaking energy from the market.
Currently, SPPC has contracted for a total of 75 MW of long-term firm purchased power from the utility supplier listed below. SPPC's firm purchase power contract contains minimum purchase obligations. Meeting these minimums has not been a problem for SPPC in the past, and is not expected to be a problem in the future.
Contract Operation Termination Minimum Contract Party Capacity Date Date Capacity ------------------------------------------------------------------------------------ PacifiCorp 75 MW June 1989 Feb 28, 2009 70% |
According to PURPA, SPPC is obligated, under certain conditions, to purchase the generation produced by small power producers and co-generation facilities at costs determined by the appropriate state utility commission. Generation facilities that meet the specifications of the regulations are known as qualifying facilities. As of December 31, 2001, SPPC had a total of 109 MW of maximum contractual firm capacity under 15 contracts with QFs. SPPC also had contracts with three projects at variable short-term avoided cost rates. All QF contracts currently delivering power to SPPC at long-term rates have been approved by either the PUCN or the California Public Utility Commission (CPUC), and have QF status as approved by the FERC. One long-term QF contract terminates in 2006, one terminates in 2039, and the rest terminate between 2014 and 2022.
Energy purchased by SPPC from QFs constituted 8.8% of the net system requirements (excluding wholesale purchases) during 2001. These contracts continue to provide useful diversity for SPPC in meeting its peak load. All the QFs from which SPPC makes firm purchases are either geothermal (87%), hydroelectric or biomass.
The actual QF firm capacity output under contract was 64 MW during the summer of 2001. The actual QF output for all non-utility generator deliveries during the summer 2001 peak was 93 MW
Transmission
SPPC's existing transmission lines extend some 300 miles from the crest of the Sierra Nevada in eastern California, northeast to the Nevada-Idaho border at Jackpot, Nevada, about 160 miles from Reno northwest to Alturas, California, and 250 miles from the Reno area south to Tonopah, Nevada. A 230 kV transmission line connects SPPC to facilities near the Utah-Nevada state line, which in turn interconnects SPPC to Utah Power facilities. A 345 kV transmission line connects SPPC to Idaho Power facilities at the Idaho-Nevada state line. A 345 kV line connects SPPC to the Bonneville Power Administration's facilities near Alturas, California.
SPPC also has two 120 kV lines and one 60 kV line that interconnect with Pacific Gas & Electric on the west side of SPPC's system at Donner Summit, California. Two 60 kV transmission ties allow wheeling of up to 14 MW of power from the Beowawe Geothermal Project, which is located within SPPC's service area, to Southern California Edison. These two minor interties are available for use during emergency conditions affecting either party. The transmission intertie system provides access to regional energy sources.
The Falcon to Gonder Project is a 185-mile 345 kV line connecting SPPC's Falcon Substation to Mt. Wheeler Power's Gonder Substation. The Falcon to Gonder Project improves system import and export capabilities and enables SPPC to provide transmission service between Idaho, Utah, and the northwest. The Final Environmental Impact Statement was released in December 2001. Federal permitting is expected to be completed by the end of March 2002, with construction starting in May 2002. SPPC has ordered long lead material like towers and transformers, and is preparing to start the construction bid process. The project in-
service date is June 2003. Total project costs incurred through December 31, 2001, were $11.5 million. Actual costs incurred in 2001 were $5.9 million. Estimated costs for 2002 are $54.5 million.
See Regulation and Rate Proceedings, FERC Matters in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations for a discussion of regional transmission issues.
Fuel Availability
SPPC's 2001 fuel requirements for electric generation were provided by natural gas, coal, and oil. The average costs of coal, gas and oil for energy generation per MMBtu for the years 1997-2001, along with the percentage contribution to total fuel requirements, are as follows:
------------------------------------------------------------------------------------------ Average Consumption Cost & Percentage Contribution to Total Fuel Requirements Gas Coal Oil --- ---- --- $/MMBtu Percent $/MMBtu Percent $/MMBtu Percent ------- ------- ------- ------- ------- ------- 2001 5.63 45.3% 1.55 32.4% 6.49 22.3% 2000 4.99 66.6% 1.51 32.2% 7.62 1.2% 1999 2.71 62.3% 1.46 37.3% 3.41 0.4% 1998 2.12 60.7% 1.56 39.0% 3.96 0.3% 1997 2.03 62.0% 1.80 37.0% 3.35 1.0% ------------------------------------------------------------------------------------------ |
For a discussion of the change in fuel costs, see Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
SPPC's long-term contract with Black Butte Coal Company for coal shipments to Valmy from the mine near Rock Springs, Wyoming, remains in effect until June 30, 2007, or until all volume requirements under the contract are delivered and/or cancelled. Due to previous accelerated purchases and cancellations, and continuing cancellations of minimum monthly volume obligations, SPPC fully satisfied all volume requirements and termination of the contract occurred in February 2002.
SPPC's long-term coal contract with Canyon Fuel Company, LLC (Canyon), which provides coal for Valmy from Canyon's SUFCO mine in Central Utah, expires on June 30, 2003. This contract also contains minimum volume requirements that SPPC expects to meet each year until termination. The current owner of the SUFCO mine is Arch Coal, Inc., which acquired ARCO Coal (the previous owner of the Canyon properties, including SUFCO) on June 1, 1998.
During 2001, two short-term agreements for the purchase of spot market coal were in place. The source of this coal is the Uinta Basin of Utah. These spot market purchases supplement base volume requirements under SPPC's long-term coal contracts at a cost approximately one-half that of contract coal.
As of December 31, 2001, Valmy's coal inventory level was 378,011 tons, or approximately 65 days of consumption at 100% capacity. Inventory levels were increased to allow for economically priced supplies under contract to be delivered prior to the expiration of those supply arrangements.
During 2001, transportation of coal to Valmy was provided by the Union Pacific Railroad (UP) under a 3-year agreement effective June 1, 1998. The agreement was extended an additional 3.5 years and will now expire December 31, 2004.
During 2001, SPPC operated the Pinon Pine facility exclusively on natural gas. No coal was purchased in 2001 for synthetic gas production in the plant's coal gasification facility.
SPPC meets its needs for residual oil for generation through purchases on the spot market. During portions of 2001, oil prices were significantly lower than natural gas prices. Additional oil supply was ordered for consumption and to ensure the ability of the electric division to make gas available to SPPC's natural gas business on peak days. The actual residual oil inventory level at these two sites was 318,000 barrels as of December 31, 2001, which is equal to a 14-day supply at full load operation.
Natural Gas Business
SPPC's natural gas business consists of operating the local distribution company (LDC) for the Reno/Sparks metropolitan area and procuring gas for electrical power generation at the Tracy and Ft. Churchill plants. The LDC accounted for $145.7 million in 2001 operating revenues or 9.4% of SPPC's revenues from continuing operations. Growth in SPPC's LDC service territory continues to be strong. Customer meter count growth during 2001 was 4.7%. SPPC's total customer meter count increased by 5,446 to 121,862 meters by the end of 2001.
Growth in all sectors is expected to continue as new developments in SPPC's distribution service area are planned. SPPC's forecast for growth in the number of LDC customers in 2002 is: residential 4.8%, small commercial 2.5%, and large commercial 5.5%.
SPPC's natural gas LDC business is subject to competition from other suppliers and other forms of energy available to its customers. Large customers with fuel switching capability compare natural gas prices on an interruptible basis to alternative energy source prices. Additionally, large customers have the ability to secure their own gas supplies; however, through 2000 and 2001, large customers that were securing their own supplies generally found that receiving gas from SPPC's LDC was more reliable and more economical than securing their own supplies. At the end of 2001, only two large customers were still securing their own supplies.
To secure gas supplies for power generation and the LDC, SPPC contracted for firm winter-only and annual gas supplies with 10 Canadian and domestic suppliers to meet the firm requirements of its LDC and electric operations. The winter period contracts totaled 160,000 Dth per day through March 2001, and the summer period contracts totaled 115,000 Dth per day for April through October 2001.
SPPC's firm natural gas supply is supplemented with natural gas storage services and supplies from a Northwest Pipeline Co. facility located at Jackson Prairie in southern Washington and liquefied natural gas (LNG) storage from a facility located near Lovelock, Nevada. The LNG facility is operated by Paiute Pipeline Company and is used for meeting peak demand. The Jackson Prairie and LNG facilities can contribute a total of approximately 48,000 Dth per day of peaking supplies.
In November 1996, SPPC entered an agreement to sell winter seasonal peaking capacity supplies to another company over a seven-year period. The contract provides for the payment to SPPC of a monthly reservation charge, reimbursement of pipeline capacity charges during the winter, and a volumetric commodity charge based on the market price for natural gas. SPPC was able to enter into this agreement due to the ability of its power plants to utilize alternative fuels and its power importation option.
Following is a summary of the transportation and approximate storage capacity of SPPC's current gas supply program for 2001 (for the twelve months period ending October 31, 2002). Firm transportation capacity on the Northwest/Paiute system exists to serve primarily the LDC. Firm transportation capacity on the PGT/Tuscarora system exists primarily to serve SPPC's electric generating plants. Storage capacity is generally used for the peaking requirements of the LDC.
Northwest: 68,696 decatherms per day firm (annual) 90,000 decatherms per day interruptible Paiute: 103,774 decatherms per day firm (November through March) 61,044 decatherms per day firm (April through October) 90,000 decatherms per day interruptible NOVA: 103,774 decatherms per day firm ANG: 93,301 decatherms per day firm PGT: 83,500 decatherms per day firm (annual) 60,270 decatherms per day firm (November through April) 90,000 decatherms per day interruptible Tuscarora: 121,911 decatherms per day firm (annual) 50,000 decatherms per day interruptible Storage Capacity ---------------- Williams: 281,242 decatherms from Jackson Prairie 12,687 decatherms per day from Jackson Prairie Paiute: 463,034 decatherms from Lovelock LNG 35,078 decatherms per day from Lovelock LNG facility |
Total LDC Dth supply requirements in 2000 and 2001 were 13.2 million Dth and 14.26 million Dth, respectively. Electric generating fuel requirements for 2001 and 2000 were 28.96 million Dth and 38.6 million Dth, respectively.
In January 2001, the PUCN approved a Purchase Gas Adjustment filing from the previous year and the new rates became effective February 1, 2001. An average residential customer had an increase in their rates of approximately 35%. In November 2001, the PUCN approved another Purchase Gas Adjustment filing. An average residential customer had an increase in their rate of approximately 25%. Each of these approvals reflects complete recovery of the LDC's gas purchases.
As of December 31, 2001, SPPC owned and operated 1,601 miles of three-inch equivalent natural gas distribution piping, 108 miles of which were added in 2001. Also during 2001, Tuscarora Gas completed construction of a lateral gas transmission line to a new SPPC high-pressure regulator station (completed in 2000). The lateral transmission line connected Tuscarora's primary transmission line to SPPC's LDC north of Reno in the Stead, Nevada area. The line provided the LDC the ability to receive more supply and exercise more operating flexibility. In 2001, SPPC completed several smaller system improvement projects. A small propane system that SPPC owns and operates was connected to the new Tuscarora Gas lateral line and converted to a natural gas system. Over 4 miles of 12" diameter main was added to the system, which improved the capacity and reliability in the southwest Reno area.
Sale of Water Business
On June 11, 2001, SPPC closed the sale of its water business to the Truckee Meadows Water Authority (TMWA) for $341 million. SPPC recorded a $25.8 million gain on the sale, net of income taxes of $18.2 million. Pursuant to a stipulation entered into in connection with the sale and approved by the PUCN, SPPC is required to refund to customers $21.5 million of the proceeds from the sale. The refund is being credited on the electric bills of SPPC's former water customers over a period not to exceed fifteen months from June 11, 2001.
Under a service contract with TMWA, SPPC will provide, on an interim basis, customer service, billing, and meter reading services to TMWA. Transfer of the hydroelectric facilities included in the contract of sale for an additional $8 million will require action by the CPUC. The sale agreement contemplates a second
closing for the hydroelectric facilities to accommodate the CPUC's review of the transaction. Not included in the sale were certain properties along the Truckee River related to the hydroelectric facilities and in California at Independence Lake. SPPC will continue to own this property with the intent of a possible future sale.
Regulation and Rate Proceedings
See Regulation and Rate Proceedings in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
As a condition to its approval of the merger between SPR and NPC, the PUCN required the Utilities to file a Divestiture Plan for the sale of their electric generation assets. The PUCN approved a revised Divestiture Plan stipulation in February 2000. In May 2000 an agreement was announced for the sale of NPC's 14% undivided interest in the Mohave Generating Station ("Mohave"). In the fourth quarter of 2000 the Utilities announced agreements to sell six additional bundles of generation assets described in the approved Divestiture Plan. The sales were subject to approval and review by various regulatory agencies.
AB 369, which was signed into law on April 18, 2001, prohibits until July 2003 the sale of generation assets and directs the PUCN to vacate any of its orders that had previously approved generation divestiture transactions. In January 2001, California enacted a law that prohibits until 2006 any further divestiture of generation properties by California utilities, including SPPC, and could also affect any sale of NPC's interest in Mohave after July 2003 since the majority owner of that project is Southern California Edison. In addition, SPPC's request for an exemption from the requirements of a separate California law requiring approval of the CPUC to divest its plants was denied, subject to future refiling.
The sales agreements for the six bundles provide that they terminate eighteen months after their execution unless the parties agree to an earlier termination. The parties may extend the termination another six months to obtain additional regulatory approvals. As a result of the legislative and regulatory developments which have rendered the contracts impossible to perform, the Utilities are engaged in discussions with the buyers of the generation assets regarding the formal termination of the sales agreements and the related energy buyback contracts and interconnection agreements. As of December 31, 2001, the Utilities had incurred costs of approximately $12.3 million and $15.5 million, respectively, in order to prepare for the sale of generation assets. The Utilities have requested recovery of these costs in each Utility's respective general rate case filing with the PUCN, discussed in Regulation and Rate Proceedings, in Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operation.
On April 26, 2001, SPR and Enron Corp. announced that they had mutually agreed to terminate their agreement for SPR's purchase of Enron's wholly owned subsidiary, Portland General Electric (PGE). In negotiating the mutual termination, SPR agreed to share certain expenses that Enron Corp and PGE had incurred for the proposed transaction. The Consolidated Statement of Income of SPR for the year ended December 31, 2001, reflects a charge in connection with the planned purchase of PGE of $22 million, including approximately $7.5 million representing a termination payment for shared expenses.
As with other utilities, NPC and SPPC are subject to federal, state and local regulations governing air, water quality, hazardous and solid waste, land use and other environmental considerations. Nevada's Utility Environmental Protection Act requires approval of the PUCN prior to construction of major utility, generation
or transmission facilities. The United States Environmental Protection Agency (EPA), Nevada Division of Environmental Protection (NDEP), and Clark County Health District (CCHD) administer regulations involving air quality, water pollution, solid, hazardous and toxic waste. SPR's Board of Directors has a comprehensive environmental policy and separate board committee that oversees NPC, SPPC, and SPR's corporate performance and achievements related to the environment.
Nevada Power Company
The Grand Canyon Trust and Sierra Club filed a lawsuit in the U.S. District Court, District of Nevada, in February 1998, against the owners (including NPC) of the Mohave Generation Station ("Mohave"), alleging violations of the Clean Air Act regarding emissions of sulfur dioxide and particulates. An additional plaintiff, National Parks and Conservation Association, later joined the suit. The plant owners and plaintiffs have had numerous settlement discussions and filed a proposed settlement with the court in October 1999. The consent decree, approved by the court in November 1999, established emission limits for sulfur dioxide and opacity and required installation of air pollution controls for sulfur dioxide, nitrogen oxides and particulate matter. The new emission limits must be met by January 1, 2006 and April 1, 2006 for the first and second units respectively. However, if the owners sell their entire ownership interest with a closing date prior to December 30, 2002, the new emission limits become effective 36 months and 39 months from the date of last closing for the two respective units. The estimated cost of new controls is $395 million. As a 14% owner in the Mohave Station, NPC's cost could be $55 million.
Also, the United States Congress authorized the EPA to study the potential impact Mohave may have on visibility in the Grand Canyon area. A final report of the study results was released in March 1999. The study acknowledges that sulfur dioxide emissions from Mohave are transported to the Grand Canyon. The EPA has solicited information to determine whether visibility impairment in the Grand Canyon can be reasonably attributed to Mohave. The EPA determined that significant visibility impairment to the Grand Canyon cannot be reasonably attributable to the station provided controls are installed as agreed to in the consent order. Therefore, the EPA will not require a Best Available Retrofit Technology Review. Provisions that were agreed to in the settlement will be reflected in the state Implementation Plan for Nevada.
In May 1997, NDEP ordered NPC to submit a plan to eliminate the discharge of Reid Gardner Station wastewater to groundwater. The NDEP order also required a hydrological assessment of groundwater impacts in the area. In June 1999, NDEP determined that wastewater ponds had degraded groundwater quality. In August 1999, NDEP issued a discharge permit to Reid Gardner Station and an order that requires all wastewater ponds to be closed or lined with impermeable liners over the next 10 years. This order also required NPC to submit a Site Characterization Plan to NDEP to ascertain impacts. This plan is under review by NDEP. After approval, an estimate of remediation costs will be determined by NPC. New pond construction and lining costs are estimated at $15 million.
Also, at the Reid Gardner Station, the NDEP has determined that there is additional groundwater contamination that resulted from oil spills at the facility. NDEP has required submitting a corrective action plan. The extent of contamination has been determined and remediation is occurring at a modest rate. An engineering evaluation of the current remediation technology will occur in 2002 to verify efficiency and to expedite remediation. Remediation modifications are not expected to materially affect the financial position of SPR or NPC.
In May 1999, NDEP issued an order to eliminate the discharge of NPC's Clark Station wastewater to groundwater. The order also required a hydrological assessment of groundwater impacts in the area. This assessment, submitted to NDEP in February 2001, warranted a Corrective Action Plan which was submitted to NDEP in November and is pending review. Remediation costs are expected to be in the $500,000 - $750,000
range. In addition to remediation, NPC will spend $789,000 to line existing ponds. After review and approval of the Corrective Action Plan by NDEP, NPC will implement remediation.
In July 2000, NPC received a request from the EPA for information to determine the compliance of certain generation facilities at the Clark Station with the applicable State Implementation Plan. In November 2000, NPC and the Clark County Health District entered into a Corrective Action Order requiring, among other steps, capital expenditures at the Clark Station totaling approximately $3 million. In March 2001, the EPA issued an additional request for information that could result in remediation beyond that specified in the November 2000 Corrective Action Order. If the EPA prevails, capital expenditures and temporary outages of four of Clark Station's generation units could be required. Additionally, depending on the time of year that the compliance activity and corresponding generation outage would occur, the incremental cost to purchase replacement energy could be substantial.
Sierra Pacific Power Company
In September 1994, Region VII of EPA notified SPPC that it was being named as a potentially responsible party (PRP) regarding the past improper handling of Polychlorinated Biphenyls (PCBs) by PCB Treatment, Inc., located in Kansas City, Kansas, and Kansas City, Missouri (the Sites). The EPA is requesting that SPPC voluntarily pay an undefined, pro rata share of the ultimate clean-up costs at the Sites. A number of the largest PRP's formed a steering committee, which is chaired by SPPC. The responsibility of the Committee is to direct clean-up activities, determine appropriate cost allocation, and pursue actions against recalcitrant parties, if necessary. The EPA issued an administrative order on consent requiring signatories to perform certain investigative work at the Sites. The steering committee retained a consultant to prepare an analysis regarding the Sites. The Site evaluations have been completed. EPA is developing an allocation formula to allocate the remediation costs. SPPC has recorded a preliminary liability for the Sites of $650,000 of which approximately $136,000 has been spent through December 31, 2001. Once evaluations are completed, SPPC will be in a better position to estimate and record the ultimate liabilities for the Sites.
Other Subsidiaries of SPR
LOS, a wholly owned subsidiary of SPR, owns property in North Lake Tahoe, California, which is leased to independent condominium owners. The property has both soil and groundwater petroleum contaminate resulting from an underground fuel tank that has been removed from the property. Additional contaminate from a third party fuel tank on the property has also been identified and is undergoing remediation. Estimated future remediation costs are not expected to be significant.
NEICO, a wholly owned subsidiary of SPR, owns property in Wellington, Utah, which was the site of a coal washing and load out facility. The site now has a reclamation estimate supported by a bond of $4 million with the Utah Division of Oil and Gas Mining. The property was under contract for sale and the contract required the purchaser to provide $1.3 million in escrow towards reclamation. However, the sales contract was terminated and NEICO took title to the escrow funds. In September 2000, NEICO leased the property together with an option to purchase. It is NEICO's intention to either lease or sell the property.
Tuscarora Gas Pipeline Company
TGPC was formed as a wholly owned subsidiary in 1993 for the purpose of entering into a partnership (Tuscarora Gas Transmission Company or TGTC) with a subsidiary of TransCanada to develop, construct and operate a natural gas pipeline to serve an expanding gas market in Reno, northern Nevada, and northeastern California. In December 1995, TGTC completed construction and began service on its 229-mile pipeline
extending from Malin, Oregon to Reno, Nevada. TGTC interconnects with PG&E Gas Transmission - Northwest (GT-NW) at Malin, Oregon. GT-NW is a major interstate natural gas pipeline extending from the U.S./Canadian border, at a point near Bonners Ferry, Idaho to the Oregon/California border. The GT-NW system provides TGTC customers access to natural gas reserves in the Western Canadian Sedimentary basin, one of the largest natural gas reserve basins in North America. As of December 31, 2001, SPR had an investment of approximately $14.6 million in this subsidiary.
As an interstate pipeline, TGTC provides only transportation service. SPPC was the largest customer of TGTC during 2001, contributing 80% of revenues. Malin, Oregon began taking service from TGTC during October 1996. The Sierra Army Depot at Herlong, California began taking service from TGTC in October 1997. In 1998, TGTC began serving two new customers, the United States Gypsum Company located north of Empire, Nevada, and HL Power Company located northwest of Wendel, California.
In 2000, TGTC began construction on a 14.2-mile lateral, creating a new city gate connection into the SPPC distribution system. The lateral was completed and placed in service January 29, 2001, providing SPPC with an additional 10,000 Dth per day of firm transportation capacity in January 2001 and 5,661 Dth in November 2001. Also in 2000, TGTC surveyed shipper interest in the feasibility of an expansion of transportation capacity. This survey established that 95,912 Dth per day of new capacity would be required to meet the needs of existing and new shippers for the 2002-2003 winter heating season. Facilities required in Nevada would be approximately 14.2 miles of 20" diameter pipe and one 600 HP booster unit, and in California, three compressor stations each with a 6,000 HP turbine and related facilities. On January 30, 2002, the FERC approved the plans to expand the interstate gas pipeline owned by the Tuscarora Gas Transmission Company. The project will increase the pipeline's capacity by 74% and will improve reliability of the natural gas transmission systems that serve northern Nevada. Final permitting for the project is pending before the U.S. Bureau of Land Management and other state and local agencies.
In May 2001, TGTC completed construction of approximately 3,520-feet of pipeline with meter and flow control to serve a 360 MW plant, a new interruptible transportation customer east of Reno, Nevada near SPPC's Tracy Power Plant, and in September, 2001, TGTC completed construction of a 10.8-mile pipeline to serve two new customers: the City of Susanville and the Department of Correction both in California.
For a discussion of TGPC's results of operations, refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Sierra Pacific Communications
SPC was created to examine and pursue telecommunications opportunities that leverage SPPC's existing skills of installing and deploying pipe and wire infrastructure. SPC presently has fiber optic assets deployed in the cities of Reno and Las Vegas.
SPC is currently marketing bandwidth services in the Reno/Sparks and Las Vegas metropolitan areas.
Sierra Touch America LLC (STA), a partnership between SPC and Touch America, a subsidiary of Montana Power Company, is constructing a fiber optic line between Salt Lake City, Utah and Sacramento, CA. The conduits included in the line are under contract to be sold to AT&T, PF Net corporations, and STA. SPC is responsible for 50% of the partnership's operating expenses and shares in the construction cost of the fiber network. Construction activity between Sacramento and Reno commenced in July 2000. Construction within Salt Lake City is complete and construction is in progress through the Reno, NV metropolitan area. The entire project is expected to be completed by mid 2003.
For a discussion of the legal proceedings affecting SPC refer to Item 3, Legal Proceedings.
For a discussion of SPC's results of operations refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
e.three
e.three was organized in October 1996 as an unregulated wholly owned subsidiary of SPR. It provides comprehensive energy and other business solutions in commercial and industrial markets. This is accomplished by offering a variety of energy-related products and services to increase customers' productivity and profits and improve the quality of the indoor environment. These products and services include: technology and efficiency improvements to lighting, heating, ventilation and air-conditioning equipment; installation or retrofit of controls and power quality systems; energy performance contracting; end-use services; and ongoing energy monitoring and verification services.
In September 1998, e.three and NEICO, then a wholly owned subsidiary of NPC, formed e.three Custom Energy Solutions, LLC, a Nevada limited liability company, for the purpose of selling and implementing energy-related performance contracts and similar energy services in southern Nevada. e.three Custom Energy Solutions, LLC's primary focus for its sales activities is in the commercial and industrial markets.
In October 1998, e.three acquired Independent Energy Consulting, Inc. (IEC), a California based company, in an exchange of SPR stock for all of IEC's stock. IEC provides energy procurement management, third party auditing, performance contract consulting and strategic energy planning in the industrial and commercial markets.
In mid 2000, e.three Custom Energy Solutions, LLC completed the construction of a chilled water cooling plant in the downtown area of Las Vegas. The plant is owned by e.three Custom Energy Solutions, LLC and supplies the indoor air-cooling requirements for a number of businesses in its immediate vicinity.
For a discussion of e.three's results of operations refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Sierra Pacific Energy Company
SPE was formed to market a package of technology and energy-related products and services in Nevada. SPE filed an application with the PUCN to be licensed as an Alternative Seller of Electricity in the state of Nevada. SPE has withdrawn its application with the PUCN and dissolved its retail energy marketing efforts. SPE continues to manage several long term commitments entered into prior to its withdrawal from the retail energy marketing effort.
For a discussion of SPE's results of operations refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Lands of Sierra
LOS was organized in 1964 to develop and manage SPPC's non-utility property in Nevada and California. These properties previously included retail, industrial, office and residential sites, timberland, and other properties. Remaining properties include land in Nevada and California. SPR has decided to focus on its core energy business. In keeping with this strategy, LOS continues to sell its remaining properties.
For a discussion of LOS' results of operations refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
Nevada Electric Investment Company
NEICO is a wholly owned subsidiary of SPR. In October of 1997, NEICO and UTT Nevada, Inc., an affiliate of Exelon Thermal Technologies, formed Northwind Las Vegas, LLC, a Nevada limited liability company, for the purpose of evaluating district energy projects in southern Nevada. Also, in October of 1997, NEICO and UTT Nevada, Inc. formed Northwind Aladdin, LLC, a Nevada limited liability company, for the purpose of owning, constructing, operating and maintaining the facility for the production and distribution of chilled water, hot water and emergency power for the Aladdin Hotel and Casino project in Las Vegas, Nevada. The project was completed in the first quarter of 2000 and is operational.
In September 1998, NEICO and e.three formed e.three Custom Energy Solutions, LLC, a Nevada limited liability company, for the purpose of selling and implementing energy-related performance contracts and similar energy services in southern Nevada. Refer to e.three for a more complete discussion of these activities
For a discussion of NEICO's results of operations refer to Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations.
SPR and its subsidiaries had 3,333 employees as of December 31, 2001, of which 1,787 were employed by NPC and 1,415 were employed by SPPC.
NPC's current contract with the International Brotherhood of Electrical Workers (IBEW) Local No. 396, which covers 55% of NPC's workforce, was renegotiated in February 2002 and is in effect until February 1, 2005. The contract provides for a 3% general wage increase for bargaining unit employees effective February 2, 2002, with 3% increases in 2003 and 2004.
SPPC's current contract with the IBEW Local No. 1245, which represents 62% of SPPC's workforce, was renegotiated in March 2000 and is in effect until December 31, 2002. The two-year contract provided for 3% general wage increases for bargaining unit employees beginning January 1, 2001, and January 1, 2002. In addition, the contract provides for participation by bargaining unit employees in the incentive compensation program.
The Utilities have nonexclusive local franchises or revocable permits to carry on their business in the localities in which their respective operations are conducted in Nevada and California. The franchise and other governmental requirements of some of the cities and counties in which the Utilities operate provide for payments based on gross revenues. During 2001, the state also passed a law requiring public utilities to collect from their customers a fee based on consumption. This universal energy charge is to help those customers who need assistance in paying their utility bills or need help in paying for ways to reduce energy consumption. During 2001, the Utilities collected $58.3 million in franchise or other fees based on gross revenues. They collected $3.9 million in universal energy charges based on consumption. They also paid and recorded as expense $0.5 million of fees based on net profits.
Franchise Type of Service Expiration Date -------------------------------------------------------------------------------- NPC: Las Vegas Electric November 2029 Clark County Electric May 2004 Nye County Electric May 2006 City of Henderson * Electric November 1999 SPPC: Reno Electric, Gas and Water** January 2006 Sparks Electric May 2006 Sparks Gas May 2007 Sparks Water** April 2004 Carson City Electric February 2012 City of Elko Electric April 2017 City of South Lake Tahoe Electric April 2018 Washoe County Gas and Water** May 2015 Washoe County Electric September 2015 Eureka County Electric July 2018 |
*currently being renegotiated.
** Water rights and obligations under the franchise agreements were assumed
by Truckee Meadows Water Authority in June 2001 upon the sale of SPPC's water
business.
The Utilities will apply for renewal of franchises in a timely manner prior to their respective expiration dates.
SPR, through its NPC and SPPC subsidiaries, participates in several utility associations, including the Electric Power Research Institute.
SPR has invested in Nth Power Technologies (Nth), a venture capital fund that invests in developing technology companies. Nth has made several investments that may result in SPR strengthening its market position and developing new products and services.
ITEM 2. PROPERTIES
The general character of SPR's, NPC's, and SPPC's principal facilities is discussed in Item 1 - Business.
Substantially all of NPC's utility plant is subject to the lien of the Indenture of Mortgage, dated October 1, 1953, and supplemental indentures thereto among NPC and Bankers Trust Company, securing NPC's outstanding first mortgage bonds.
Additionally, all of NPC's property in Nevada is subject to the lien of the General and Refunding Mortgage Indenture dated as of May 1, 2001 between NPC and the Bank of New York, as trustee, which lien is junior, subject and subordinate to the prior lien of the Indenture of Mortgage mentioned above.
Substantially all of SPPC's utility plant is subject to the lien of the Indenture of Mortgage, dated December 1, 1940, and supplemental indentures thereto between SPPC and State Street Bank and Trust, and Gerald R. Wheeler, as trustees, securing SPPC's outstanding first mortgage bonds.
Additionally, all of SPPC's property in Nevada is subject to the lien of the General and Refunding Mortgage Indenture dated as of May 1, 2001 between SPPC and the Bank of New York, as trustee, which lien is junior, subject and subordinate to the prior lien of the Indenture of Mortgage mentioned above.
Item 3. Legal Proceedings
Sierra Touch America LLC (STA), a partnership between SPC and Touch America, a subsidiary of Montana Power Company, is constructing a fiber optic line between Salt Lake City, Utah and Sacramento, CA. The conduits included in the line are under contract to be sold to AT&T, PF Net corporations, and STA. SPC is responsible for 50% of the partnership's operating expenses and shares in the construction cost of the fiber network. Construction activity between Sacramento and Reno commenced in July 2000, and the estimated completion date has been moved to early 2003. Williams Communications, LLC ("Williams") has filed a complaint in United States District Court alleging that STA has failed to make timely payment on invoices in connection with a construction agreement between Williams and STA. TI Energy Services ("TI") has filed a complaint in the District Court of Harris County, Texas, alleging that STA has failed to make timely payment on invoices in connection with a services agreement between TI and STA, whereby TI is to provide services for certain segments of the fiber optic line. Although SPC's ultimate liability, if any, cannot be estimated, Management believes the final outcome of the litigation is not likely to have a material adverse effect on SPR's financial position or results of operations.
SPPC owns a 345 kV transmission line that connects SPPC to the facilities of the Bonneville Power Administration ("BPA") near Alturas, California. The Transmission Agency of Northern California ("TANC") initiated proceedings in the United States District Court for the Eastern District of California and the United States Court of Appeals for the Ninth Circuit, in each case alleging that BPA's construction of a small portion of the Alturas Intertie violated the Northwest Power Preference Act and requesting an injunction prohibiting operation of the Alturas Intertie. The case before the Eastern District was dismissed for lack of jurisdiction. The case before the Ninth Circuit was dismissed for TANC's failure to prosecute. In December 1999, TANC filed suit in the Superior Court of the State of California, Sacramento County, seeking an injunction against operation of the Alturas Intertie based on numerous allegations under state law, including inverse condemnation, trespass, private nuisance, and conversion. That case was removed to Federal Court and dismissed by the trial court, and is now on appeal in the Ninth Circuit. Although SPPC's ultimate liability, if any, cannot be estimated at this time, Management believes the final outcome of the appeal and any subsequent litigation is not likely to have a material adverse effect on SPR's financial position or results of operation.
See Environment in Item 1, Business, for information on environmental proceedings.
SPR and its subsidiaries, through the course of their normal business operations, are currently involved in a number of other legal actions, none of which has had or, in the opinion of management, is expected to have a significant impact on their financial positions or results of operations.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None.
PART II
ITEM 5. MARKET FOR THE REGISTRANT'S COMMON STOCK AND RELATED STOCKHOLDER
MATTERS
SPR's Common Stock is traded on the New York Stock Exchange (symbol SRP). The dividends paid per share and high and low sale prices of the Common Stock in the consolidated transaction reporting system in "The Dow Jones News Retrieval Service" for 2001 and 2000 are as follows:
Dividends Paid Per Share High Low --------------- ---------- ------------ 2001 First Quarter $.250 $ 16.000 $ 10.800 Second Quarter .000 17.000 13.290 Third Quarter * .200 17.020 14.670 Fourth Quarter * .200 15.560 13.850 2000 First Quarter .250 18.437 12.125 Second Quarter .250 15.687 12.500 Third Quarter .250 19.437 12.562 Fourth Quarter .250 18.062 14.875 |
* For federal income tax purposes, these payments were determined to be return of capital and therefore not taxable as ordinary income.
Number of Security Holders:
Title of Class Number of Holders -------------- ----------------- Common Stock: $1.00 Par Value As of March 15, 2002: 25,019 |
Dividends are considered periodically by SPR's Board of Directors and are subject to factors that ordinarily affect dividend policy, such as current and prospective earnings, current and prospective business conditions, regulatory factors, SPR's financial condition and other matters within the discretion of the Board. As a result of the unprecedented conditions in the wholesale energy markets that negatively affected SPR's earnings prior to the restoration of deferred energy accounting in Nevada, the Board of Directors decided on April 13, 2001 not to pay the Common Stock dividend that, if it had followed historical practices, would have been paid in May 2001. Following the passage of legislation in Nevada which reinstated deferred energy accounting for electric utilities, the Board re-examined the factors described previously and on July 20, 2001 declared a dividend of $.20 per share on SPR's Common Stock, payable September 15, 2001. The Board of Directors also established the following schedule for when future dividends would normally be paid, if declared: December 15, March 15, June 15 and September 15. The Board subsequently voted on November 6, 2001 to declare a dividend of $.20 per share, payable December 15, 2001. The Board will continue to review these factors on a periodic basis to determine if and when it would be prudent to declare a dividend on SPR's Common Stock. There is no guarantee that dividends will be paid in the future, or that, if paid, the dividends will be paid at the same amount or with the same frequency as in the past.
On February 6, 2002, the SPR Board of Directors declared a quarterly common dividend of $.20 per share. This dividend of approximately $20.4 million will be paid on March 15, 2002, to holders of record as of February 22, 2002.
The primary source of funds for the payment of dividends to SPR's stockholders is dividends paid to SPR by NPC and SPPC on their common stock, all of which is owned by SPR. These two subsidiaries are public utilities and are subject to regulation by state utility commissions which may impose limits on investment returns or otherwise impact the amount of dividends which may be paid by those companies. Moreover, the Articles of Incorporation of SPPC contain restrictions on the payment of dividends on SPPC's common stock in the event of a default in the payment of dividends on SPPC's preferred stock. Similarly, the bank credit facilities of NPC and SPPC prohibit the payment of dividends on each company's common stock if that company is in default under the terms of the relevant credit facility. Finally, the terms of certain outstanding series of first mortgage bonds of both NPC and SPPC contain certain quantitative limits on the amount of dividends that may be paid on each company's common stock.
ITEM 6. SELECTED FINANCIAL DATA
See Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of factors that may affect the future financial condition and results of operations of SPR, NPC, and SPPC.
The table below, for periods prior to July 28, 1999, reflects historical information for NPC.
Year ended December 31, (dollars in thousands, except per share amounts) ------------------------------------------------------------------------------ 2001 2000 1999 1998 1997 ---- ---- ---- ---- ---- Operating Revenues $ 4,588,730 $ 2,334,254 $ 1,284,792 $ 873,682 $ 799,148 ============ ============== ============= =============== ============= Operating Income $ 222,869 $ 127,389 $ 162,861 $ 147,277 $ 137,196 ============ ============== ============= =============== ============= Net Income (Loss) from Continuing Operations $ 29,866 $ (49,414) $ 48,210 $ 83,499 $ 82,091 ============= ============== ============= =============== ============= Income (Loss) from Continuing Operations Per Average Common Share - Basic $ 0.34 $ (0.63) $ 0.77 $ 1.64 $ 1.65 ============= ============== ============= =============== ============= Income (Loss) from Continuing Operations Per Average Common Share - Diluted $ 0.34 $ (0.63) $ 0.77 $ 1.64 $ 1.65 ============= ============== ============= =============== ============= Total Assets $ 8,181,314 $ 5,677,908 $ 5,235,917 $ 2,541,840 $ 2,339,422 ============= ============== ============= =============== ============= Long-Term Debt and SPPC/NPC Obligated Mandatorily Redeemable Preferred Trust Securities $ 3,564,977 $ 2,371,051 $ 1,793,999 $ 1,089,099 $ 1,014,311 ============= ============== ============= =============== ============= Dividends Declared Per Common Share $ 0.40 $ 1.00 $ 1.17 $ 1.45 $ 1.60 ============= ============== ============= =============== ============= |
Year ended December 31, (dollars in thousands) ---------------------------------------------------------------------------------------- 2001 2000 1999 1998 1997 ---- ---- ---- ---- ---- Operating Revenues $ 3,025,103 $ 1,325,470 $ 977,262 $ 873,682 $ 799,148 =============== =============== ================ ================ ================== Operating Income $ 144,364 $ 73,460 $ 116,983 $ 147,277 $ 137,196 =============== =============== ================ ================ =================== Net Income (Loss) $ 56,733 $ (39,780) $ 51,750 $ 83,499 $ 82,091 =============== =============== ================ ================ ================== Total Assets $ 5,225,369 $ 3,407,751 $ 3,378,485 $ 2,541,840 $ 2,339,422 =============== =============== ================ ================ ================== Long-Term Debt and Obligated Mandatorily Redeemable Preferred Trust Securities $ 1,796,839 $ 1,116,656 $ 1,119,876 $ 1,089,099 $ 1,014,311 =============== =============== ================ ================ ================== Dividends Declared - Common Stock $ 33,000 $ 64,000 $ 72,000 $ 73,715 $ 79,177 =============== =============== ================ ================ ================== |
The table below, for the years ended December 31, 1998 and 1997, includes information for SPPC's water business disposed of in 2001.
Year ended December 31, (dollars in thousands) ---------------------------------------------------------------------------------------- 2001 2000 1999 1998 1997 ---- ---- ---- ---- ---- Operating Revenues $ 1,544,786 $ 994,585 $ 709,374 $ 685,189 $ 657,540 =============== =============== ================ ================ ================== Operating Income $ 78,968 $ 47,135 $ 112,703 $ 114,263 $ 120,172 =============== =============== ================ ================ ================== Net Income (Loss) from Continuing Operations $ 19,043 $ (7,576) $ 59,658 $ 79,678 $ 77,668 =============== =============== ================ ================ ================== Total Assets $ 2,685,907 $ 2,208,389 $ 2,084,707 $ 2,011,820 $ 1,912,242 =============== =============== ================ ================ ================== Long-Term Debt and Obligated Mandatorily Redeemable Preferred Trust Securities $ 923,070 $ 654,316 $ 673,930 $ 654,950 $ 655,389 =============== =============== ================ ================ ================== Dividends Declared - Common Stock $ 63,000 $ 85,000 $ 76,000 $ 76,000 $ 72,000 =============== =============== ================ ================ ================== |
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The information in this Form 10-K includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. These forward-looking statements relate to anticipated financial performance, management's plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters. Words such as "anticipate," "believe," "estimate," "expect," "intend," "plan" and "objective" and other similar expressions identify those statements that are forward-looking. These statements are based on management's beliefs and assumptions and on information currently available to management. Actual results could differ materially from those contemplated by the forward-looking statements. In addition to any assumptions and other factors referred to specifically in connection with such statements, factors that could cause the actual results of Sierra Pacific Resources (SPR), Nevada Power Company (NPC), or Sierra Pacific Power Company (SPPC) to differ materially from those contemplated in any forward-looking statement include, among others, the following:
(1) unfavorable rulings in rate cases previously filed and to be filed by NPC and SPPC (the "Utilities") with the Public Utilities Commission of Nevada (PUCN), including the periodic applications authorized by recent Nevada legislation to permit the Utilities to recover costs for fuel and purchased power that have been recorded by the Utilities in their deferred energy accounts and deferred natural gas recorded by SPPC for its gas distribution business;
(2) the ability of SPR, NPC and SPPC to access the capital markets to support their requirements for working capital, including amounts necessary to finance deferred energy costs, construction costs and the repayment of maturing debt, particularly in the event of unfavorable rulings by the PUCN and/or a downgrade of the existing debt ratings of SPR, NPC or SPPC;
(3) whether the PUCN will issue favorable orders in a timely manner to permit the Utilities to borrow money and issue additional securities to finance the Utilities' operations and to purchase power and fuel necessary to serve their respective customers;
(4) the extent to which volatile energy prices and the financial difficulties of electric utilities and power exchanges in the western United States cause any counterparties to the Utilities' purchased power contracts to default on their obligations, thus requiring the Utilities to seek to replace the power on the spot market;
(5) the effect of price controls promulgated in June 2001 by the Federal Energy Regulatory Commission ("FERC") on the price at which the Utilities can sell excess power in the wholesale markets;
(6) the effect that any future terrorist attacks may have on the tourism and gaming industries in Nevada, particularly in Las Vegas, as well as on the economy in general;
(7) the effect of existing or future Nevada, California or federal legislation or regulations affecting electric industry restructuring, including laws or regulations which could allow certain customers to choose new electricity suppliers;
(8) unseasonable weather and other natural phenomena, which can have potentially serious impacts on the Utilities' ability to procure adequate supplies of fuel or purchased power to serve their respective customers and on the cost of procuring such supplies;
(9) industrial, commercial and residential growth in the service territories of the Utilities;
(10) the loss of any significant customers;
(11) changes in the business of major customers, including those engaged in gold mining or gaming, which may result in changes in the demand for services of the Utilities;
(12) changes in environmental regulations, tax or accounting matters or other laws and regulations to which the Utilities are subject;
(13) future economic conditions, including inflation rates and monetary policy;
(14) financial market conditions, including changes in availability of capital or interest rate fluctuations;
(15) unusual or unanticipated changes in normal business operations, including unusual maintenance or repairs; and
(16) employee workforce factors, including changes in collective bargaining unit agreements, strikes or work stoppages.
Other factors and assumptions not identified above may also have been involved in deriving these forward-looking statements, and the failure of those other assumptions to be realized, as well as other factors, may also cause actual results to differ materially from those projected. SPR, NPC and SPPC assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking statements.
CRITICAL ACCOUNTING POLICIES
The following items represent critical accounting policies that under different conditions or using different assumptions could have a material effect on the financial condition, liquidity and capital resources of SPR and the Utilities.
Regulatory Accounting
The Utilities' rates are currently subject to the approval of the PUCN and are designed to recover the cost of providing generation, transmission and distribution services. As a result, the Utilities qualify for the application of Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation", issued by the Financial Accounting Standards Board (FASB). This statement recognizes that the rate actions of a regulator can provide reasonable assurance of the existence of an asset and requires the capitalization of incurred costs that would otherwise be charged to expense where it is probable that future revenue will be provided to recover these costs. SFAS No. 71 prescribes the method to be used to record the financial transactions of a regulated entity. The criteria for applying SFAS No. 71 include the following: (i) rates are set by an independent third party regulator, (ii) approved rates are intended to recover the specific costs of the regulated products or services, and (iii) rates that are set at levels that will recover costs can be charged to and collected from customers.
Deferred Energy Accounting
On April 18, 2001, the Governor of Nevada signed into law Assembly Bill (AB) 369. The provisions of AB 369, which are described in greater detail in "Regulation and Rate Proceedings," later, include, among others, a reinstatement of deferred energy accounting for fuel and purchased power costs incurred by electric utilities. In accordance with the provisions of SFAS No. 71, the Utilities began utilizing deferred energy accounting on March 1, 2001, for their respective electric operations. Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates, that excess is not recorded as a current expense on the income statement but rather is deferred and recorded as an asset on the balance sheet. Conversely, a liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs. These excess amounts are reflected in adjustments to rates and recorded as revenue or expense in future time periods, subject to PUCN review. AB 369 provides that the PUCN may not allow the recovery of any costs for purchased fuel or purchased power "that were the result of any practice or transaction that was undertaken, managed or performed imprudently by the electric utility." In reference to deferred energy accounting, AB 369 specifies that fuel and purchased power costs include all costs incurred to purchase fuel, to purchase capacity, and to purchase energy. The Utilities also record, and are eligible to recover, a carrying charge on such deferred balances.
If not for deferred energy accounting during 2001, SPR's, NPC's and SPPC's results of operations, financial condition, liquidity and capital resources would have been materially adversely affected. For example, without the deferred energy accounting provisions of AB 369, the 2001 reported net income of SPR, NPC and SPPC of $56.7 million, $63.4 million/1/ and $45.9 million would have been (net of income tax) reported as net losses of ($715.4) million, ($573.6) million/1/ and ($89.1) million, respectively. In addition, a significant disallowance by the PUCN of costs currently deferred would have a material adverse affect on the future results of operations of SPR, NPC and SPPC. See "Regulation and Rate Proceedings," later, for a more detailed discussion of deferred energy accounting, including the regulatory process underway to recover these deferred costs.
Derivatives and Hedging Activities
Effective January 1, 2001, SPR, SPPC, and NPC adopted SFAS No. 133, "Accounting for Derivative Instruments and Hedging Activities," as amended by SFAS No. 138. As amended, SFAS No. 133 requires that an entity recognize all derivative instruments as either assets or liabilities in the statement of financial position and measure the instruments at fair value.
In order to manage loads, resources and energy price risk, the Utilities buy fuel and power under forward contracts. In addition to forward fuel and power purchase contracts, the Utilities also use options and swaps to manage price risk. All of these instruments are considered to be derivatives under SFAS No. 133. The risk management assets and liabilities recorded in the balance sheets of the Utilities and SPR are primarily comprised of the fair value of these forward fuel and power purchase contracts and other energy related derivative instruments.
With the reinstatement of deferred energy accounting pursuant to AB 369, prudently incurred fuel and purchased power costs are expected to be recoverable through future rates. Accordingly, the energy related risk management assets and liabilities and the corresponding unrealized gains and losses (changes in fair value) are offset with a regulatory asset or liability rather than recognized in the statements of income and comprehensive income. Upon settlement of the derivative instrument, actual fuel and purchased power costs are recognized or deferred to the extent they are recoverable or payable through future rates.
The fair values of the forward contracts and swaps are determined based on quotes obtained from independent brokers and exchanges. The fair values of options are determined using a pricing model which incorporates assumptions such as the underlying commodity's forward price curve, time to expiration, strike price, interest rates, and volatility. The use of different assumptions and variables in the model could have a significant impact on the valuation of the instruments.
SPR and the Utilities have other non-energy related derivative instruments such as interest rate swaps. The transition adjustment resulting from the adoption of SFAS No. 133 related to these types of derivative instruments was reported as the cumulative effect of a change in accounting principle in Other Comprehensive Income. Additionally, the changes in fair values of these non-energy related derivatives are also reported in the statements of comprehensive income until the related transactions are settled or terminate, at which time the amounts will be reclassified into earnings. No amounts were reclassified into earnings during 2001.
See Note 22 of "Notes to Financial Statements" for additional information regarding derivatives and hedging activities.
Provision for Uncollectible Accounts
The Utilities reserve for doubtful accounts based on past experience writing off uncollectible customer accounts. The collapse of the energy markets in California, and the subsequent bankruptcy of the California Power Exchange and the financial difficulties of the Independent System Operator, resulted in the Utilities reserving for outstanding receivables for power purchases by these two entities of $19.9 million and $1.5 million (before taxes) for NPC and SPPC, respectively. The weakening economy and the disruption to the leisure travel industry after September 11th also impacted the Utilities' customer delinquencies in 2001. Additional amounts of $14.8 million and $6.1 million were reserved for delinquent retail customer accounts of NPC and SPPC, respectively. The adequacy of these reserves will vary to the extent that future collections differ from past experience. Uncollectible retail customer accounts amounting to $5.6 million and $2.5 million respectively, for NPC and SPPC, were written off against this provision in 2001. Significant collection efforts are underway to recover portions of the rest of the delinquent accounts.
MAJOR FACTORS AFFECTING RESULTS OF OPERATIONS
As discussed in the results of operations sections that follow, operating results for 2001 were affected by the high and extremely volatile fuel and purchased power costs that developed in the western United States in 2000 and continued into 2001, and by several responsive legislative and regulatory actions.
In an effort to mitigate the effects of higher fuel and purchased power costs, in July 2000, the Utilities entered into the Global Settlement with the PUCN, which established a mechanism that initiated incremental rate increases for each Utility. Cumulative electric rate increases under the Global Settlement were $127 million and $65 million per year, respectively, for the Utilities.
However, because the rate adjustment mechanism of the Global Settlement was subject to certain caps and could not keep pace with the continued escalation of fuel and purchased power prices, on January 29, 2001, the Utilities filed a Comprehensive Energy Plan (CEP) with the PUCN. The CEP included a request for emergency rate increases (CEP Riders). On March 1, 2001, the PUCN permitted the requested CEP Riders to go into effect subject to later review. The CEP Riders provided further rate increases of $210 million and $104 million per year, respectively, for NPC and SPPC.
Notwithstanding the increases under the Global Settlement and the CEP Riders, the Utilities' revenues for fuel and purchased power recovery continued to be less than the related expenses. Accordingly, the Utilities sought additional relief pursuant to legislation.
On April 18, 2001, the Governor of Nevada signed into law AB 369. The provisions of AB 369, which are described later in greater detail in "Regulation and Rate Proceedings," include a moratorium on the sale of generation assets by electric utilities until 2003, the repeal of electric industry restructuring, and, beginning March 1, 2001, a reinstatement of deferred energy accounting for fuel and purchased power costs incurred by electric utilities. The stated purposes of this emergency legislation included, among others, to control volatility in the price of electricity in the retail market in Nevada and to ensure that the Utilities have the necessary financial resources to provide adequate and reliable electric service under present market conditions.
As discussed above in "Critical Accounting Policies," deferred energy accounting allows the Utilities an opportunity to recover in future periods that portion of their costs for fuel and purchased power not covered by current rates and defers to future periods the expense associated with the amounts by which fuel and purchased power costs exceed the costs to be recovered in current rates. Recovery is subject to PUCN review as to prudency and other matters.
AB 369 requires each Utility to file general rate applications and deferred energy applications with the PUCN by specific dates. NPC's deferred energy application, filed on November 30, 2001, seeks to establish a Deferred Energy Accounting Adjustment ("DEAA") rate to clear accumulated purchased fuel and power costs of $922 million and spread the cost recovery over a not more than three-year period resulting in a net increase of 21%. The decision of the PUCN on NPC's deferred energy application is to take effect on April 1, 2002. SPPC's deferred energy application, filed on February 1, 2002, seeks to establish a DEAA rate to clear accumulated purchased fuel and power costs of $205 million and spread the cost recovery over a not more than three-year period resulting in a net increase of 9.8%. The PUCN decision on SPPC's deferred energy application is to take effect on June 1, 2002. See "Regulation and Rate Proceedings," later, for a discussion of the Utilities' general rate case filings.
The decisions of the PUCN on the Utilities' deferred energy applications are expected to have a significant effect on the results of operations of SPR, NPC, and SPPC in 2002 and subsequent periods, and may have a material effect on the financial condition, liquidity, and capital resources of SPR, NPC, and SPPC. In particular, to the extent that the PUCN finds that any amount included in either Utility's deferred account was imprudently incurred, the PUCN will not permit that amount to be recovered through higher rates, and an equivalent amount of the Utility's deferred energy costs asset will be required to be written off. Such a write-off could cause a substantial loss to be incurred by the Utility, could cause its securities to be downgraded by the rating agencies and could make it significantly more difficult to finance the operations of the Utility and to buy fuel and purchased power from third parties. In the event that a significant amount of the Utilities' deferred energy costs are disallowed by the PUCN, there can be no assurance that SPR, NPC, or SPPC will be able to remain solvent.
As discussed in greater detail in "Regulation and Rate Proceedings," on June 19, 2001, the FERC adopted a price mitigation plan applicable to spot market wholesale power sales in California and throughout the western United States during the period June 20, 2001 through September 30, 2002. The price mitigation plan established a mechanism with which to determine the maximum amount that may be charged for power sold during this period. Although the Utilities are not able to predict at this time the long-term effect that the FERC price mitigation plan and other market developments may have on their results of operations, management believes that, under certain market conditions, the FERC plan adversely affects the availability of spot market power to the Utilities and reduces the price at which the Utilities can sell power on the wholesale market. Another potential result from these price mitigation measures could be the delay and/or cancellation of proposed power plants throughout the western United States. If these results occur, the long-term supply of energy could be reduced. Numerous parties, including NPC and several northwest utilities, appealed the FERC order to the District of Columbia Court of Appeals on the basis that the price caps are unfair to electric customers who reside outside of California. The parties to the appeal await action by the Court.
Results of Operations
SPR earned $56.7 million for the year ended December 31, 2001, compared to a net loss of ($39.8) million in 2000, and net income of $51.8 million in 1999. NPC and SPPC, SPR's principal subsidiaries, declared common stock dividends to their parent, SPR, of $33 million and $63 million, respectively. SPPC also declared $3.9 million in dividends to holders of its preferred stock.
Liquidity and Capital Resources (SPR Consolidated)
SPR's net cash flows during 2001 were comparable to 2000. An increase in net cash flows used for operating activities was offset by a decrease in cash used for investing activities and an increase in cash provided from financing activities. The increase in cash used in operating activities resulted substantially from the payment of higher energy and natural gas costs. The decrease in cash used for investing activities resulted from the sale of SPPC's water business. The increase in cash provided from financing activities resulted from a reduction in net retirements of short-term debt and proceeds from the sale of common stock. Cash provided by financing activities was substantially utilized for the payment of higher energy costs in 2001. See Notes 7 (Common Stock and Other Paid-in Capital) and 12 (Short-Term Borrowings) for detailed financing information.
SPR's net cash flows increased in 2000 compared to 1999. The net increase in cash resulted from less cash used in investing activities offset substantially by decreases in cash from operating and financing activities. The decrease in cash flows used in investing activities is due to the merger cash requirements included in the 1999 amounts. Cash flows from operating activities were less in 2000 due primarily to a decrease in operating income and an increase in accounts receivable, offset, in part, by increases in accounts payable and depreciation and amortization. Cash flows from financing activities decreased in 2000 compared to 1999 because most of the cash provided by long-term debt issued in 2000 was utilized to retire short-term borrowings and other long-term debt. See Notes 9 (Long Term-Debt) and 12 (Short-Term Borrowings) for detailed financing information.
Since SPR is a holding company, substantially all of its cash flow is provided by dividends paid to SPR by NPC and SPPC on their common stock, all of which is owned by SPR. Since these two subsidiaries are public utilities, they are subject to regulation by state utility commissions which may impose limits on investment returns or otherwise impact the amount of dividends which may be paid by those companies. Moreover, the Articles of Incorporation of SPPC contain restrictions on the payment of dividends on SPPC's common stock in the event of a default in the payment of dividends on SPPC's preferred stock. Similarly, the Credit Agreements of NPC and SPPC prohibit the payment of dividends on each company's common stock if that company is in default under the terms of the relevant credit facility. Finally, the terms of certain outstanding series of first mortgage bonds of both NPC and SPPC limit the cumulative amount of dividends that may be paid on each company's common stock to the cumulative net earnings of that company over an extended period of time. Any of these provisions which potentially restrict dividends payable by NPC or SPPC could adversely affect liquidity at the SPR level.
In addition to the liquidity provided by dividends from its subsidiaries, SPR maintains $75 million of short-term liquidity capacity at the holding company level in the form of a Credit Agreement with the same bank group that has entered into Credit Agreements with NPC and SPPC. This facility matures on November 28, 2002 and may be used to provide liquidity for general corporate purposes including to back up a commercial paper program, although SPR does not currently maintain a commercial paper program. The Credit Agreement contains a number of restrictive covenants including restrictions on liens, sales of assets and mergers or sale and leaseback transactions by SPR or its subsidiaries. The Credit Agreement also contains financial covenants requiring that SPR maintain:
. a ratio of (i) Total Indebtedness to (ii) the sum of Total Indebtedness and
Shareholders Equity that does not exceed 0.65:1 as of the last day of each
fiscal quarter.
. a Consolidated Interest Coverage Ratio of not less than 1.5 to 1 calculated
as of the last day of each fiscal quarter for the preceding four consecutive
fiscal quarters.
As of December 31, 2001, SPR was in compliance with these financial covenants.
The borrowing costs under the Credit Agreement are at a variable interest rate consisting of a spread over LIBOR or an alternate base rate that is based upon a pricing grid tied to the credit rating on SPR's senior unsecured long-term debt. SPR had no borrowings outstanding under the Credit Agreement as of December 31, 2001. On or before the maturity date of the Credit Agreement, SPPC currently intends to either renew or replace the Credit Agreement.
Like the Credit Agreements for NPC and SPPC, SPR's Credit Agreement is unsecured. However, SPR's Credit Agreement does not require the issuance of collateral to the banks in the event that the credit rating on SPR's long-term unsecured debt is downgraded.
Construction Expenditures and Financing (SPR Consolidated)
The table below provides SPR's consolidated cash construction expenditures and internally generated cash, net for 1999 through 2001 (dollars in thousands):
2001 2000 1999 Total -------------- ----------- ---------- ------------- Cash construction expenditures $ 302,875 $328,990 $729,794 $1,361,659 ============== =========== ========== ============= Net cash flow from operating activities $ (1,045,221) $185,896 $211,089 $ (648,236) Less common & preferred cash dividends 64,917 83,057 115,833 263,807 -------------- ----------- ---------- ------------- Internally generated cash $ (1,110,138) 102,839 95,256 (912,043) ============== =========== ========== ============= Internally generated cash as a percentage of cash construction expenditures Not Applicable 31% 13% Not Applicable |
* 1999 cash construction expenditures include $448.3 million of merger related costs.
SPR's estimated cash construction expenditures for 2002 through 2006 are $1.7 billion. Construction expenditures for 2002 (approximately $470 million) will be financed through debt issuance and internally generated funds, including recovery of deferred energy. It is anticipated that the Utilities will pay all of their net income in dividends to SPR. SPR anticipates capital contributions of $16 million to NPC and $60 million to SPPC in 2002. SPPC will utilize proceeds from the issuance of short-term debt and parent contributions to fund construction.
Cash provided by internally generated funds during 2002 assumes full recovery of deferred energy costs over three years for NPC and SPPC. SPR also assumes general rate increases approved as filed effective at the beginning of the second quarter and mid-year for NPC and SPPC, respectively. To the extent that the PUCN finds that any of the Utilities' deferred energy costs resulted from imprudent purchases, the PUCN will not permit that amount to be recovered through higher rates, and an equivalent amount of the Utilities' deferred energy cost asset will be required to be written off. A material write-off of deferred energy costs would have a material adverse affect on the future results of operations of SPR and the Utilities and could cause their securities to be downgraded by the rating agencies and make it significantly more difficult to finance operations, and buy fuel and purchased power from third parties.
If SPR does not receive substantial recovery of deferred energy costs for the Utilities, depending upon the extent of the disallowance, the rating agencies might downgrade SPR and its subsidiaries. A downgrade by one or more of the national rating agencies of the credit rating for the debt of SPR, NPC or SPPC would affect the companies' liquidity primarily in two principal areas: (1) their respective financing arrangements and (2) NPC's and SPPC's contracts for fuel, for purchase and sale of electricity and for transportation of natural gas.
With respect to the financing arrangements, in the event that either NPC's or SPPC's commercial paper programs are downgraded, the downgraded issuer would no longer be able to issue commercial paper, thereby requiring the issuer to draw upon its back-up credit facility to pay off outstanding commercial paper balances. With respect to other financing arrangements, a downgrade in and of itself would not trigger an event of default or otherwise accelerate the payment obligations under any of SPR's, NPC's or SPPC's financing agreements. However, the bank Credit Agreements of NPC and SPPC include a "springing lien" feature, pursuant to which NPC or SPPC would be required, in the event that the company's senior unsecured debt is downgraded, to issue General and Refunding Mortgage bonds to the banks in an amount equal to the aggregate principal amount of the commitments under the facilities. If the springing lien were triggered for NPC, NPC would likely be obligated, under a negative pledge clause applicable to its senior unsecured notes, to issue an additional $130 million of General and Refunding Bonds as collateral for those securities.
With respect to NPC's and SPPC's contracts for purchased power, NPC and SPPC purchase and sell electricity with their counterparties under the Western Systems Power Pool ("WSPP") agreement, which is an industry standard contract. The WSPP contract is posted on the WSPP website. These contracts provide that a material adverse change may trigger a request for collateral, which, if not provided within 3 business days, may trigger a default. A request for collateral must be exercised within 30 days of the event becoming known. A default will result in a termination payment equal to the present value of the net gains and losses aggregated to a single liquidated amount due within 3 business days following the date the notice of termination is received. The mark to market value can be used to roughly approximate the termination payment at any point in time.
With respect to the purchase and sale of natural gas, NPC and SPPC use several types of contracts. Standard industry sponsored agreements include: (1) the Gas Industry Standards Board ("GSIB") agreement which is used for physical gas transactions, (2) the GasEDI Base Contract for Short Term Sale and Purchase of Natural Gas which is also used for physical gas transactions, or (3) the International Swap Dealers Association (ISDA) agreement which is used for financial gas transactions. Alternatively, the gas transactions might be governed by a non-standard bilateral master agreement negotiated between the parties, or by the confirmation associated with the transaction. The natural gas contract terms and conditions are more varied than the electric contracts. Consequently, some of the contracts do not contain rating downgrade triggers and some contain language similar to that found in the WSPP agreement.
Gas transmission services are provided under the FERC Gas Tariff or a custom agreement. These contracts require the entities to establish and maintain creditworthiness to obtain service.
Contractual Obligations (SPR Consolidated)
The table below provides SPR's consolidated contractual obligations, not including estimated construction expenditures described above, as of December 31, 2001, that SPR expects to satisfy through a combination of internally generated cash and, as necessary, through the issuance of short-term and long-term debt (dollars in thousands):
Payments Due By Period 2002 2003 2004 2005 2006 Thereafter Total ------------- ------------------------------------------------------------------------------- Long- Term Debt (1) $ 299,010 $ 570,632 $ 132,621 $ 302,622 $ 52,629 $ 2,317,601 $ 3,675,115 Purchased Power 1,348,451 152,852 151,627 136,680 137,446 777,064 2,704,120 Coal and Natural Gas 367,373 126,027 129,482 96,671 94,299 725,651 1,539,503 Capital Lease Obligations 6,156 6,156 6,946 7,736 7,736 58,016 92,746 Operating Leases 12,127 9,284 8,194 7,289 6,863 63,463 107,220 Other Long-Term Obligations 300 300 ------------- ------------ ------------ ----------- ----------- -------------- ------------ Total Contractual Cash Obligations $ 2,033,417 $ 864,951 $ 428,870 $ 550,998 $ 298,973 $ 3,941,795 $ 8,119,004 ============= ============ ============ =========== =========== ============== ============ |
(1) Includes short-term debt of $177,000.
Capital Structure (SPR Consolidated)
SPR's actual consolidated capital structure at December 31, 2001, and 2000 was as follows (dollars in thousands):
2001 2000 ------------------------- ----------------------- Short-Term Debt (1) $ 299,010 6% $ 685,601 15% Long-Term Debt 3,376,105 57% 2,133,679 48% Preferred Stock 50,000 1% 50,000 1% Preferred Trust Securities 188,872 4% 237,372 5% Common Equity 1,702,322 32% 1,359,712 31% ------------------------- -------------------------- TOTAL $5,616,309 100% $ 4,466,364 100% ========================= ========================== |
(1) Including current maturities of long-term debt. Included in amounts above for Long-Term Debt is $600 million of SPR holding company debt.
The merger between SPR and NPC was accounted for as a reverse purchase under generally accepted accounting principles, with NPC considered the acquiring entity, even though SPR became the legal parent of NPC. For accounting purposes, the merger was deemed to have occurred on August 1, 1999. As a result of this reverse purchase accounting treatment: (i) the historical financial statements of SPR for periods prior to the date of the merger are no longer the financial statements of SPR, and therefore, are no longer presented; (ii) the historical financial statements of SPR for periods prior to the date of the merger are those of NPC; (iii) based on a merger date of August 1, 1999, the Consolidating Statements of Income for the twelve months ended December 31, 1999, include five months (August through December 1999) of operating activity for SPR and its subsidiaries other than NPC and include the operating results of NPC for the entire periods presented; and (iv) each of the Consolidating Statements of Income for the twelve months periods ended December 31, 2001 and 2000, include twelve months of operating activity for SPR and its subsidiaries.
SIERRA PACIFIC RESOURCES CONSOLIDATING STATEMENTS OF INCOME
(Dollars in Thousands)
Year Ended December 31, 2001 ---------------------------------------------------------- 12 months 12 months 12 months NPC SPPC Other Total ---------------------------- --------------------------- OPERATING REVENUES: Electric $ 3,025,103 $ 1,399,134 $ - $ 4,424,237 Gas 145,652 - 145,652 Other - - 18,841 18,841 ------------- -------------- ------------ -------------- 3,025,103 1,544,786 18,841 4,588,730 ------------- -------------- ------------ -------------- OPERATING EXPENSES: Operation: Purchased power 3,026,336 1,025,741 - 4,052,077 Fuel for power generation 441,900 286,719 - 728,619 Gas purchased for resale - 136,534 - 136,534 Deferral of energy costs-electric-net (937,322) (198,826) - (1,136,148) Deferral of energy costs-gas-net - (23,170) - (23,170) Other 169,442 117,627 44,892 331,961 Maintenance 45,136 24,363 - 69,499 Depreciation and amortization 93,101 70,358 1,181 164,640 Taxes: - Income taxes 17,775 8,507 (27,512) (1,230) Other than income 24,371 17,965 743 43,079 ------------- -------------- ------------ -------------- 2,880,739 1,465,818 19,304 4,365,861 ------------- -------------- ------------ -------------- OPERATING INCOME 144,364 78,968 (463) 222,869 ------------- -------------- ------------ -------------- OTHER INCOME: Allowance for other funds used during construction (382) 856 - 474 Other income - net 27,272 8,489 2,962 38,723 ------------- -------------- ------------ -------------- 26,890 9,345 2,962 39,197 ------------- -------------- ------------ -------------- Total Income Before Interest Charges 171,254 88,313 2,499 262,066 ------------- -------------- ------------ -------------- INTEREST CHARGES: Long-term debt 81,599 55,199 51,572 188,370 Other 13,219 7,433 3,509 24,161 Allowance for borrowed funds used during construction and capitalized interest (2,141) (660) - (2,801) ------------- -------------- ------------ -------------- 92,677 61,972 55,081 209,730 ------------- -------------- ------------ -------------- INCOME (LOSS) BEFORE SPPC/NPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 78,577 26,341 (52,582) 52,336 Preferred dividend requirements of obligated mandatorily redeemable preferred trust securities (15,172) (3,598) - (18,770) ------------- -------------- ------------ -------------- INCOME (LOSS) BEFORE PREFERRED STOCK DIVIDENDS 63,405 22,743 (52,582) 33,566 Preferred stock dividend requirements - (3,700) - (3,700) ------------- -------------- ------------ -------------- INCOME (LOSS) FROM CONTINUING OPERATIONS 63,405 19,043 (52,582) 29,866 INCOME FROM DISCONTINUED OPERATIONS - 1,022 - 1,022 GAIN ON DISPOSAL OF WATER BUSINESS - 25,845 - 25,845 ------------- -------------- ------------ -------------- NET INCOME (LOSS) $ 63,405 $ 45,910 $ (52,582) $ 56,733 ============= ============== ============ ============== |
SIERRA PACIFIC RESOURCES CONSOLIDATING STATEMENTS OF INCOME
(Dollars in Thousands)
Year Ended December 31, 2000 ---------------------------------------------------------- 12 months 12 months 12 months NPC SPPC Other Total ---------------------------- ----------------------------- OPERATING REVENUES: Electric $ 1,325,470 $ 893,782 $ - $ 2,219,252 Gas 100,803 - 100,803 Other - - 14,199 14,199 ------------- -------------- -------------- -------------- 1,325,470 994,585 14,199 2,334,254 ------------- -------------- -------------- -------------- OPERATING EXPENSES: Operation: Purchased power 671,396 444,979 - 1,116,375 Fuel for power generation 292,787 233,748 - 526,535 Gas purchased for resale - 83,199 - 83,199 Deferral of energy costs-electric-net 16,719 - - 16,719 Deferral of energy costs-gas-net - (16,164) - (16,164) Other 139,723 96,438 24,335 260,496 Maintenance 34,057 18,420 - 52,477 Depreciation and amortization 85,989 69,350 696 156,035 Taxes: Income taxes (12,162) (672) (18,188) (31,022) Other than income 23,501 18,152 562 42,215 ------------- -------------- -------------- -------------- 1,252,010 947,450 7,405 2,206,865 ------------- -------------- -------------- -------------- OPERATING INCOME 73,460 47,135 6,794 127,389 ------------- -------------- -------------- -------------- OTHER INCOME: Allowance for other funds used during construction 2,456 357 - 2,813 Other income (expense) - net 1,718 (2,429) 3,357 2,646 ------------- -------------- -------------- -------------- 4,174 (2,072) 3,357 5,459 ------------- -------------- -------------- -------------- Total Income Before Interest Charges 77,634 45,063 10,151 132,848 ------------- -------------- -------------- -------------- INTEREST CHARGES: Long-term debt 64,513 36,865 33,218 134,596 Other 13,732 11,312 10,843 35,887 Allowance for borrowed funds used during construction and capitalized interest (7,855) (2,779) - (10,634) ------------- -------------- -------------- -------------- 70,390 45,398 44,061 159,849 ------------- -------------- -------------- -------------- INCOME (LOSS) BEFORE SPPC/NPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 7,244 (335) (33,910) (27,001) Preferred dividend requirements of obligated mandatorily redeemable preferred trust securities (15,172) (3,742) - (18,914) ------------- -------------- -------------- -------------- (LOSS) BEFORE PREFERRED STOCK DIVIDENDS (7,928) (4,077) (33,910) (45,915) Preferred stock dividend requirements - (3,499) - (3,499) ------------- -------------- -------------- -------------- (LOSS) FROM CONTINUING OPERATIONS (7,928) (7,576) (33,910) (49,414) INCOME FROM DISCONTINUED OPERATIONS - 9,634 - 9,634 ------------- -------------- -------------- -------------- NET (LOSS) INCOME $ (7,928) $ 2,058 $ (33,910) $ (39,780) ============= ============== ============== ============== |
SIERRA PACIFIC RESOURCES CONSOLIDATING STATEMENTS OF INCOME
(Dollars in Thousands)
Year Ended December 31, 1999 --------------------------------------------------------- 12 months 5 months 5 months NPC SPPC Other Total --------------------------- ----------------------------- OPERATING REVENUES: Electric $ 977,262 $ 259,440 $ - $ 1,236,702 Gas - 38,958 - 38,958 Other - - 9,132 9,132 ------------- ------------- ------------- --------------- 977,262 298,398 9,132 1,284,792 ------------- ------------- ------------- --------------- OPERATING EXPENSES: Operation: Purchased power 293,600 79,856 - 373,456 Fuel for power generation 154,546 51,584 - 206,130 Gas purchased for resale - 27,262 - 27,262 Deferral of energy costs-electric-net 97,238 - - 97,238 Other 141,041 40,961 11,389 193,391 Maintenance 50,805 8,492 - 59,297 Depreciation and amortization 80,644 29,188 243 110,075 Taxes: Income taxes 19,943 10,602 (5,247) 25,298 Other than income 22,462 7,232 90 29,784 ------------- ------------- ------------- --------------- 860,279 255,177 6,475 1,121,931 ------------- ------------- ------------- --------------- OPERATING INCOME 116,983 43,221 2,657 162,861 ------------- ------------- ------------- --------------- OTHER INCOME: Allowance for other funds used during construction 3,713 (1,374) - 2,339 Other (expense) income - net (1,824) (853) 352 (2,325) ------------- ------------- ------------- --------------- 1,889 (2,227) 352 14 ------------- ------------- ------------- --------------- Total Income Before Interest Charges 118,872 40,994 3,009 162,875 ------------- ------------- ------------- --------------- INTEREST CHARGES: Long-term debt 64,454 12,741 299 77,494 Other 8,815 5,885 11,529 26,229 Allowance for borrowed funds used during construction and capitalized interest (8,356) 356 - (8,000) ------------- ------------- ------------- --------------- 64,913 18,982 11,828 95,723 ------------- ------------- ------------- --------------- INCOME (LOSS) BEFORE SPPC/NPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 53,959 22,012 (8,819) 67,152 Preferred dividend requirements of obligated mandatorily redeemable preferred trust securities (15,172) (1,570) - (16,742) ------------- ------------- ------------- --------------- INCOME (LOSS) BEFORE PREFERRED STOCK DIVIDENDS 38,787 20,442 (8,819) 50,410 Preferred stock dividend requirements (95) (2,105) - (2,200) ------------- ------------- ------------- --------------- INCOME (LOSS) FROM CONTINUING OPERATIONS 38,692 18,337 (8,819) 48,210 INCOME FROM DISCONTINUED OPERATIONS - 3,540 - 3,540 ------------- ------------- ------------- --------------- NET INCOME (LOSS) $ 38,692 $ 21,877 $ (8,819) $ 51,750 ============= ============= ============= =============== |
Results of Operations
NPC earned net income of $63.4 million in 2001, compared to a net loss of ($7.9) million in 2000, and 1999 net income before dividend requirements on preferred stock of $38.8 million. These amounts do not include NPC's equity in the earnings (losses) of SPR. The causes for significant changes in specific lines comprising the results of operations for NPC for the respective years ended are provided below (dollars in thousands except for amounts per unit):
Electric Operating Revenue
2001 2000 1999 ---------------------------- ----------------------------- ------------- Change from Change from Amount Prior year Amount Prior year Amount ------------- ------------- ------------- ------------- ------------- Electric Operating Revenues: Residential $ 644,875 31.0% $ 492,365 18.3% $ 416,345 Commercial 302,682 32.9% 227,790 13.8% 200,186 Industrial 447,766 37.0% 326,916 12.6% 290,409 ------------- ------------- ------------- Retail revenues 1,395,323 33.3% 1,047,071 15.5% 906,940 Other 1,629,780 485.4% 278,399 295.9% 70,322 ------------- ------------- ------------- Total Revenues $ 3,025,103 128.2% $ 1,325,470 35.6% $ 977,262 ============= ============= ============= Total retail sales (MWh) 16,799,000 2.7% 16,363,000 12.0% 14,615,000 Average retail revenue per MWh $ 83.06 29.8% $ 63.99 3.1% $ 62.06 |
NPC's retail revenues increased in 2001 due to a combination of customer growth, and rate increases resulting from the Global Settlement and Comprehensive Energy Plan (CEP) (see Major Factors Affecting Results Of Operations, earlier). The number of residential, commercial, and industrial customers increased over the prior year by 4.8%, 4.4% and 6.5%, respectively. As a result of the CEP, a rate increase of 17% for retail customers became effective March 1, 2001. Substantially all of the increase in Other electric revenues was due to the sale of wholesale electric power to other utilities. NPC's increase in wholesale sales compared to 2000 was a result of market conditions and NPC's power procurement activities. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
NPC's retail revenues increased in 2000 due to a combination of customer growth, warmer than normal weather, and rate increases resulting from the Global Settlement. The number of residential, commercial, and industrial customers increased over the prior year by 5.6%, 4.6% and 7.4%, respectively. As a result of the Global Settlement, NPC implemented monthly rate increases starting August 1, 2000. Other electric revenues were higher in 2000 compared to 1999 due to increased sales of wholesale electric power to other utilities. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
Purchased Power
2001 2000 1999 ----------------------------- ---------------------------- ------------- Change from Change from Amount Prior year Amount Prior year Amount -------------- ------------- ------------ ------------- ------------- Total purchased power $ 3,026,336 350.8% $ 671,396 98.1% $ 338,972 Less imputed capacity deferral - - - - (45,372) -------------- ------------- ------------- Purchased Power $ 3,026,336 350.8% $ 671,396 128.7% $ 293,600 ============== ============= ============= Purchased power MWh 19,268,305 99.5% 9,659,118 22.9% 7,861,985 Average cost per MWh of purchased power $ 157.06 126.0% $ 69.51 61.2% $ 43.12 |
NPC's purchased power costs were significantly higher in 2001 due to substantial increases in prices and volumes. Per unit costs of power increased 126% primarily due to higher Short-Term Firm energy prices. These price increases were the result of much higher fuel costs, combined with increased demand and limited power supplies. Volumes purchased rose 100% to accommodate increases in system load of approximately 2.7% and increases in wholesale sales of approximately 310%. Purchases associated with risk management activities, which include transactions entered into for hedging purposes and to optimize purchased power costs, are included in the purchased power amounts. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
Purchased power costs were higher in 2000 as compared to 1999 due to a 23% increase in the volume purchased and an increase in the per unit cost of power of 61%.
Fuel for Power Generation
2001 2000 1999 ---------------------------- ----------------------------- ------------- Change from Change from Amount Prior year Amount Prior year Amount ------------- ------------- ------------- ------------- ------------- Fuel for Power Generation $ 441,900 50.9% $ 292,787 89.4% $ 154,546 MWhs generated 9,899,195 -7.9% 10,744,466 17.2% 9,167,963 Average fuel cost per MWh of generated power $ 44.64 63.8% $ 27.25 61.6% $ 16.86 |
NPC's 2001 fuel expense increased over 50% compared to 2000 primarily due to a substantial increase in natural gas prices, offset in part, by decreased generation late in 2001 when the cost of purchased power was more economical than generation. In 2000, NPC's fuel expense increased 89% compared to 1999 primarily due to a substantial increase in natural gas prices.
Deferral of Energy Costs - Net
2001 2000 1999 --------------------------- -------------------------- --------- Change from Change from Amount Prior year Amount Prior year Amount ----------- -------------- ---------- -------------- ---------- Deferral of energy costs-electric-net $ (937,322) N/A $ 16,719 -82.8% $ 97,238 |
NPC recorded a significant Deferral of energy costs-net in 2001 due to the implementation of deferred energy accounting beginning March 1, 2001. The current year amounts reflect the extent to which actual fuel and purchased power costs exceeded the fuel and purchased power costs recovered through current rates. Deferral of energy costs-net for 2000 represents energy costs that had been deferred in prior periods and were then recovered in 2000, as a result of deferred energy rate increases granted in 1999.
Deferral of energy costs-net decreased in 2000 compared to 1999 because NPC discontinued deferred energy cost accounting effective August 1, 2000, pursuant to the July 2000 Global Settlement with the PUCN, and because of decisions, described below, by the PUCN affecting 1999's Deferral of energy costs-net. For more information on the Global Settlement, see Major Factors Affecting Results Of Operations, earlier.
In February and March 2000, the PUCN issued orders that rejected NPC's requested rate relief in its 1999 deferred energy filings. As a result of these decisions, a pre-tax charge of $80 million to Deferral of energy costs-net was made in 1999 to write-off deferred energy and imputed capacity costs.
See "Critical Accounting Policies," earlier, and Note 1 of "Notes to Financial Statements" for more information regarding deferred energy accounting.
Allowance For Funds Used During Construction (AFUDC)
2001 2000 1999 -------------------------- --------------------------- ---------- Change from Change from Amount Prior year Amount Prior year Amount ---------- -------------- ---------- --------------- ---------- Allowance for other funds used during construction $ (382) -115.6% $ 2,456 -33.9% $ 3,713 Allowance for borrowed funds used during construction 2,141 -72.7% 7,855 -6.0% 8,356 ------- -------- -------- $ 1,759 -82.9% $ 10,311 -14.6% $ 12,069 ------- -------- -------- |
NPC AFUDC is lower in 2001 because of adjustments to amounts assigned to specific components of facilities that were completed in different periods. In 2000, there was a small decrease in the AFUDC rate compared to 1999 because of an increase in short-term debt.
Other Expenses
2001 2000 1999 ------------------------------ --------------------------- ------------ Change from Change from Amount Prior year Amount Prior year Amount ------------ -------------- ------------ ------------- ------------ Other operating expense $ 169,442 21.3% $ 139,723 -0.9% $ 141,041 Maintenance expense 45,136 32.5% 34,057 -33.0% 50,805 Depreciation and amortization 93,101 8.3% 85,989 6.6% 80,644 Income taxes 17,775 N/A (12,162) -161.0% 19,943 Interest charges on long-term debt 81,599 26.5% 64,513 0.1% 64,454 Interest charges- other 13,219 -3.7% 13,732 55.8% 8,815 Other income (expense)-net 27,272 1487.4% 1,718 -194.2% (1,824) |
Other operating expense increased in 2001 compared to 2000 due to a $16.6 million larger addition to the provision for uncollectible customer accounts than in 2000, reflecting the impact of the weakening economy and disruption to the leisure travel industry after September 11, 2001. Other operating expense also increased due to the addition of $12.6 million to the uncollectible provision related to receivables from the California Power Exchange (PX) and California's Independent System Operator (ISO). NPC's other operating expense for 2000 was $8.8 million lower than 1999 due to reduced labor and benefit costs as a result of merger efficiencies and unfilled vacancies. These savings were offset, in part, by an increase in the provision for uncollectible accounts that included a provision of $7.3 million related to the PX and ISO.
The level of NPC's maintenance and repair expenses depends primarily upon the scheduling, magnitude and number of generation unit overhauls at NPC's generating stations. Maintenance expense for 2001 increased from the prior year as a result of increased outage work at Reid-Gardner, additional expenditures for repairs and outages at Clark Station and increased work at Mohave. In 2000 maintenance expense decreased from the prior year primarily as a result of fewer planned plant maintenance activities at NPC's coal generation facilities. In addition, in 2000 crews performed required activities of a capital nature, thereby reducing the amount of maintenance expense.
An increase in plant-in-service was the cause of NPC's increase in depreciation and amortization expense in 2001 compared to 2000. Depreciation and amortization was also higher in 2000 than 1999 due to an increase in plant-in-service.
As a result of net income for 2001, NPC incurred income tax expense. Due to a net loss in 2000, NPC recorded an income tax benefit for the year. See Note 10 of "Notes to Financial Statements" for additional information regarding the computation of income taxes.
NPC's interest charges on long-term debt increased in 2001 compared to 2000, following a net increase in associated debt of $450 million (new issuances of $700 million and redemptions of $250 million during 2001). Interest charges on long-term debt for 2000 were comparable to 1999s. See Note 9 of "Notes to Financial Statements" for additional information regarding long-term debt.
NPC's interest charges-other in 2001 were comparable to 2000. Interest charges-other increased in 2000 compared to 1999 due to increased debt through the issuance of commercial paper in 2000 and due to interest costs associated with the issuance of floating rate notes in October 1999 and June, August, and December 2000.
NPC's other income (expense) - net improved in 2001 due primarily to the recognition in the current year of carrying charges on deferred fuel and purchased power balances pursuant to AB 369. Other income
(expense)-net improved in 2000 over the prior year as a result of greater increases in life insurance cash surrender values and reductions in contributions and membership dues.
Liquidity and Capital Resources
NPC's net cash flows decreased in 2001 compared to 2000. The net decrease in cash resulted from a significant increase in cash flows used in operating activities combined with cash used in investing activities both partially offset by an increase in cash provided by external financing sources. The increase in cash flows used in operating activities resulted substantially from the payment of significantly higher energy costs during 2001. Net cash used in investing activities was comparable between 2001 and 2000. Net cash provided by financing activities was higher in 2001 as a result of cash provided by the issuance of short-term and long-term debt, as described in Notes 12 and 9 to the Financial Statements, and additional capital contributions from SPR. Cash provided by financing activities was substantially utilized for the payment of higher energy costs in 2001.
NPC's net cash flows increased in 2000 compared to 1999. The net increase in cash resulted from less cash used in investing activities and more cash provided by financing activities. A reduction in the net cash used for utility plant was the main cause for the decrease in cash used for investing activities. The increase in cash flows from financing activities was due to an increase in funding received from SPR (less dividends paid) offset, in part, by less cash provided by the net issuance of long and short-term debt. The overall net increase in cash was also partially offset by a reduction in cash received from operating activities that was mainly due to a decrease in operating income.
As discussed in "Construction Expenditures and Financing" and "Capital Structure" that follow, NPC anticipates external capital requirements for construction costs and for the repayment of maturing short-term and long-term debt during 2002 totaling approximately $403 million, which NPC will fund through a combination of (i) internally generated funds, (ii) the issuance of short-term debt and preferred stock, and (iii) capital contributions from SPR.
NPC's primary source of short-term liquidity has been its commercial paper program, pursuant to which it sells commercial paper of varying maturities through dealers to institutional purchasers of commercial paper. NPC's current program permits the sale of up to $200 million of commercial paper on a revolving basis. As of December 31, 2001, NPC had $130.5 million of commercial paper outstanding, representing all of NPC's short-term debt as of that date. As is customary for an A2/P2 commercial paper issuer, NPC's commercial paper program requires that NPC maintain a back-up credit facility in the event that NPC is unable to sell additional commercial paper to pay off outstanding commercial paper due to conditions within the commercial paper market or due to a downgrade in the credit rating of NPC's commercial paper. Accordingly, if there ever were an event of default under or cancellation or termination of the back-up credit facility, NPC would not be able to issue commercial paper until NPC obtained another back-up credit facility or until the default were waived or cured.
As discussed in "Capital Structure" below, NPC has a Credit Agreement with a number of banks which matures on November 28, 2002. Although this facility may be used to provide liquidity for general corporate purposes, it has been used primarily by NPC to back up its commercial paper program. The Credit Agreement contains a number of restrictive covenants including restrictions on liens, sales of assets, mergers, and sale and leaseback transactions. The Credit Agreement also contains financial covenants requiring that NPC maintain:
. a ratio of (i) Total Indebtedness to (ii) the sum of Total Indebtedness and
Shareholders Equity that does not exceed 0.60:1 as of the last day of each
fiscal quarter.
. a Consolidated Interest Coverage Ratio of not less than 2.0:1 calculated as
of the last day of each fiscal quarter for the preceding four consecutive
fiscal quarters.
As of December 31, 2001, NPC was in compliance with these financial covenants.
The borrowing costs under the Credit Agreement are at a variable interest rate consisting of a spread over LIBOR or an alternate base rate that is based upon a pricing grid tied to the credit rating on NPC's senior unsecured long-term debt. NPC had no borrowings outstanding under the Credit Agreement as of December 31, 2001. On or before the maturity date of the Credit Agreement, NPC currently intends to either renew or replace the Credit Agreement.
The Credit Agreement is currently unsecured. However, NPC will be required to secure the Credit Agreement through the issuance of General and Refunding Mortgage bonds to the lenders in the event that the credit rating on NPC's senior unsecured long-term debt is downgraded (i) by Moody's Investors Service, Inc. to Baa3 or lower or (ii) by Standard & Poor's Ratings Group to BB+ or lower. The Credit Agreement requires NPC to maintain sufficient capacity under its General and Refunding Mortgage Indenture to satisfy this collateral requirement.
NPC and SPPC are currently negotiating receivables purchase facilities, in an aggregate principal amount not to exceed $200 million, that are expected to be finalized by the end of first quarter 2002. Under the proposed facilities, NPC and SPPC would each sell receivables in a true sale to special purpose entities that would in-turn sell those assets to a commercial paper conduit that would pay for the purchase of the assets by issuing commercial paper. These facilities will be used to provide additional liquidity for working capital and general corporate purposes in addition to NPC's existing commercial paper program. NPC expects the facility to be accounted for in compliance with SFAS No. 140, "Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities." The special purpose entities will be wholly owned subsidiaries and their financial positions and results of operations will be reflected in the consolidated financial statements of SPR, NPC, and SPPC.
NPC's first mortgage indenture creates a first priority lien on substantially all of NPC's properties. As of December 31, 2001, $387.5 million of NPC's first mortgage bonds were outstanding. Although the first mortgage indenture allows NPC to issue additional mortgage bonds on the basis of (i) 60 percent of net utility property additions and/or (ii) the principal amount of retired mortgage bonds, NPC agreed in its General and Refunding Mortgage Indenture that it would limit the issuance of additional first mortgage bonds to not more than $80 million.
NPC's General and Refunding Mortgage Indenture creates a lien on substantially all of NPC's properties in Nevada that is junior to the lien of the first mortgage indenture. As of December 31, 2001, $490 million of NPC's General and Refunding Mortgage securities were outstanding. Additional securities may be issued under the General and Refunding Mortgage Indenture on the basis of (i) 70 percent of net utility property additions, (ii) the principal amount of retired General and Refunding Mortgage bonds and/or (iii) the principal amount of first mortgage bonds retired after delivery to the indenture trustee of the initial expert's certificate under the General and Refunding Mortgage Indenture. At December 31, 2001, NPC had the capacity to issue approximately $1.2 billion of additional General and Refunding Mortgage bonds. However, the financial covenants contained in the Credit Agreement described above may limit NPC's ability to issue additional general and refunding bonds or other debt.
NPC also has the ability to release property from the liens of the two mortgage indentures on the basis of net property additions, cash and/or retired bonds. To the extent NPC releases property from the lien of its General and Refunding Mortgage Indenture, it will reduce the amount of bonds issuable under that indenture. Under the terms of NPC's $130 million of 6.20% Senior Unsecured Notes due 2004, NPC may be required, upon the issuance of additional General and Refunding Mortgage bonds, to secure the Senior Unsecured Notes through the issuance of an equal principal amount of General and Refunding Mortgage bonds.
Construction Expenditures and Financing
The table below provides NPC's consolidated cash construction expenditures and internally generated cash, net for 1999 through 2001 (dollars in thousands):
2001 2000 1999 Total ---------- --------- --------- ---------- Cash construction expenditures $ 196,896 $ 196,636 $ 220,919 $ 614,451 ========== ========= ========= ========== Net cash flow from operating activities $ (757,402) $ 113,711 $ 178,178 $ (465,513) Less common & preferred cash dividends 33,014 88,308 121,646 242,968 ---------- --------- --------- ---------- Internally generated cash (790,416) 25,403 56,532 (708,481) Add equity contribution from parent 474,921 137,000 18,000 629,921 ---------- --------- --------- ---------- Total cash available $ (315,495) $ 162,403 $ 74,532 $ (78,560) ========== ========= ========= ========== Internally generated cash as a percentage of cash construction expenditures Not Applicable 13% 26% Not Applicable Total cash generated (used) as a percentage of cash construction expenditures Not Applicable 83% 34% Not Applicable ---------------------------------------------------------------------------------------------------------------------- |
NPC's estimated cash construction expenditures for 2002 through 2006 are $1.118 billion. Construction expenditures for 2002 (approximately $311 million) will be financed through debt issuance and internally generated funds, including recovery of deferred energy. In 2002, NPC expects to pay all of its net income in dividends to SPR and to receive $16 million of capital contribution from SPR.
Cash provided by internally generated funds during 2002 assumes full recovery of deferred energy over three years and general rate increases approved as filed effective at the beginning of the second quarter. To the extent that the PUCN finds that any of NPC's deferred energy costs resulted from imprudent purchases, the PUCN will not permit that amount to be recovered through higher rates, and an equivalent amount of NPC's deferred energy cost asset will be required to be written off. A material write-off of deferred energy costs would have a material adverse affect on the future results of operations of NPC and could cause NPC's securities to be downgraded by the rating agencies and make it significantly more difficult to finance operations, and buy fuel and purchased power from third parties. Also see Construction Expenditures and Financing (SPR Consolidated) earlier.
Contractual Obligations
The table below provides NPC's contractual obligations, not including estimated construction expenditures described above, as of December 31, 2001, that NPC expects to satisfy through a combination of internally generated cash and, as necessary, through the issuance of short-term and long-term debt and preferred stock (dollars in thousands):
Payments Due By Period 2002 2003 2004 2005 2006 Thereafter Total ---------- -------------------------------------------------------------------------------- Long- Term Debt (1) $ 149,880 $ 350,000 $ 130,000 $ - $ - $1,127,967 $1,757,847 Purchased Power 1,046,893 17,061 109,904 109,374 108,996 713,711 2,105,939 Coal and Natural Gas 187,663 55,493 63,780 31,043 31,064 373,228 742,271 Capital Lease Obligations 6,156 6,156 6,946 7,736 7,736 58,016 92,746 Operating Leases 2,941 1,470 1,090 926 504 - 6,931 ---------- ---------- ---------- ---------- ---------- ---------- ---------- Total Contractual Cash Obligations $1,393,533 $ 430,180 $ 311,720 $ 149,079 $ 148,300 $2,272,922 $4,705,734 ========== ========== ========== ========== ========== ========== ========== |
(1) Includes short-term debt of $130,500.
Capital Structure
As of December 31, 2001, NPC had short-term debt outstanding of $130.5 miion comprised entirely of commercial paper.
On November 29, 2001, NPC put into place a $200 million unsecured revolving credit facility replacing an existing $250 million credit facility, which may be used for working capital and general corporate purposes, including commercial paper backup. This new credit facility requires NPC to issue general and refunding mortgage bonds to secure this credit facility in the event of a decline in NPC's senior unsecured debt rating. This facility will expire on November 28, 2002.
NPC's actual consolidated capital structure at December 31, 2001, and 2000 was as follows (dollars in thousands):
2001 2000 ------------------------- ----------------------- Short-Term Debt (1) $ 149,880 4% $ 352,910 15% Long-Term Debt 1,607,967 48% 927,784 39% Preferred Trust Securities 188,872 6% 188,872 8% Common Equity (2) 1,393,063 42% 887,737 38% ------------------------- ----------------------- TOTAL $3,339,782 100% $2,357,303 100% ========================= ======================= |
(1) Including current maturities of long-term debt.
(2) Does not include equity in Sierra Pacific Resources: 2001 = $309,259; 2000
= $471,975.
Results of Operations
SPPC's operating results that follow are based upon the Sierra Pacific Power Company Consolidated Statements of Income included in Item 8 of this report. SPPC's 2001 net income from continuing operations before dividend requirements on preferred stock was $22.7 million, compared to a net loss in 2000 of ($4.1) million and net income of $64.6 million in 1999.
As described in Note 17, Discontinued Operations, SPPC closed the sale of its water utility business on June 11, 2001. Accordingly, the water business is reported as a discontinued operation and the continuing operating results have been reclassified to report separately the net results of operations from the water business.
The components of gross margin are (dollars in thousands):
2001 2000 1999 --------------- --------------- --------------- Operating Revenues: Electric $ 1,399,134 $ 893,782 $ 609,197 Gas 145,652 100,803 100,177 --------------- --------------- --------------- Total Revenues 1,544,786 994,585 709,374 --------------- --------------- --------------- Energy Costs: Electric 1,113,634 678,727 294,846 Gas 113,364 67,035 68,125 --------------- --------------- --------------- Total Energy Costs 1,226,998 745,762 362,971 --------------- --------------- --------------- Gross Margin $ 317,788 $ 248,823 $ 346,403 =============== =============== =============== Gross Margin by Segment: Electric $ 285,500 $ 215,055 $ 314,351 Gas 32,288 33,768 32,052 --------------- --------------- --------------- Total $ 317,788 $ 248,823 $ 346,403 =============== =============== =============== |
The causes for significant changes in specific lines comprising the results of operations for the years ended are provided below (dollars in thousands except for amounts per unit):
Electric Operating Revenues
2001 2000 1999 --------------------------- --------------------------- ------------ Change from Change from Amount Prior year Amount Prior year Amount ------------ ------------ ------------ ------------ ------------ Electric Operating Revenues: Residential $ 210,350 17.7% $ 178,701 4.2% $ 171,533 Commercial 243,883 23.9% 196,846 4.5% 188,348 Industrial 253,936 29.5% 196,143 5.6% 185,771 ------------ ------------ ------------ Retail revenues 708,169 23.9% 571,690 4.8% 545,652 Other 690,965 114.5% 322,092 406.9% 63,545 ------------ ------------ ------------ Total Revenues $ 1,399,134 56.5% $ 893,782 46.7% $ 609,197 ============ ============ ============ Total retail sales (MWh) 8,729,173 -0.9% 8,807,332 4.7% 8,412,853 ------------ ------------ ------------ Average retail revenue per MWh $ 81.13 25.0% $ 64.91 0.1% $ 64.86 |
The increase in SPPC's 2001 retail revenues was primarily due to rate increases resulting from the Global Settlement and CEP - see Major Factors Affecting Results Of Operations, earlier. These rate increases partially offset the increases in fuel and purchased power costs that SPPC had incurred. Also contributing to the higher revenues was an increase in the number of residential, commercial and industrial customers of 2.8%, 3.3% and 9.3%, respectively. Substantially all of the increase in Other electric revenues was due to the sale of wholesale electric power to other utilities. SPPC's increase in wholesale sales compared to 2000 was a result of market conditions and SPPC's power procurement activities. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
In 2000, as a result of the Global Settlement, retail revenues were $2.9 million higher than 1999 because the PUCN allowed SPPC to begin recovering its increases in fuel and purchased power costs. The increases in residential and commercial electric revenues in 2000 were also due to warmer weather during the cooling-season than in 1999 and, to a lesser extent, by increases in the number of customers. Industrial revenues increased because of significant increases in usage per customer, primarily by mining customers. Other electric revenues were higher due to an increase in wholesale electric sales. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
Gas Operating Revenues
2001 2000 1999 --------------------------- --------------------------- ------------ Change from Change from Amount Prior year Amount Prior year Amount ------------ ------------ ------------ ------------ ------------ Gas Operating Revenues: Residential $ 63,815 46.6% $ 43,541 1.5% $ 42,888 Commercial 30,680 43.6% 21,368 0.5% 21,259 Industrial 17,941 58.7% 11,307 0.5% 11,252 Wholesale 33,298 46.0% 22,805 -2.8% 23,473 Miscellaneous (82) -104.6% 1,782 36.6% 1,305 ------------ ------------ ------------ Total Revenues $ 145,652 44.5% $ 100,803 0.6% $ 100,177 ============ ============ ============ Sales (Decatherms) 17,099,787 -8.9% 18,760,851 -21.2% 23,812,031 Average revenues per decatherm $ 8.52 58.7% $ 5.37 27.6% $ 4.21 |
Gas revenues rose in 2001, primarily due to the fact that the PUCN allowed SPPC to implement two gas rate increases (see Regulation and Rate Proceedings). These increases were the result of higher gas costs that SPPC incurred. Revenues were also higher due to increases of 5.0%, 3.1% and 10.6%, respectively, in residential, commercial and industrial customers, and an increase in wholesale revenues.
Residential, commercial and industrial gas revenues in 2000 were comparable to 1999. Increases from customer growth were largely offset by lower usage as a result of milder temperatures during the heating seasons. Overall, wholesale gas sales declined slightly in 2000 compared to 1999. A decline in wholesale volume was the result of less gas available for wholesale sales because of significant increases in the usage of gas supplies for electricity generation. This decline was nearly offset by an increase in wholesale unit prices.
Purchase Power
2001 2000 1999 --------------------------- --------------------------- ------------ Change from Change from Amount Prior year Amount Prior year Amount ------------ ------------ ------------ ------------ ------------ Purchased Power $ 1,025,741 130.5% $ 444,979 147.5% $ 179,781 Purchased Power MWH 7,591,000 3.3% 7,349,000 26.8% 5,797,903 Average cost per MWH of Purchased Power $ 135.13 123.2% $ 60.55 95.3% $ 31.01 |
Purchased power costs increased dramatically in 2001 due to Short-Term Firm purchase power prices doubling. Purchased power costs also reflect a 14% increase in wholesale sales. Purchases associated with risk management activities, which include transactions entered into for hedging purposes and to optimize purchased power costs, are included in the purchased power amounts. See Purchased Power Procurement, later, for a discussion of the Utilities' purchased power procurement strategies.
Purchased power costs were higher in 2000 than 1999 primarily because prices per MWh were double that of the prior year and purchased power was relied on to accommodate increased system load. Purchased power costs were also higher during 2000 due to hedging activities in response to higher purchased power prices.
Fuel For Power Generation
2001 2000 1999 ---------------------------- ----------------------------- -------------- Change from Change from Amount Prior year Amount Prior year Amount -------------- ------------- -------------- ------------- -------------- Fuel for Power Generation $ 286,719 22.7% $ 233,748 103.1% $ 115,065 MWHs generated 5,985,779 4.0% 5,756,000 15.2% $ 4,998,140 Average fuel cost per MWH of Generated Power $ 47.90 18.0% $ 40.61 76.4% $ 23.02 |
Fuel for power generation costs increased 22.7% in 2001 due mainly to increased natural gas prices, and, to a lesser extent, because volumes purchased were higher to accommodate greater system load.
Fuel for generation costs in 2000 were higher than 1999 due to higher gas prices and an increase in volumes purchased.
Gas Purchased for Resale
2001 2000 1999 ---------------------------- ----------------------------- -------------- Change from Change from Amount Prior year Amount Prior year Amount -------------- ------------- ----------- ------------- ------------ Gas Purchased for Resale $ 136,534 64.1% $ 83,199 22.1% $ 68,125 Gas Purchased for Resale (decatherms) 16,756,970 -9.2% 18,457,112 -22.9% 23,925,940 Average cost per decatherm $ 8.15 80.7% $ 4.51 58.2% $ 2.85 |
The cost of gas purchased for resale increased in 2001 because a decrease in the quantities of gas purchased was more than offset by large increases in unit prices. The decrease in quantities purchased was the result of increased plant consumption of gas, thereby decreasing the availability of gas for wholesale activities. The significant gas price increases are consistent with the regional growth in demand for limited supplies of natural gas.
The cost of gas purchased for resale increased in 2000 because the decrease in quantities of gas purchased was again more than offset by large increases in unit prices. The decrease in quantities purchased corresponded to reduced demand by SPPC's retail customers and reduced availability of gas for wholesale sales as a result of increased power plant consumption of gas. The higher unit prices were attributable to increased demand for gas in the Pacific Northwest and additional transportation fees.
Deferral of Energy Cost - Net
2001 2000 1999 ---------------------------- ---------------------------- -------------- Change from Change from Amount Prior year Amount Prior year Amount --------------- ------------ --------------- ----------- -------------- Deferred energy costs - electric $ (198,826) N/A $ - N/A - Deferred energy costs - gas (23,170) 43.3% (16,164) N/A - --------------- --------------- -------------- Total $ (221,996) N/A $ (16,164) N/A $ - =============== =============== ============== |
For 2001, SPPC recorded significant Deferral of energy costs electric-net (for purchased power and fuel for generation) due to the implementation of deferred energy accounting beginning March 1, 2001. The current year amounts reflect the extent to which actual fuel and purchased power costs exceeded the fuel and purchased power costs recovered through current rates. SPPC did not utilize deferred energy accounting for its electric operations in 2000 or 1999.
Recovery of fuel expenses is administered under Nevada's deferred energy cost accounting procedures. Under the deferred energy procedure, changes in the costs of fuel and purchased power are reflected in customer rates through annual rate adjustments and do not affect income. See "Critical Accounting Policies," earlier, and Note 1 of "Notes to Financial Statements" for more information regarding deferred energy accounting.
In January 2000, after the expiration of a rate freeze that was in effect from 1997 through 1999, SPPC began deferring natural gas costs in excess of that allowed in the tariff for its gas LDC. The deferral increased significantly in 2001 due to higher gas costs incurred by SPPC, as discussed in "Gas Purchased for Resale," above.
Allowance For Funds Used During Construction (AFUDC)
2001 2000 1999 ---------------------------- --------------------------- -------------- Change from Change from Amount Prior year Amount Prior year Amount --------------- ----------- -------------- ----------- -------------- Allowance for other funds used during construction $ 856 139.8% $ 357 N/A $ (1,370) Allowance for borrowed funds used during construction 660 -76.3% 2,779 1870.9% 141 --------------- --------------- -------------- $ 1,516 -51.7% $ 3,136 N/A $ (1,229) --------------- --------------- -------------- |
SPPC's AFUDC is lower in 2001 because of adjustments to amounts assigned to specific components of facilities that were completed in different periods offset by an increase in the AFUDC rate. AFUDC for 2000 is higher than 1999 because of an AFUDC rate increase in 2000 and a $2.3 million adjustment in 1999 to reverse amounts previously charged to AFUDC.
Other Expenses
2001 2000 1999 ---------------------------- ------------------------- ----------- Change from Change from Amount Prior year Amount Prior year Amount ----------- --------------- ----------- ------------ ----------- Other operating expense $ 117,627 22.0% $ 96,438 4.0% $92,745 Maintenance expense 24,363 32.3% 18,420 -9.3% 20,309 Depreciation and amortization 70,358 1.5% 69,350 -0.6% 69,762 Income taxes 8,507 N/A (672) -102.0% 33,870 Interest charges on long-term debt 55,199 49.7% 36,865 18.3% 31,151 Interest charges- other 7,433 -34.3% 11,312 0.2% 11,286 Other income (expense)-net 8,489 N/A (2,429) 260.9% (673) |
Other operating expense increased in 2001 compared to 2000 due to a $7
million larger addition to the provision for uncollectible customer accounts
than in 2000, and a $3.5 million reserve provision established as a result of AB
369. Additionally, there were increased expenses related to the start-up of the
Pinon Gasifier in 2001. Other operating expense for 2000 was higher due to an
increase in the provision for uncollectible accounts offset, in part, by reduced
labor and benefit costs as a result of merger efficiencies and unfilled
vacancies.
Maintenance costs in 2001 were higher due to additional turbine repairs and no major overhauls in 2000 at Valmy. There was also a shift from divestiture in 2000 to maintenance activities in 2001 at Tracy as well as unplanned maintenance on the diesel generators. Maintenance expense for 2000 decreased from 1999 as a result of fewer outages and lower plant maintenance expenses.
Depreciation and amortization was higher in 2001 than 2000 due to an increase in plant-in-service. Depreciation and amortization decreased in 2000 from 1999 because of computer software that was fully amortized in 1999.
As a result of recorded income for continuing operations for 2001, SPPC incurred income tax expense. Due to a net loss from continuing operations, SPPC recorded an income tax benefit for 2000. See Note 10 of "Notes to Financial Statements" for additional information regarding the computation of income taxes.
SPPC'S interest charges on long-term debt were higher in 2001 than 2000, primarily due to the issuance of $320 million of its General and Refunding Mortgage bonds in May 2001. Interest charges on long-term debt were higher in 2000, as a result of increased average long-term debt balances compared to 1999, including the June 2000 issuance of $200 million of variable rate notes.
SPPC'S interest charges-other decreased in 2001 compared to 2000 due to a decrease in commercial paper balances in 2001. For the year 2000, these interest charges-other were comparable to 1999.
SPPC's other income (expense) - net improved in 2001 due primarily to the recognition in the current year of carrying charges on deferred fuel and purchased power balances pursuant to AB 369. SPPC's other income (expense)-net declined in 2000 mainly due to the reclassification of lease expenses for SPPC's main offices.
Discontinued Operations
2001 2000 1999 ---------------------------- --------------------------- ------------ Change from Change from Amount Prior year Amount Prior year Amount ------------ -------------- ------------ ------------ ------------ Income from operations of water business $ 1,022 -89.4% $ 9,634 46.3% $ 6,583 |
Income from operations of the water business decreased in 2001 as a result of the sale of the water business on June 11, 2001, prior to the seasonal increase in revenues resulting from higher water send-out. Income from operations of the water business increased in 2000 due primarily to higher revenues, which resulted from both customer growth and to a lesser extent higher usage per customer.
Liquidity and Capital Resources
SPPC's net cash flows during 2001 were comparable to 2000. For 2001, an increase in net cash flows from investing activities was substantially offset by a decrease in net cash flows from operating activities. The increase in net cash flows from investing activities resulted from the sale of the assets of SPPC's water business. The decrease in cash flows from operating activities resulted substantially from the payment of significantly higher energy and resale natural gas costs. These uses of cash flows were partially offset by a decrease in accounts payable in 2001. The decrease in cash flows from financing activities was due to reduced reliance on commercial paper in 2001 and the retirement of preferred stock as described in Note 8 to the Financial Statements offset, in part, by capital contributions from SPR.
SPPC's net cash flows increased in 2000 compared to 1999. The net increase in cash resulted from less cash used in investing activities and more cash provided by financing activities. The decrease in cash used for investing activities was primarily due to SPPC's 1999 acquisition of General Electric Capital Corporation's interest in Pinon Pine Company L.L.C. Cash flows from financing activities increased slightly compared to the prior year due to the retirement of preferred stock in 1999. See Note 8 (Preferred Stock and Preferred Trust Securities) for information concerning the preferred stock retirement.
As discussed in "Construction Expenditures and Financing" and "Capital
Structure" below, SPPC will have capital requirements for construction costs and
for the repayment of maturing short-term and long-term debt during 2002 totaling
approximately $189 million, which SPPC will need to fund through a combination
of (i) internally generated funds, (ii) the issuance of short-term debt, and
(iii) capital contributions from SPR.
SPPC's primary source of short-term liquidity has been its commercial paper program, pursuant to which it sells commercial paper of varying maturities through dealers to institutional purchasers of commercial paper. SPPC's current program permits the sale of up to $150 million of commercial paper on a revolving basis. As of December 31, 2001, SPPC had $46.5 million of commercial paper outstanding, representing all of SPPC's short-term debt as of that date. As is customary for an A2/P2 commercial paper issuer, SPPC's commercial paper program requires that SPPC maintain a back-up credit facility in the event that SPPC is unable to sell additional commercial paper to pay off outstanding commercial paper due to conditions within the commercial paper market or due to a downgrade in the credit rating of SPPC's commercial paper. Accordingly, if there ever were an event of default under or cancellation or termination of the back-up credit facility, SPPC would not be able to issue commercial paper until SPPC obtained another back-up credit facility or until the default were waived or cured.
As discussed in "Capital Structure" below, SPPC has a Credit Agreement with a number of banks which matures on November 28, 2002. Although this facility may be used to provide liquidity for general corporate purposes, it has been used primarily by SPPC to back up its commercial paper program. The Credit Agreement
contains a number of restrictive covenants including restrictions on liens, sales of assets, mergers, and sale and leaseback transactions. The Credit Agreement also contains financial covenants requiring that SPPC maintain:
. a ratio of (i) Total Indebtedness to (ii) the sum of Total Indebtedness
and Shareholders Equity that does not exceed 0.60:1 as of the last day of
each fiscal quarter.
. a Consolidated Interest Coverage Ratio of not less than 2.0:1 calculated
as of the last day of each fiscal quarter for the preceding four
consecutive fiscal quarters.
As of December 31, 2001, SPPC was in compliance with these financial covenants.
The borrowing costs under the Credit Agreement are at a variable interest rate consisting of a spread over LIBOR or an alternate base rate that is based upon a pricing grid tied to the credit rating on SPPC's senior unsecured long-term debt. SPPC had no borrowings outstanding under the Credit Agreement as of December 31, 2001. On or before the maturity date of the Credit Agreement, SPPC currently intends to either renew or replace the Credit Agreement.
The Credit Agreement is currently unsecured. However, SPPC will be required to secure the Credit Agreement through the issuance of General and Refunding Mortgage bonds to the lenders in the event that the credit rating on SPPC's senior unsecured long-term debt is downgraded (i) by Moody's Investors Service, Inc. to Baa3 or lower or (ii) by Standard & Poor's Ratings Group to BB+ or lower. The Credit Agreement requires SPPC to maintain sufficient capacity under its General and Refunding Mortgage Indenture to satisfy this collateral requirement.
SPPC and NPC are currently negotiating receivables purchase facilities, in an aggregate principal amount not to exceed $200 million, that are expected to be finalized by the end of first quarter 2002. Under the proposed facilities, SPPC and NPC would each sell receivables in a true sale to special purpose entities that would in-turn sell those assets to a commercial paper conduit that would pay for the purchase of the assets by issuing commercial paper. These facilities will be used to provide additional liquidity for working capital and general corporate purposes in addition to SPPC's existing commercial paper program. SPPC expects the facility to be accounted for in compliance with SFAS No. 140, "Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities." The special purpose entities will be wholly owned subsidiaries and their financial positions and results of operations will be reflected in the consolidated financial statements of SPR, NPC, and SPPC.
SPPC's first mortgage indenture creates a first priority lien on
substantially all of SPPC's properties in Nevada and California. As of December
31, 2001, $509.7 million of SPPC's first mortgage bonds were outstanding.
Although the first mortgage indenture allows SPPC to issue additional mortgage
bonds on the basis of (i) 60 percent of net utility property additions and/or
(ii) the principal amount of retired mortgage bonds, SPPC agreed in its General
and Refunding Mortgage Indenture that it would not issue any additional first
mortgage bonds.
SPPC's General and Refunding Mortgage Indenture creates a lien on substantially all of SPPC's properties in Nevada that is junior to the lien of the first mortgage indenture. As of December 31, 2001, $320 million of SPPC's General and Refunding Mortgage bonds were outstanding. Additional securities may be issued under the General and Refunding Mortgage Indenture on the basis of (i) 70 percent of net utility property additions, (ii) the principal amount of retired General and Refunding Mortgage bonds and/or (iii) the principal amount of first mortgage bonds retired after delivery to the indenture trustee of the initial expert's certificate under the General and Refunding Mortgage Indenture. At December 31, 2001, SPPC had the capacity to issue approximately $416 million of additional General and Refunding Mortgage bonds. However, the financial covenants contained in the Credit Agreement described above may limit SPPC's ability to issue additional General and Refunding bonds or other debt.
SPPC also has the ability to release property from the liens of the two mortgage indentures on the basis of net property additions, cash and/or retired bonds. To the extent SPPC releases property from the lien of its General and Refunding Mortgage Indenture, it will reduce the amount of bonds issuable under that indenture.
Construction Expenditures and Financing
The table below provides SPPC's consolidated cash construction expenditures and internally generated cash, net for 1999 through 2001 (dollars in thousands):
2001 2000 1999 Total ----------- --------- --------- ----------- Cash construction expenditures $ 105,979 $ 132,354 $ 116,131 $ 354,464 =========== ========= ========= =========== Net cash flow from operating activities $ (213,579) $ 112,010 $ 122,329 $ 20,760 Less common & preferred cash dividends 89,901 84,899 81,746 256,546 ----------- --------- --------- ----------- Internally generated cash (303,480) 27,111 40,583 (235,786) Add equity contribution from parent 104,948 14,000 22,000 140,948 ----------- --------- --------- ----------- Total cash available $ (198,532) $ 41,111 $ 62,583 $ (94,838) =========== ========= ========= =========== Internally generated cash as a percentage of cash construction expenditures Not Applicable 20% 35% Not Applicable Total cash generated (used) as a percentage of cash construction expenditures Not Applicable 31% 54% Not Applicable --------------------------------------------------------------------------------------------------------------------------------- |
SPPC's estimated cash construction expenditures for 2002 through 2006 are $556 million. SPPC estimates that 29% of its 2002 cash expenditures (approximately $40 million) will be provided by the issuance of short-term debt and parent contributions. In 2002, SPPC expects to pay all of its net income in dividends to SPR and to receive $60 million of capital contribution from SPR.
Cash provided by internally generated funds during 2002 assumes full recovery of deferred energy over three years; and assumes general rate increases approved as filed and effective mid-year. To the extent that the PUCN finds that any of SPPC's deferred energy costs resulted from imprudent purchases, the PUCN will not permit that amount to be recovered through higher rates, and an equivalent amount of SPPC's deferred energy cost asset will be required to be written off. A material write-off of deferred energy costs would have a material adverse affect on the future results of operations of SPPC and could cause SPPC's securities to be downgraded by the rating agencies and make it significantly more difficult to finance operations, and buy fuel and purchased power from third parties. Also see Construction Expenditures and Financing (SPR Consolidated) earlier.
Contractual Obligations
The table below provides SPPC's contractual obligations, not including estimated construction expenditures described above, as of December 31, 2001, that SPPC expects to satisfy through a combination of internally generated cash and, as necessary, through the issuance of short-term and long-term debt (dollars in thousands):
Payments Due By Period 2002 2003 2004 2005 2006 Thereafter Total --------------------------------------------------------------------------------------------------------- Long-Term Debt (1) $ 49,130 $ 20,632 $ 2,621 $ 2,622 $ 52,629 $ 844,566 $ 972,200 Purchased Power 301,558 135,791 41,723 27,306 28,450 63,353 598,181 Coal and Natural Gas 179,710 70,534 65,702 65,628 63,235 352,423 797,232 Operating Leases 8,612 7,337 6,724 6,217 6,212 61,376 96,478 ------------- ----------- ------------ -------------- ------------- -------------- ------------ Total Contractual Cash Obligations $539,010 $ 234,294 $ 116,770 $ 101,773 $ 150,526 $ 1,321,718 $ 2,464,091 ============= =========== ============ ============== ============= ============== ============ |
(1) Includes short-term debt of $46,500.
Capital Structure
As of December 31, 2001, SPPC had short-term debt outstanding of $46.5 million comprised entirely of commercial paper.
On November 29, 2001, SPPC put into place a $150 million unsecured revolving credit facility replacing an existing $250 million credit facility, which may be used for working capital and general corporate purposes, including commercial paper backup. This new credit facility requires SPPC to issue general and refunding mortgage bonds to secure this credit facility in the event of a decline in SPPC's senior unsecured debt rating. This facility will expire on November 28, 2002.
SPPC's actual capital structure at December 31, 2001, and 2000 was as follows (dollars in thousands):
2001 2000 ---------------------- ------------------------- Short-Term Debt (1) $ 49,130 3% $ 328,578 20% Long-Term Debt 923,070 54% 605,816 37% Preferred Stock 50,000 3% 50,000 3% Preferred Trust Securities - - 48,500 3% Common Equity 692,654 40% 604,795 37% ------------- -------- --------------- --------- TOTAL $1,714,854 100% $ 1,637,689 100% ============= ======== =============== ========= |
(1) Including current maturities of long-term debt.
PURCHASED POWER PROCUREMENT (NPC and SPPC)
Traditionally, the Utilities obtained purchased power through annual and monthly Requests for Proposals ("RFPs") to electric suppliers. Over the past few years, structural and competitive changes in the energy markets have decreased the responsiveness of potential suppliers to the Utilities' RFPs. As a result of the market conditions in late 1999, the Utilities modified their procurement practices to rely less on the formal RFP process and more on the broker market. Brokers connect buyers and sellers in order to obtain optimal pricing for both sides. In October 1999, the Utilities established and utilized a timed procurement strategy in order to obtain a targeted percentage of their calculated purchased power requirement for procurement in the forward markets each month, following an overall trend of procuring power closer to the time of delivery. The timed procurement strategy was implemented at a time when the PUCN had ordered the Utilities to sell their generation plants in anticipation of retail competition and when it was still unclear what role the Utilities would play as a provider of last resort.
As the price of purchased power escalated in the late Spring of 2000 and serious concerns developed regarding the availability of purchased power in California and throughout the western United States, the
Utilities began accelerating and extending their timed procurement strategies to fill summer peak requirements for 2001 and 2002. In an effort to mitigate the higher costs for 2001 energy procurement at the height of the crisis and to insure availability of electricity to the Utilities' customers, the Utilities entered into forward agreements covering 2001 and 2002 in order to take advantage of the then lower pricing for 2002 purchases. The Utilities are currently working with major regional suppliers seeking bids to blend some of their existing forward contract prices (for deliveries in 2002 through 2005) to smooth out recent spikes in forward contract prices and to reduce overall purchased power costs for deliveries in 2002. At this time the Utilities cannot predict the likelihood of success of these efforts.
The Utilities continued to use the monthly RFP process in 2001, with the exception of the months of March through September for NPC. During the months of March through September, NPC had already secured purchased power resources such that it could rely on the spot market for its remaining power requirements.
In NPC's Refiled 2000 Resource Plan (PUCN Docket No. 01-7016) and SPPC's 2001 Resource Plan (PUCN Docket No. 01-7004), the Utilities set forth their base long-term procurement strategy which has since been modified to include obtaining up to 300 MW for NPC and 250 MW for SPPC of firm, baseload energy (seven days a week, twenty four hours a day) beginning January 1, 2004, with up to 500 MW of intermediate and peaking power purchases for delivery in the second and third quarter of each year.
The Utilities' purchased power procurement strategy involves an analysis of the Utilities' energy requirements to meet the needs of their retail and FERC jurisdictional loads. Net energy requirements are determined by subtracting already secured resources, including power plant generation, cogeneration facilities and previously purchased power contracts, from the Utilities' forecasted energy requirements. Once the net energy requirements are established, future energy prices are analyzed, using the forward market as the best predictor of future prices.
The net energy requirements and applicable pricing data are presented to the Utilities' Risk Management Committee ("RMC") which analyzes these requirements, reviews alternative purchasing strategies and provides guidance on the timing and quantity of purchases. See Item 7A, Quantitative and Qualitative Disclosures About Market Risk for additional discussion regarding the RMC's role and the application of risk management policies. The RMC regularly reviews updated transaction information, available secured energy resources and power requirements in order to determine secured resources requirements as well as total power requirements.
Short Term Power Procurement Strategy
The Utilities' short term power procurement strategy involves both day-ahead (next day through the end of the current month) and real-time (next hour through the end of the current day) activities that require buying, selling and scheduling power resources to determine the most economical way to produce or procure the power resources needed to meet the retail customer load. After connecting generation units to the system, the Utilities dispatch the generation output based on the comparative economics of generation versus spot-market purchase opportunities and determine the amount of excess capacity, which is then sold on the wholesale market, or the amount of deficiency capacity, which must be procured on an hourly basis.
The day-ahead resource coordination begins with an analysis of projected loads and existing resources. Firm forward take-or-pay contracts are scheduled and counted towards meeting the capacity needs of the day being pre-scheduled. Any deficiency in the projected operating reserve for the next day, after consideration of available internal generation resources is met by additional firm purchased power resources. The day-of resource coordination involves minimizing system production costs each hour by either changing the generation output or buying needed power/selling excess power in the wholesale market. Any sale of excess power priced above the incremental cost of producing such power reduces the net production cost of operating the electrical
system and thereby benefits the end use customer. The Utilities endeavor to reduce the electrical systems' net production cost by selling the available excess power resources.
Real-time resource coordination requires an hourly determination of whether to run generation or purchase power in order to achieve the lowest production costs by calculating the projected incremental or decremental cost of generation required to meet the forecast load in comparison to obtaining power in the wholesale power market. In the event that committed generators suffer a forced outage that is expected to last through the remaining monthly period, the operating cost of the next available generation resource is compared to purchase power options to determine the lowest cost option.
Term Power Procurement Strategy
The majority of the Utilities' purchased power resources are secured through term transactions (transactions of greater than one month). To coordinate fuel and purchase power resources, the Utilities analyze their existing portfolios of fuel and purchased power and the projected electrical system loads for the period under consideration. Existing contracts for natural gas and purchased power are compared to the projected load profile to determine if there are adequate resources to cover the peak loads plus reasonable reserves.
If monthly resources are insufficient to cover the average daily peak plus 7%, the cost of generating additional electrical energy is compared to the available purchase power cost to determine the lowest cost option for securing additional power resources. If the monthly resources exceed the requirements of the average daily peak plus 7%, the Utilities analyze whether it is more cost-efficient to sell off power and power resources or to keep the excess power to cover generation contingencies and deal with the excesses on a daily or hourly basis.
Hedging Transactions
Over the last two years the Utilities have used hedges to reduce price and commodity risk for future purchases by executing contracts at so-called "liquid" trading points. A liquid trading point is a hub where significant volumes of energy are freely purchased and sold amongst many parties at a heavy volume so that one particular transaction has no discernable effect on the market price of energy at that trading point. The hedged purchases are either delivered to the Utilities' service territories to service their customers or, if the hedged purchase is not needed to fulfill power requirements, resold in the liquid market depending upon the size of the load, the status of internal generation, and the market price at time of delivery.
A typical hedge transaction involves the purchase or sale of power at one of the major trading hubs where prices are highly correlated to the ultimate point of delivery. The following is an illustration of a typical hedging transaction for NPC. NPC's main point of interconnection with the Western System Coordinating Council grid is at Mead Substation, Nevada. If NPC seeks to purchase 25 MW of power for delivery on a specified future date, NPC can purchase energy from other major trading hubs that are highly correlated to Mead, such as Palo Verde, Arizona, thereby assuring the availability of 25 MW electricity on that date to meet anticipated loads. By purchasing power at Palo Verde, NPC is also protected from the risk of market participants knowing that NPC must make a purchase and the resultant increase in prices at NPC's primary point of delivery. Once it makes the purchase at Palo Verde, NPC will continually monitor whether other power might be available at a lower total cost, including the cost of transmitting the electricity to NPC's system. If NPC finds an opportunity to purchase the same amount of power at delivery hubs closer to Mead, such as Pinnacle Peak Substation in Arizona, for a lower total cost than taking delivery of the original purchase at Palo Verde, NPC will sell its 25 MW position at Palo Verde and purchase the 25 MW position for delivery at Pinnacle Peak. Shortly before the date of delivery, NPC may have an opportunity to procure yet another source of power that will deliver 25 MW more cheaply, on a total cost basis, directly to Mead Substation. NPC would
therefore sell the 25 MW position at Pinnacle Peak and purchase the 25 MW position for delivery at Mead Substation.
In the above example, NPC will record a total of 75 MW of purchased power expense, 50 MW of wholesale power sales and 25 MW of retail sales, all of which are related to meeting the same 25 MW load requirement. This series of transactions is designed to acquire power at the lowest feasible total cost while at the same time ensuring that the basic commodity will be available on the date needed. At no time are the Utilities trading power on a speculative basis. Any savings in costs achieved by such a series of transactions will lower the Utility's overall costs for purchased power and therefore reduce the Utility's deferred energy account balance.
Tuscarora Gas Pipeline Company
TGPC, a wholly owned subsidiary of SPR, contributed $2.6 million in net income for the twelve months ended December 31, 2001, and $2.1 million in net income for the twelve months ended December 31, 2000. The Consolidated Statements of Income of Sierra Pacific Resources for the year ended December 31, 1999, include the operating results of TGPC for the five month period ended December 31, 1999, based on a merger date of August 1, 1999, for accounting purposes. TGPC contributed $711,000 in net income for the five months ended December 31, 1999, and $1.8 million in net income for the twelve months ended December 31, 1999.
Sierra Pacific Communications
SPC, a wholly owned subsidiary of SPR, incurred a net loss of ($2.9) million for the twelve months ended December 31, 2001, and a net loss of ($989,000) for the twelve months ended December 31, 2000. The Consolidated Statements of Income of Sierra Pacific Resources for the year ended December 31, 1999, include the operating results of SPC, for the five month period ended December 31, 1999, based on a merger date of August 1, 1999, for accounting purposes. SPC incurred a net loss of ($62,000) for the five months ended December 31, 1999, and a net loss of ($75,000) for the twelve months ended December 31, 1999.
e.three
e.three, a wholly owned subsidiary of SPR, contributed $666,000 of net income for the twelve months ended December 31, 2001, and $338,000 of net income for the twelve months ended December 31, 2000. The Consolidated Statements of Income of Sierra Pacific Resources for the year ended December 31, 1999, include the operating results of e.three, for the five month period ended December 31, 1999, based on a merger date of August 1, 1999, for accounting purposes. e. three incurred a net loss of ($381,000) for the five months ended December 31, 1999, and a net loss of ($788,000) for the twelve months ended December 31, 1999.
Sierra Pacific Energy Company
SPE, a wholly owned subsidiary of SPR, incurred a net loss of ($335,000) for the twelve months ended December 31, 2001, and a net loss of ($4.5) million for the twelve months ended December 31, 2000. The Consolidated Statements of Income of Sierra Pacific Resources for the year ended December 31, 1999, include the operating results of SPE for the five month period ended December 31, 1999, based on a merger date of August 1, 1999, for accounting purposes. SPE incurred a net loss of ($2.2) million for the five months ended December 31, 1999, and a net loss of ($3.6) million for the twelve months ended December 31, 1999.
Lands of Sierra
LOS, a wholly owned subsidiary of SPR, incurred a net loss of ($281,000) for the twelve months ended December 31, 2001, and a net loss of ($191,000) for the twelve months ended December 31, 2000. The Consolidated Statements of Income of Sierra Pacific Resources for the year ended December 31, 1999, include the operating results of LOS for the five month period ended December 31, 1999, based on a merger date of August 1, 1999, for accounting purposes. LOS contributed net income of $816,000 for the five months ended December 31, 1999, and net income of $810,000 for the twelve months ended December 31, 1999.
Nevada Electric Investment Company
Nevada Electric Investment Company (NEICO), a wholly owned subsidiary of SPR, contributed net income of $101,000 for the twelve months ended December 31, 2001, and net income of $384,000 for the twelve months ended December 31, 2000. Prior to 2000, NEICO was a wholly owned subsidiary of NPC. Accordingly, NEICO's operating results for the twelve months ended December 31, 1999 (a net loss of $594,000), are included in NPC's operating results for that period.
Sierra Pacific Resources (Holding Company)
The holding company operating results included approximately $55.8 million, $44.5 million, and $11.5 million of interest costs for 2001, 2000, and 1999, respectively, that resulted primarily from the merger financing. For additional merger information, see Note 2 to the Consolidated Financial Statements included in this report.
The Utilities are subject to the jurisdiction of the PUCN and, in the case of SPPC, the California Public Utility Commission (CPUC) with respect to rates, standards of service, siting of and necessity for, generation and certain transmission facilities, accounting, issuance of securities and other matters with respect to electric distribution and transmission operations. NPC and SPPC submit integrated resource plans to the PUCN for approval.
Under federal law, the Utilities are subject to certain jurisdictional regulation, primarily by the FERC. The FERC has jurisdiction under the Federal Power Act with respect to rates, service, interconnection, accounting, and other matters in connection with the Utilities' sale of electricity for resale and interstate transmission. The FERC also has jurisdiction over the natural gas pipeline companies from which the Utilities take service.
As a result of regulation, many of the fundamental business decisions of the Utilities, as well as the rate of return they are permitted to earn on their utility assets, are subject to the approval of governmental agencies.
As with other utilities, NPC and SPPC are subject to federal, state and local regulations governing air, water quality, hazardous and solid waste, land use and other environmental considerations. Nevada's Utility Environmental Protection Act requires approval of the PUCN prior to construction of major utility, generation or transmission facilities. The United States Environmental Protection Agency (EPA), Nevada Division of Environmental Protection (NDEP), and Clark County Health District (CCHD) administer regulations involving air quality, water pollution, solid, hazardous and toxic waste. SPR's Board of Directors has a comprehensive environmental policy and separate board committee that oversees NPC, SPPC, and SPR's corporate performance and achievements related to the environment.
On April 18, 2001, the Governor of Nevada signed into law AB 369. The provisions of AB 369 include a moratorium on the sale of generation assets by electric utilities, the repeal of electric industry restructuring, and a reinstatement of deferred energy accounting for fuel and purchased power costs incurred by electric utilities. The stated purposes of this emergency legislation were, among others, to control volatility in the price of electricity in the retail market in Nevada, and to ensure that the Utilities have the necessary financial resources to provide adequate and reliable electric service under present market conditions. To achieve these purposes, AB 369 allows the Utilities to recover in future periods their current costs for wholesale power and fuel, which have risen dramatically over the past year. Deferred energy accounting will have the effect of delaying additional rate increases to consumers until the second quarter of 2002 while, at the same time, providing a method for the Utilities to recover their increased costs for fuel and purchased power. Set forth below is a summary of key provisions of AB 369.
Generation Divestiture Moratorium
AB 369 prohibits all divestiture of generation assets by electric utilities until July 2003. After January 1, 2003, NPC or SPPC may seek PUCN permission to sell one or more generation assets with the sale to be effective on or after July 1, 2003. The PUCN may approve the request to divest only if it finds the transaction to be in the public interest. The PUCN may base its approval of the request upon such terms, conditions, or modifications as it deems appropriate.
AB 369 directs the PUCN to take all steps necessary to obtain federal approval for the prohibition on divestiture and to vacate any of its own orders that had previously approved generation divestiture transactions.
Deferred Energy Accounting
AB 369 required the Utilities to use deferred energy accounting for their respective electric operations beginning on March 1, 2001. The intent of deferred energy accounting is to ease the effect of fluctuations in the cost of purchased power and fuel. See Note 3 to the Financial Statements for a discussion of the deferred energy accounting provisions of AB 369.
Transition of Rates to Deferred Energy Accounting
All rates in effect on April 1, 2001, including the cumulative increases under the Global Settlement and the CEP Riders, remain in effect until the PUCN issues final orders on future general and initial deferred energy rate applications. (See "Required Filings," below). No further applications can be made for the Fuel and Purchased Power (F&PP) riders that were part of the July 2000 Global Settlement described in SPR's Annual Report on Form 10-K for the year ended December 31, 2000.
The Utilities are not permitted to recover any shortfall incurred before March 1, 2001, resulting from the difference between actual fuel and purchased power costs and the rates permitted by the Global Settlement. Although the F&PP riders were in effect during this period, the riders were based on trailing 12-month average costs and were subject to caps and, therefore, did not allow the Utilities full recovery for fuel and purchased power costs due to the rapid rise in energy prices.
AB 369 prohibits the PUCN from taking any further action on the CEP, and provides that, except for the CEP Rider rate increases put in effect on April 1, 2001, the CEP will be deemed to have been withdrawn by the Utilities. Additionally, approximately $20 million of revenue collected by the Utilities based on the CEP before
April 1, 2001 was credited to the deferred energy accounts, which caused the accounts to start in an over-collected position.
Required Filings
The Utilities have both filed a general rate application and a deferred energy application on the dates listed below:
General Rate Case Deferred Energy Filing ----------------- ---------------------- File Date Effective Date File Date Effective Date Nevada Power Company Oct. 1, 2001 April 1, 2002 Dec. 1, 2001 April 1, 2002 Sierra Pacific Power Company Dec. 1, 2001 June 1, 2002 Feb. 1, 2002 June 1, 2002 |
In connection with clearing the Utilities' deferred energy accounts, the PUCN must investigate and determine whether the Utilities' rates that went into effect on March 1, 2001, pursuant to the CEP, are just and reasonable and reflect prudent business practices. The rates in effect on April 1, 2001, remain in effect until the PUCN issues final orders on the general and initial deferred energy rate applications referred to above. The PUCN is prohibited from adjusting rates during this time period unless an adjustment is absolutely necessary to avoid a finding that the rates are confiscatory and, therefore, in violation of the United States or Nevada Constitutions. If adjustments are necessary, they may only be made to the extent necessary to avoid an unconstitutional result.
After the initial general rate applications described above, each Utility will be required to file future general rate applications at least every 24 months.
See "Nevada Power Company General Rate Case," later, for a discussion of NPC's general rate application filed on October 1, 2001 and "Nevada Power Company Deferred Energy Case," later, for a discussion of NPC's deferred rate application filed on November 30, 2001.
See "Sierra Pacific Power Company General Rate Case," later, for a discussion of SPPC's general rate application filed on November 30, 2001 and "Sierra Pacific Power Company Deferred Energy Case," later, for a discussion of SPPC's deferred rate application filed on February 1, 2002.
Restrictions on Mergers and Acquisitions
AB 369 imposes certain restrictions on mergers and acquisitions involving Nevada electric utilities. In particular, the PUCN may not approve a merger or acquisition involving an electric utility unless the utility complies with the generation divestiture provisions of AB 369.
In addition, AB 369 includes provisions that would have significantly affected the required regulatory approvals for the proposed acquisition of PGE from Enron. On April 26, 2001, Enron and SPR terminated, by mutual agreement, the proposed purchase and sale of PGE.
AB 369 also provides that if an electric utility holding company acquires an interest in an out-of-state public utility prior to July 1, 2003, each electric utility in which the holding company holds a controlling interest shall not be entitled to the benefit of deferred energy accounting. Thus, in the event that SPR acquires an out-of-state public utility, NPC and SPPC would lose the ability to utilize deferred energy accounting.
Repeal of Electric Industry Restructuring
AB 369 repeals all statutes authorizing retail competition in Nevada's electric utility industry and voids any license issued to an alternative seller in connection with retail electric competition.
Other Legislation
SB 372, which increased renewable energy portfolio requirements, was enacted in the 2001 Nevada legislative session. Renewable resources include biomass, wind, solar, and geothermal projects. In 2003, the Utilities will be required to purchase five percent of their energy from renewable resources. These requirements increase to 15% by 2013. Prior law capped renewable energy requirements at one percent. Currently, SPPC obtains approximately nine percent of its energy from renewable resources, while NPC obtains less than one percent from renewables. SB 372 requires the PUCN to establish standards for renewable energy contracts, including prices and other terms and conditions. If sufficient renewable energy contracts that meet PUCN standards are not available, the Utilities will not be required to meet the portfolio requirements. All renewable energy contracts meeting PUCN standards will be recoverable in the deferred energy accounts.
The 2001 Nevada legislature passed another key piece of legislation for the Nevada energy industry, AB 661. AB 661 allows commercial and governmental customers with an average demand greater than 1 MW to select new energy suppliers. The Utilities would continue to provide transmission, distribution, metering and billing services to such customers. AB 661 requires customers wishing to choose a new supplier to receive the approval of the PUCN and meet public interest standards. In particular, departing customers must secure new energy resources that are not under contract to the Utilities, remaining customers or the utility cannot be negatively impacted by the departure, and the departing customers must pay any deferred energy balances. The PUCN has adopted regulations prescribing the criteria that will be used to determine if there will be negative impacts to remaining customers or the utility. Certain limits are placed upon the departure of NPC customers until 2003; most significantly, the amount of load departing is limited to approximately 1100 MW in peak conditions. AB 661 permits customers to file applications with the PUCN beginning in the fourth quarter of 2001. Customers must provide 180-day notice to the Utilities and could begin to receive service from new suppliers by mid-2002. On January 10, 2002, an approximately 130 MW SPPC customer submitted an application to the PUCN under AB 661. The customer, SPPC, and PUCN staff are negotiating a stipulation regarding settlement of the terms and conditions under which this customer will be permitted to procure energy from an alternative source other than SPPC. The terms and conditions of the stipulation are expected to comply with the provisions of AB 661 in that SPPC and its remaining customers will not be negatively impacted by the customer's departure. A hearing on the stipulation has been set for March 20, 2002.
AB 661 also contains new electric and gas energy surcharges for low-income assistance and weatherization programs. These surcharges are recoverable directly from customers as separate line items on their bills with the Utilities remitting collected surcharges to the PUCN. Various state agencies will administer the disposition of the funds.
Nevada Power Company General Rate Case (NPC)
On October 1, 2001, NPC filed an application with the PUCN seeking an electric general rate increase. This application was mandated by AB 369, which was enacted by the Nevada legislature in April 2001. On December 21, 2001, NPC filed a Certification to its general rate filing updating costs and revenues pursuant to Nevada regulations. In the certification filing, NPC requested an increase in its general rates charged to all classes of electric customers designed to produce an increase in annual electric revenues of $22.7 million, which is an overall 1.7% rate increase. The application also seeks a return on common equity ("ROE") for Nevada Power's total electric operations of 12.25% (a reduction from NPC's last-authorized ROE for bundled electric
operations of 12.50%) and an overall rate of return ("ROR") of 9.30% (a reduction from NPC's last-authorized ROR for bundled electric operations of 10.02%). Public hearings on NPC's general rate case began on February 4, 2002. Various parties have intervened in NPC's general rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, MGM/Mirage, and the Nevada Coalition Of Commercial Energy Consumers. The reduction of NPC's revenue requirements proposed by the intervenors ranges from $50 million to $107 million.
Nevada Power Company Deferred Energy Case (NPC)
On November 30, 2001, NPC filed an application with the PUCN seeking to clear deferred balances for purchased fuel and power costs accumulated between March 1, 2001 through September 30, 2001. This application was mandated by AB 369, which was enacted by the Nevada Legislature in April 2001. The application seeks to establish a Deferred Energy Accounting Adjustment ("DEAA") rate to clear accumulated purchased fuel and power costs of $922 million and spread the cost recovery over a not more than three-year period. It also seeks to recalculate the Base Tariff Energy Rate to reflect anticipated ongoing purchased fuel and power costs. The total rate increase resulting from the DEAA would amount to 21%. NPC has proposed an alternate plan in which full recovery of the deferred balance would be amortized over a period greater than three years, but not to exceed six years. Public hearings began March 4, 2002. Various parties have intervened in NPC's deferred energy rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, MGM/Mirage, the Southern Nevada Water Authority, the Nevada Energy Buyers Group, and the Nevada Coalition Of Commercial Energy Consumers. The disallowance of NPC's deferred energy balance that is proposed by the intervenors ranges from $85 million to $980 million. The disallowance of a significant amount of NPC's deferred energy costs could result in NPC becoming insolvent. Some intervenors have argued that disallowance of NPC's deferred energy costs would be in the best interests of ratepayers based on speculation that some of the deferred energy costs could be avoided under bankruptcy laws if NPC were to become subject to bankruptcy proceedings.
Sierra Pacific Power Company General Rate Case (SPPC)
On November 30, 2001, SPPC filed an application with the PUCN seeking an electric general rate increase. This application was mandated by AB 369, which was enacted by the Nevada Legislature in April 2001. On February 28, 2002, SPPC filed a certification to its general rate filing, updating costs and revenues pursuant to Nevada regulations. In the certification filing, SPPC requested an increase in its general rates charged to all classes of electric customers, which were designed to produce an increase in annual electric revenues of $15.9 million representing an overall 2.4% rate increase. The application also seeks an ROE for SPPC's total electric operations of 12.25% (an increase from SPPC's last authorized ROE for bundled electric operations of 12.0%) and an overall ROR of 9.42% (a reduction from SPPC's last authorized ROR for bundled electric operations of 10%). Public hearings for SPPC's general rate case are scheduled to begin on April 8, 2002. Various parties have intervened in SPPC's general rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, and Barrick Goldstrike Mines, among others. Intervenor testimony will not be filed until March 22, 2002.
Sierra Pacific Power Company Deferred Energy Case (SPPC)
On February 1, 2002, SPPC filed an application with the PUCN seeking to clear deferred balances for purchased fuel and power costs accumulated between March 1, 2001 and November 30, 2001. This application was mandated by AB 369. The application seeks to establish a DEAA rate to clear accumulated purchased fuel and power costs of $205 million and spread the cost recovery over a not more than three-year period. It also seeks to recalculate the Base Tariff Energy Rate to reflect anticipated ongoing purchased fuel and power costs. The total rate increase resulting from the DEAA would amount to 9.8%. SPPC has proposed an alternate plan in which full recovery of the deferred balance would be amortized over a period greater than three years, but not to exceed six years. Public hearings are scheduled to begin in April 2002. Various parties have intervened in SPPC's deferred energy rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, and Barrick Goldstrike Mines, among others. Intervenor testimony will not be filed until April 22, 2002. The disallowance of a significant amount of SPPC's deferred energy costs could result in SPPC becoming insolvent.
Resource Plans (SPPC, NPC)
On July 2, 2001, SPPC filed its electric resource plan for the period of 2001-2020. On July 9, 2001, NPC filed its amended electric resource plan for the period of 2000-2019. The plans include scenarios to meet the electric needs of customers while sustaining reliable electric systems. The integrated resource plans evaluate resources to be used to meet forecasted loads. Resource options considered include new transmission lines to access energy markets, construction of generation facilities, power purchases from IPP's under short- and long-term agreements, and conservation programs. On October 18, 2001, the PUCN approved NPC's amended resource plan. On August 2, 2001, a pre-hearing conference was held on SPPC's resource plan and procedural orders were established. Public hearings on SPPC's plan were held in late October, and on November 1, 2001, the PUCN issued an order approving and adopting SPPC's plan.
PUCN Rulemaking for Assembly Bill 661 (SPPC, NPC)
The PUCN opened an investigatory and rulemaking docket to implement the provisions of AB 661. The PUCN has scheduled a workshop to receive comments regarding proposed regulations. These regulations concern eligible customers purchasing new electric resources from suppliers other than SPPC or NPC. A public hearing regarding the regulation was held on October 30, 2001. On November 26, 2001, the PUCN approved the regulations.
Optional Conservation Service (NPC, SPPC)
On April 19, 2001, the PUCN approved new NPC and SPPC electric rates for Optional Conservation Service (Schedule OC). Schedule OC allows the Utilities to request customers with demand greater than 1 MW to voluntarily curtail their load when there is an economic or system need for capacity and energy. Customers who curtail load will receive a billing credit.
Parallel Generation Tariffs (NPC, SPPC)
On May 11, 2001, the Utilities filed with the PUCN revisions to existing tariffs that will allow customers to interconnect standby generators in parallel with the Utilities' facilities. These changes will allow customers meeting specific requirements to utilize their standby generators in support of the Optional Conservation Service tariffs during times of power shortages or higher prices. On August 3, 2001, the PUCN approved the revisions.
Finance Authority (NPC, SPPC)
On September 20, 2001, the PUCN approved the June 19, 2001 applications by the Utilities for authority to issue long or short-term debt on either a secured or unsecured basis in an aggregate amount not to exceed $200 million for NPC and $100 million for SPPC through the end of 2002. NPC has issued all of its $200 million of authorized debt. SPPC has not issued any debt under this authority and has the full amount of the $100 million of authorized debt available for future issuances. On September 20, 2001, the PUCN also approved the Utilities' June 19, 2001 applications to amend an order issued by the PUCN allowing each of the Utilities to issue unsecured short-term promissory notes in an amount not to exceed $250 million through the period ending December 31, 2001. In the applications, the Utilities requested that the PUCN amend its previous order to provide the Utilities with the flexibility to issue secured promissory notes in addition to, or in lieu of, the authorized unsecured promissory notes.
On October 1, 2001, NPC and SPPC each filed an application with the PUCN requesting authority to issue secured or unsecured promissory notes in aggregate amounts not to exceed $250 million through December 31, 2004. On October 9, 2001, the Utilities filed amended applications reducing the time period to
December 31, 2003. On November 29, 2001, the PUCN issued a compliance order approving the requests. Currently, NPC has $50 million and SPPC has $100 million of short-term debt authority remaining from these PUCN authorizations.
Natural Gas Rate Increase (SPPC)
On June 29, 2001, SPPC filed with the PUCN a Purchase Gas Adjustment (PGA) seeking recovery of $41.4 million in accumulated, unrecovered purchased gas expenses, and an increase in the going-forward rate to $.71 per therm. Public hearings were held on October 22 and 23, 2001. On November 5, 2001, the PUCN granted SPPC's application and approved recovery of the entire $41.4 million accumulated deferred balance over a three-year period and an increase in the going-forward rate to $.6648 per therm. Any over or under-recovery of future energy costs will be the subject of a future PGA application. SPPC will file its next PGA on July 1, 2002.
SPR and NPC Merger (NPC and SPPC)
The merger between SPR and NPC was finalized on July 28, 1999. As part of the conditions for the merger, the Utilities were each required to divest all generation assets and file a general rate case unbundling costs. In May 1999, the Nevada Legislature passed SB 438, which modified the electric restructuring statutes. The Utilities filed general rate cases, unbundling costs and filed distribution rates for an unregulated market. However, in April of 2001 the Nevada Legislature passed AB 369, discussed earlier, which repealed the condition that the Utilities divest their generation assets and placed a moratorium on the sale of any generation assets until July 2003. AB 369 also repealed electric restructuring (deregulation).
Price Mitigation Plan
On June 19, 2001, the FERC adopted a price mitigation plan applicable to spot market wholesale power sales in California and throughout the western United States during the period June 20, 2001 through September 30, 2002. The price mitigation plan establishes a mechanism with which to determine the maximum amount that may be charged for power sold during this period. The intent of the mitigation plan is to simulate the price that might be charged for electricity sold under competitive market conditions. Sellers that do not wish to establish rates on the basis of this price mitigation plan may propose cost-of-service rates covering all of their generating units in the WSCC for the duration of the mitigation plan. Although the Utilities are not able to predict at this time the long-term effect that the FERC price mitigation plan and other market developments may have on their results of operations, management believes that, under certain market conditions, the FERC plan adversely affects the availability of spot market power to the Utilities and reduces the price at which the Utilities can sell power on the wholesale market. Another potential result from these price mitigation measures could be the delay and/or cancellation of proposed power plants throughout the western United States. If these results occur, the long-term supply of energy could be reduced. Numerous parties, including NPC and several northwest utilities, appealed the June 19 and July 25, 2001 orders from the FERC to the District of Columbia Court of Appeals on the basis that the price caps are unfair to electric customers who reside outside of California. In a report to Congress on January 31, 2002, the FERC said the price mitigation plan had little if any influence on prices at which Western utilities were able to resell power. SPR is not persuaded by the FERC's report and continues to believe that the FERC's price caps have negatively impacted electric customers outside California. The parties to the appeal await action by the Court.
Regional Transmission Organization and Independent Transmission Company
NPC and SPPC are members of the utility groups that are forming a proposed regional transmission organization (RTO West) and a proposed independent transmission company (TransConnect).
In October 2000, RTO West submitted to the FERC a compliance filing and supplemental material, which provided details of the formation of the RTO. RTO West, as proposed, would be a non-profit independent system operator of the regional transmission grid, governed by an independent board of directors. This filing was made in compliance with FERC Order 2000, which required all investor-owned utilities in the United States who own interstate transmission to file a proposal to participate in an RTO or an explanation of efforts and plans to participate in an RTO. Also in October 2000, TransConnect submitted to the FERC a proposal to form a for-profit Independent Transmission Company which would become a member of RTO West.
On April 25, 2001, FERC gave preliminary approval for both RTO West and TransConnect. On November 13, 2001, TransConnect submitted a filing to FERC asking for preliminary approval of its proposed transmission rate structure, modified governance proposal, and transmission planning and expansion protocol. On December 1, 2001, RTO West submitted a status report on its development efforts to FERC in compliance with FERC's April 2001 order. Both organizations remain subject to approvals from state regulators and the board of directors of each member company.
The current filing utility members of RTO West are NPC, SPPC, Avista Corporation, British Columbia Hydro & Power Authority, Bonneville Power Administration (BPA), Idaho Power Company, The Montana Power Company, PacifiCorp, Portland General Electric, and Puget Sound Energy, Inc. The current filing utility members of TransConnect are NPC, SPPC, Avista Corporation, and Portland General Electric.
Wholesale Sales Tariffs
On March 13, 2001, the Utilities each filed an application for an order approving market-based rates. The market-based authority would apply to sales of electric energy and capacity outside of the Utilities' control areas. On May 11, 2001, SPPC and NPC received approval for market-based rates subject to a compliance order. SPPC's and NPC's compliance filing was accepted on August 10, 2001.
Alturas Intertie
Certain Northern California public power groups have challenged SPPC's filing with the FERC of the interconnection and operating agreements related to the Alturas Intertie in December 1998 and January 1999. The California groups alleged that the potential reduction in imports into California constitutes an impairment of reliability and therefore seek to force reductions in use of the Alturas Intertie during peak periods. SPPC (supported by Bonneville Power Administration and PacifiCorp) has filed testimony before the FERC that the Alturas Intertie does not adversely affect reliability and that, under the FERC's Order No. 888, customers in Nevada are entitled to compete with customers in California for transmission capacity in the Pacific Northwest on a first-come, first-served basis. The FERC staff has agreed with SPPC's position on this matter. The matter was tried to an Administrative Law Judge (ALJ) in April and May 2000. In 2001, the ALJ agreed with SPPC's position, but imposed a limitation on additional transfer capacity created by future upgrades to the system. The ALJ stated allocation of additional transfer capacity would require agreement among the parties. Both sides have appealed this decision to the full FERC.
Rate Stabilization Plan
SPPC serves approximately 44,500 customers in California. On June 29, 2001, SPPC filed with the CPUC a Rate Stabilization Plan, which includes two phases. Phase One, which was also filed June 29, 2001, is an emergency electric rate increase of $10.2 million annually or 26%. If granted, the typical residential monthly electric bill for a customer using 650 kilowatt-hours would increase from approximately $47.12 to $60.12. On August 14, 2001, a pre-hearing conference was held, and a procedural order was established. On September 27, 2001, the Administrative Law Judge issued an order stating that no interim or emergency relief could be granted until the end of the "rate freeze" period mandated by the California restructuring law for recovery of stranded costs. In accordance with the judge's request, on October 26, 2001, SPPC filed an amendment to its application declaring the rate freeze period to be over.
Phase Two, which is scheduled to be filed with the CPUC in April 2002, will be a general rate case to recover costs for expenses other than fuel and purchased power. SPPC will also ask the CPUC to reinstate the Energy Cost Adjustment Clause, which would allow SPPC to file for periodic rate adjustments to reflect its actual costs for fuel and purchased power. Phase Two will also include a proposal pertaining to the termination of the 10% rate reduction mandated by AB 1890. On December 5 and 11, 2001 hearings on Phase One were held and on January 11, 2002, opening briefs were filed. Reply briefs were filed on January 25, 2002. A proposed draft decision is expected by the end of March 2002. SPPC will file Phase Two on April 1, 2002.
Distribution Performance-based Rate-making
Hearings on SPPC's distribution performance -based rate-making (PBR) proposal were held on April 2, 2001. An outline of the settlement reached by SPPC, the CPUC Office of Ratepayer Advocates, and The Utility Reform Network resolving all issues was presented during the hearing. On May 11, 2001, a formal joint settlement was submitted to the Administrative Law Judge. To date there has been no formal action on the filed joint settlement. On December 11, 2001, the Commission approved an order dismissing the application because of the pending emergency rate increase request and SPPC's plans to file a GRC. This decision approved parts of the joint settlement agreement and the record of the proceeding will be available for use in future proceedings before the Commission.
California Assembly Bill 6X
On January 18, 2001, the California Legislature passed Assembly Bill (AB) 6X. AB 6X modified Section 377 of California law restricting the sale of generation assets. AB 6X states that no facility for the generation of electricity owned by a public utility may be disposed of prior to January 1, 2006. Since SPPC is a public utility serving California customers, the sale of SPPC's generation assets was halted. The sale of the Mohave Generating Station, in which NPC has a 14% undivided interest, was also stopped because Southern California Edison is an operating partner of that facility.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
SPR has evaluated its risk related to financial instruments whose values are subject to market sensitivity. Such instruments are fixed and variable rate debt, and preferred trust securities obligations, which were as follows on December 31, 2001, and 2000. Fair market value was determined using quoted market price for the same or similar issues or on the current rates offered for debt of the same remaining maturities.
Long-term debt (dollars in thousands):
Expected Maturity December 31, 2001 Date --------------------------------------------------------------------------------------------------------- Expected Maturities Amounts Weighted Avg Int Rate * Fair Market Value --------------------------------------------------------------------------------------------------------- Fixed Rate NPC SPPC SPR Consolidated Consolidated Consolidated ------------------------------------------------------- --------------------- ------------------- 2002 $ 15,000 $ 2,630 $ - $ 17,630 7.40% 2003 210,000 20,632 - 230,632 5.97% 2004 130,000 2,621 - 132,621 6.10% 2005 - 2,622 300,000 302,622 8.73% 2006 - 52,629 - 52,629 6.71% Thereafter 938,835 845,527 345,000 2,129,362 6.87% ------------------------------------------------------- --------------------- ------------------- Total Fixed Rate $1,293,835 $ 926,661 $ 645,000 $ 2,865,496 $ 2,953,374 ------------------------------------------------------- --------------------- ------------------- Variable Rate 2002 $ - $ - $ 100,000 $ 100,000 3.04% 2003 140,000 - 200,000 340,000 3.43% 2004 - - - - 2005 - - - - 2006 - - - - Thereafter 115,000 - - 115,000 1.82% ------------------------------------------------------- --------------------- ------------------- $ 255,000 $ - $ 300,000 $ 555,000 $ 549,400 ------------------------------------------------------- --------------------- ------------------- Preferred securities (fixed rate) After 2006 $ 188,872 $ - $ - $ 188,872 8.03% ------------------------------------------------------- --------------------- ------------------- $ 188,872 $ - $ - $ 188,872 $ 181,525 ------------------------------------------------------- --------------------- ------------------- Total $1,737,707 $ 926,661 $ 945,000 $ 3,609,368 $ 3,684,299 ----------------------=======================================================-------------------------------=================== |
Expected Maturity December 31, 2000 --------------------------------------------------------------------------------------------------------- Expected Maturities Amounts Weighted Avg Int Rate * Fair Market Value --------------------------------------------------------------------------------------------------------- Fixed Rate NPC SPPC SPR Consolidated Consolidated --------------------------------------------------------------------------------------------------------- 2001 $ 100 $ 19,620 $ - $ 19,720 5.57% 2002 15,000 2,626 - 17,626 7.40% 2003 - 20,632 - 20,632 5.63% 2004 130,000 2,621 - 132,621 6.20% 2005 - 2,622 300,000 302,622 8.73% Thereafter 588,942 497,311 - 1,086,253 6.65% ======================================================= ===================== =================== Total Fixed Rate $ 734,042 $ 545,432 $ 300,000 $ 1,579,474 $ 1,579,221 ------------------------------------------------------- --------------------- ------------------- Variable Rate 2001 $ 250,000 $ 200,000 $ - $ 450,000 7.48% 2002 - - 100,000 100,000 7.29% 2003 - - 200,000 200,000 7.24% 2004 - - - - 2005 - - - - Thereafter 115,000 80,000 - 195,000 4.37% ======================================================= --------------------- =================== $ 365,000 $ 280,000 $ 300,000 $ 945,000 $ 941,920 ------------------------------------------------------- --------------------- ------------------- Peferred securities (fixed rate) After 2005 $ 188,872 $ 48,500 $ - $ 237,372 8.15% $ 234,792 ======================================================= ===================== =================== Total $1,287,914 $ 873,932 $ 600,000 $ 2,761,846 $ 2,755,933 ----------------------=======================================================-------------------------------=================== |
* Weighted daily average rate for months ended December 31, 2001, and 2000.
COMMODITY PRICE RISK
SPR is exposed to commodity price risk primarily related to changes in the market price of electricity as well as changes in fuel costs incurred to generate electricity. See Purchased Power Procurement in Item 7, Management's Discussion And Analysis Of Financial Condition And Results Of Operations, for a discussion of the Utilities' purchased power procurement strategies.
The Utilities' efforts to manage energy commodity (electricity, natural gas, coal and oil) price risk are governed by a Board of Directors approved Energy Risk Management Policy. That policy is augmented by an IT system to track any commodity price exposure. The Energy Risk Management Policy sets forth business objectives, organizational structure, performance metrics and operating requirements. The policy also establishes guidelines for the Risk Management Committee ("RMC"), which is responsible for providing management advice and recommendations on energy risk management related issues. The RMC met periodically throughout 2001.
The Utilities' commodity risk management program establishes a control framework based on existing commercial practices. The program creates common predefined risk parameters and delineates management responsibilities and organizational relationships. The program requires that transaction accounting systems and procedures be maintained for systematically identifying, measuring, evaluating and responding to the variety of risks inherent in the Utilities' commercial activities. The program's control framework consists of a disclosure and reporting mechanism designed to keep management fully informed of the operation's compliance with performance parameters.
The objective of the Utilities' energy risk management program is to help management exercise informed judgments on risk assessment and management. Supporting activities are designed:
. To provide management with a quantification of the Utilities' cash flow requirements for fuel and purchased power;
. To provide management with a quantification of the Utilities' cash flow sensitivity to movements in energy markets;
. To provide management with a quantification of the expected retail rate impact attributable to expenditures for fuel and purchased power;
. To provide management with estimates of the sensitivity of retail rates to movements in energy markets;
. To extract market pricing information that can be used in future decisions; and
. To help to optimize the output from the Utilities' generation assets.
On March 1, 2001, deferred energy accounting procedures were applied to the Utilities' electric operations. Such procedures had been in place for SPPC's gas distribution company. Deferred energy accounting facilitates the recovery of costs incurred while procuring fuel and purchased power for SPPC and NPC.
The Utilities also monitor and manage credit risk with their trading counterparties. As of December 31, 2001, the Utilities have outstanding transactions with over 40 energy and financial services companies. The Utilities had net credit risk with only eleven of their trading counterparties totaling approximately $2 million as of December 31, 2001.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Page ---- Independent Auditors' Reports .......................................................................... 83-84 Financial Statements: Consolidated Balance Sheets as of December 31, 2001 and 2000 ................................... 85 Consolidated Statements of Income for the Years Ended December 31, 2001, 2000 and 1999 ......................................................................... 86 Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2001, 2000 and 1999 ............................................................ 87 Consolidated Statements of Common Shareholders' Equity for the Years Ended December 31, 2001, 2000 and 1999 ................................................ 87 Consolidated Statements of Cash Flows for the Years Ended December 31, 2001, 2000 and 1999 ............................................................ 88 Consolidated Statements of Capitalization as of December 31, 2001 and 2000 ..................... 89-90 Balance Sheets for Nevada Power Company as of December 31, 2001 and 2000 .................................................................. 91 Statements of Income for Nevada Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 92 Statements of Cash Flows for Nevada Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 93 Statements of Capitalization for Nevada Power Company as of December 31, 2001 and 2000 ..................................................... 94 Consolidated Balance Sheets for Sierra Pacific Power Company as of December 31, 2001 and 2000 .................................................................. 95 Consolidated Statements of Income for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 96 Consolidated Statements of Comprehensive Income for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ................................ 97 Consolidated Statements of Common Shareholders' Equity for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 .......................... 97 Consolidated Statements of Cash Flows for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 98 Consolidated Statements of Capitalization for Sierra Pacific Power Company as of December 31, 2001 and 2000 ..................................................... 99 Notes to Financial Statements .......................................................................... 100 |
INDEPENDENT AUDITORS' REPORT
To the Board of Directors and Stockholders of
Sierra Pacific Resources
Reno, Nevada
We have audited the accompanying consolidated balance sheets and consolidated statements of capitalization of Sierra Pacific Resources and subsidiaries (the Company) and the separate unconsolidated balance sheets and statements of capitalization of Nevada Power Company (NPC) as of December 31, 2001 and 2000, and the related statements of income, comprehensive income, common shareholders' equity, and cash flows for each of the three years in the period ended December 31, 2001. Our audit also included the consolidated and unconsolidated financial statement schedules listed in the Index at Item 14. These financial statements and financial statement schedules are the responsibility of the Company's and NPC's management. Our responsibility is to express an opinion on these financial statements and financial statement schedules based on our audits.
We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such financial statements present fairly, in all material respects, the consolidated financial position of the Company and the financial position of NPC as of December 31, 2001 and 2000, and the respective results of their operations and their cash flows for each of the three years in the period ended December 31, 2001 in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly in all material respects the information set forth therein.
Deloitte & Touche LLP
Reno, Nevada
February 22, 2002
INDEPENDENT AUDITORS' REPORT
To the Board of Directors and Shareholder of
Sierra Pacific Power Company
Reno, Nevada
We have audited the accompanying consolidated balance sheets and consolidated statements of capitalization of Sierra Pacific Power Company and subsidiaries as of December 31, 2001 and 2000, and the related consolidated statements of income, comprehensive income, common shareholder's equity, and cash flows for each of the three years in the period ended December 31, 2001. Our audits also included the financial statement schedule listed in the Index at Item 14. These financial statements and financial statement schedule are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedule based on our audits.
We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2001 and 2000, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2001, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly in all material respects the information set forth therein.
Deloitte & Touche LLP
Reno, Nevada
February 22, 2002
SIERRA PACIFIC RESOURCES
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
December 31, 2001 2000 ----------- ----------- ASSETS Utility Plant at Original Cost: Plant in service $ 5,683,296 $ 5,269,724 Less: accumulated provision for depreciation 1,777,517 1,636,657 ----------- ----------- 3,905,779 3,633,067 Construction work-in-progress 203,456 347,299 ----------- ----------- 4,109,235 3,980,366 ----------- ----------- Investments in subsidiaries and other property, net 128,892 135,062 ----------- ----------- Current Assets: Cash and cash equivalents 99,109 51,503 Accounts receivable less provision for uncollectible accounts: 2001-$39,335; 2000-$13,194 394,489 388,332 Deferred energy costs - electric (Note 1) 333,062 - Deferred energy costs - gas (Note 1) 19,805 - Federal income tax receivable 18,590 32,904 Materials, supplies and fuel, at average cost 94,167 75,132 Risk management assets (Note 22) 286,509 - Other 14,071 18,442 ----------- ----------- 1,259,802 566,313 ----------- ----------- Deferred Charges: Goodwill, net of amortization 312,145 320,256 Deferred energy costs - electric (Note 1) 854,778 - Deferred energy costs - gas (Note 1) 23,248 16,370 Federal income tax receivable 355,659 - Regulatory tax asset 169,738 175,509 Other regulatory assets 102,959 105,588 Risk management assets (Note 22) 61,058 - Risk management regulatory assets - net (Note 22) 664,383 - Other 139,417 116,965 ----------- ----------- 2,683,385 734,688 ----------- ----------- Net assets of discontinued operations (Note 17) - 261,479 ----------- ----------- $ 8,181,314 $ 5,677,908 =========== =========== CAPITALIZATION AND LIABILITIES Capitalization: Common shareholders' equity $ 1,702,322 $ 1,359,712 Accumulated other comprehensive income (6,986) - Preferred stock 50,000 50,000 SPPC/ NPC obligated mandatorily redeemable preferred trust securities 188,872 237,372 Long-term debt 3,376,105 2,133,679 ----------- ----------- 5,310,313 3,780,763 ----------- ----------- Current Liabilities: Short-term borrowings 177,000 213,074 Current maturities of long-term debt 122,010 472,527 Accounts payable 265,250 363,242 Accrued interest 37,565 30,184 Dividends declared 1,045 20,890 Accrued salaries and benefits 30,145 28,957 Deferred taxes on deferred energy costs 123,503 - Risk management liabilities (Note 22) 855,301 - Other current liabilities 15,678 10,013 ----------- ----------- 1,627,497 1,138,887 ----------- ----------- Commitments & Contingencies (Note 18) Deferred Credits: Deferred federal income taxes 412,658 406,310 Deferred investment tax credit 51,947 55,252 Deferred taxes on deferred energy costs 307,309 Regulatory tax liability 46,702 50,994 Customer advances for construction 108,179 109,962 Accrued retirement benefits 82,624 80,027 Risk management liabilities (Note 22) 163,636 - Other 70,449 55,713 ----------- ----------- 1,243,504 758,258 ----------- ----------- $ 8,181,314 $ 5,677,908 =========== =========== |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
(Dollars in Thousands, Except Per Share Amounts)
Year ended December 31, 2001 2000 1999 ------------ ------------ ------------ OPERATING REVENUES: Electric $ 4,424,237 $ 2,219,252 $ 1,236,702 Gas 145,652 100,803 38,958 Other 18,841 14,199 9,132 ------------ ------------ ------------ 4,588,730 2,334,254 1,284,792 ------------ ------------ ------------ OPERATING EXPENSES: Operation: Purchased power 4,052,077 1,116,375 373,456 Fuel for power generation 728,619 526,535 206,130 Gas purchased for resale 136,534 83,199 27,262 Deferral of energy costs - electric - net (1,136,148) 16,719 97,238 Deferral of energy costs - gas - net (23,170) (16,164) - Other 331,961 260,496 193,391 Maintenance 69,499 52,477 59,297 Depreciation and amortization 164,640 156,035 110,075 Taxes: Income taxes (1,230) (31,022) 25,298 Other than income 43,079 42,215 29,784 ------------ ------------ ------------ 4,365,861 2,206,865 1,121,931 ------------ ------------ ------------ OPERATING INCOME 222,869 127,389 162,861 ------------ ------------ ------------ OTHER INCOME: Allowance for other funds used during construction 474 2,813 2,339 Other income (expense) - net 38,723 2,646 (2,325) ------------ ------------ ------------ 39,197 5,459 14 ------------ ------------ ------------ Total Income Before Interest Charges 262,066 132,848 162,875 ------------ ------------ ------------ INTEREST CHARGES: Long-term debt 188,370 134,596 77,494 Other 24,161 35,887 26,229 Allowance for borrowed funds used during construction and capitalized interest (2,801) (10,634) (8,000) ------------ ------------ ------------ 209,730 159,849 95,723 ------------ ------------ ------------ INCOME (LOSS) BEFORE SPPC/NPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 52,336 (27,001) 67,152 Preferred dividend requirements of SPPC/NPC obligated mandatorily redeemable preferred trust securities (18,770) (18,914) (16,742) ------------ ------------ ------------ INCOME (LOSS) BEFORE PREFERRED STOCK DIVIDENDS 33,566 (45,915) 50,410 Preferred stock dividend requirements of subsidiary (3,700) (3,499) (2,200) ------------ ------------ ------------ INCOME (LOSS) FROM CONTINUING OPERATIONS 29,866 (49,414) 48,210 ------------ ------------ ------------ DISCONTINUED OPERATIONS: Income from operations of water business disposed of (net of income taxes of $888, $3,426 and $788 in 2001, 2000 and 1999, respectively) 1,022 9,634 3,540 Gain on disposal of water business (net of income taxes of $18,237) 25,845 - - ------------ ------------ ------------ NET INCOME (LOSS) $ 56,733 $ (39,780) $ 51,750 ============ ============ ============ Income (Loss) per share - Basic and Diluted Income (Loss) from continuing operations $ 0.34 $ (0.63) $ 0.77 Income from discontinued operations 0.01 0.12 0.06 Gain on disposal of water business 0.30 - - ------------ ------------ ------------ Net income (loss) $ 0.65 (0.51) $ 0.83 ============ ============ ============ Weighted Average Shares of Common Stock Outstanding 87,542,441 78,435,405 62,577,385 ============ ============ ============ Annual Dividends Paid Per Share of Common Stock $ 0.65 $ 1.000 $ 1.165 ============ ============ ============ |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Dollars in Thousands)
Year ended December 31, --------------------------------------------- 2001 2000 1999 ----------- ----------- ----------- NET INCOME (LOSS) $ 56,733 $ (39,780) $ 51,750 OTHER COMPREHENSIVE INCOME, NET OF TAX: Adoption of SFAS No. 133- Accounting for Derivative Instruments and Hedging Activities: Cummulative effect upon adoption of change in accounting principle as of January 1 (1,923) - - Change in market value of risk management assets and liabilities as of December 31 (5,063) - - Minimum pension liability adjustment - (513) 1,001 ----------- ----------- ----------- OTHER COMPREHENSIVE INCOME (6,986) (513) 1,001 ----------- ----------- ----------- COMPREHENSIVE INCOME $ 49,747 $ (40,293) $ 52,751 =========== =========== =========== |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY
(Dollars in Thousands)
Year ended December 31, --------------------------------------------- 2001 2000 1999 ----------- ----------- ----------- Common Stock: Balance at Beginning of Year $ 78,475 $ 78,414 $ 54,066 Stock purchase and dividend reimbursement 23,636 61 - Merger conversion - - 36,064 Merger cash consideration - - (11,716) ----------- ----------- ----------- Balance at End of Year 102,111 78,475 78,414 ----------- ----------- ----------- Other Paid-In Capital: Balance at Beginning of Year 1,295,221 1,293,990 683,156 Premium on sale of common stock 330,050 - - Common stock issuance costs (13,910) - - Purchase contract adjustment payments (13,676) - - CSIP, DRP, ESPP and other 949 1,231 1,409 Merger transactions - - 212,148 Revaluation of pension asset - - 66,103 Goodwill - - 331,174 ----------- ----------- ----------- Balance at End of Year 1,598,634 1,295,221 1,293,990 ----------- ----------- ----------- Retained Earnings (Deficit): Balance at Beginning of Year (13,984) 104,725 126,814 Income (loss) from continuing operations before preferred dividends 33,566 (45,915) 50,410 Income from discontinued operations (before preferred dividend allocation of $200, $401, and $196 in 2001, 2000, and 1999, respectively) 1,222 10,035 3,736 Gain on disposal of water business 25,845 - - Dividends declared and premium on redemption: Preferred stock of subsidiaries (3,900) (3,900) (2,721) Common stock (41,172) (78,929) (73,514) ----------- ----------- ----------- Balance at End of Year 1,577 (13,984) 104,725 ----------- ----------- ----------- Total Common Shareholders' Equity at End of Year $ 1,702,322 $ 1,359,712 $ 1,477,129 =========== =========== =========== |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
Year ended December 31, 2001 2000 1999 -------------- ------------- ------------ CASH FLOWS FROM OPERATING ACTIVITIES: Income (loss) from continuing operations before preferred dividends $ 33,566 $ (45,915) $ 50,410 Income from discontinued operations before preferred dividends 1,222 10,035 3,736 Gain on disposal of water business 25,845 - - Non-cash items included in income: Depreciation and amortization 168,100 163,370 113,236 Deferred taxes and deferred investment tax credit 85,917 (18,564) (16,543) AFUDC and capitalized interest (3,285) (13,858) (10,501) Deferral of energy costs - electric - net (1,187,840) 14,884 48,313 Deferral of energy costs - gas - net (26,683) - - Early retirement and severance amortization 3,121 4,196 1,748 Gain on disposal of water business (44,081) - - Other non-cash (11,473) 30,972 24,122 Changes in certain assets and liabilities, net of acquisition: Accounts receivable (1,841) (174,112) (7,393) Materials, supplies and fuel (18,682) (1,864) (3,846) Other current assets 4,248 (52,125) 155 Accounts payable (97,992) 224,794 49,655 Other current liabilities 14,752 16,359 (6,342) Other - net 9,885 27,724 (35,661) -------------- ------------- ------------ Net Cash Flows from Operating Activities (1,045,221) 185,896 211,089 -------------- ------------- ------------ CASH FLOWS USED IN INVESTING ACTIVITIES: Acquisition of business, net of cash acquired - - (448,311) Additions to utility plant (334,456) (359,774) (299,064) AFUDC and other charges to utility plant 3,285 15,227 (3,645) Customer refunds for construction 815 (889) 8,173 Contributions in aid of construction 27,481 16,446 13,053 -------------- ------------- ------------ Net cash used for utility plant (302,875) (328,990) (729,794) Proceeds from sale of assets of water business 318,882 - - (Investments in) disposal of subsidiaries and other property - net (6,335) (28,056) 1,366 -------------- ------------- ------------ Net Cash Used in Investing Activities 9,672 (357,046) (728,428) -------------- ------------- ------------ CASH FLOWS FROM FINANCING ACTIVITIES: (Decrease) increase in short-term borrowings (36,074) (547,310) 495,165 Proceeds from issuance of long-term debt 1,215,000 1,165,000 230,699 Retirement of long-term debt (323,091) (318,061) (63,293) Redemption of preferred stock (48,500) - (26,380) Sale of common stock 340,737 1,292 - Dividends paid (64,917) (83,057) (115,833) -------------- ------------- ------------ Net Cash Provided by Financing Activities 1,083,155 217,864 520,358 -------------- ------------- ------------ Net Increase in Cash and Cash Equivalents 47,606 46,714 3,019 Beginning balance in Cash and Cash Equivalents 51,503 4,789 1,770 -------------- ------------- ------------ Ending balance in Cash and Cash Equivalents $ 99,109 $ 51,503 $ 4,789 ============== ============= ============ Supplemental Disclosures of Cash Flow Information: Cash paid (received) during period for: Interest $ 208,390 $ 167,158 $ 127,063 Income taxes $ (55,022) $ 12,730 $ 43,719 |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
(Dollars in Thousands)
December 31, 2001 2000 ----------- ----------- Common Shareholders' Equity: Common stock $1.00 par value, authorized 250 million; issued and outstanding 2001: 102,111,000 shares; 2000, 78,475,000 shares $ 102,111 $ 78,475 Other paid-in capital 1,598,634 1,295,221 Retained earnings (deficit) 1,577 (13,984) ----------- ----------- Total Common Shareholders' Equity 1,702,322 1,359,712 ----------- ----------- Accumulated Other Comprehensive Loss (6,986) - ----------- ----------- Preferred Stock of Subsidiaries: Not subject to mandatory redemption Outstanding at December 31 Class A Series 1; $1.95 dividend 50,000 50,000 ----------- ----------- Preferred Securities of Subsidiaries: NPC obligated Mandatorily Redeemable Preferred Securities of NPC's Subsidiary Trust, NVP Capital I, holding solely $122.6 million principal amount of 8.2% Junior Subordinated Debentures of NPC, due 2037 118,872 118,872 NPC obligated Mandatorily Redeemable Preferred Securities of NPC's Subsidiary Trust, NVP Capital III, holding solely $72.2 million principal amount of 7.75% Junior Subordinated Debentures of NPC, due 2038 70,000 70,000 SPPC obligated Mandatorily Redeemable Preferred Securities of SPPC's Subsidiary Trust, SPPC Capital I, holding solely $50 million principal amount of 8.60% Junior Subordinated Debentures of SPPC, due 2036 - 48,500 ----------- ----------- Total Preferred Securities 188,872 237,372 ----------- ----------- Long-Term Debt: Unamortized bond premium and discount, net (959) (913) Debt Secured by First Mortgage Bonds 7.63% Series L due 2002 15,000 15,000 6.70% Series V due 2022 105,000 105,000 6.60%Series W due 2019 39,500 39,500 7.20% Series X due 2022 78,000 78,000 8.50% Series Z due 2023 35,000 35,000 2.00% Series Z due 2004 56 72 2.00% Series O due 2011 1,281 1,374 6.35% Series FF due 2012 1,000 1,000 6.55% Series AA due 2013 39,500 39,500 6.30% Series DD due 2014 45,000 45,000 6.65% Series HH due 2017 75,000 75,000 6.65% Series BB due 2017 17,500 17,500 6.55% Series GG due 2020 20,000 20,000 6.30% Series EE due 2022 10,250 10,250 6.95% to 8.61% Series A MTN due 2022 110,000 110,000 7.10% and 7.14% Series B MTNdue 2023 58,000 58,000 6.62% to 6.83% Series C MTN due 2006 50,000 50,000 5.90% Series JJ due 2023 9,800 9,800 5.90% Series KK due 2023 30,000 30,000 |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC RESOURCES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
(Dollars in Thousands)
Continued from previous page December 31, 2001 2000 ----------- ----------- 5.00% Series Y due 2024 3,072 3,138 6.70% Series II due 2032 21,200 21,200 5.47% Series D MTN due 2001 - 17,000 5.50% Series D MTN due 2003 5,000 5,000 5.59% Series D MTN due 2003 13,000 13,000 ----------- ----------- Subtotal 781,200 798,421 ----------- ----------- Industrial development revenue bonds 5.90% Series 1997A due 2032 52,285 52,285 5.90% Series 1995B due 2030 85,000 85,000 5.60% Series 1995A due 2030 76,750 76,750 5.50% Series 1995C due 2030 44,000 44,000 6.20% Series 1999B due 2004 130,000 130,000 ----------- ----------- Subtotal 388,035 388,035 ----------- ----------- Pollution control revenue bonds 6.38% due 2036 20,000 20,000 5.80% Series 1997B due 2032 20,000 20,000 5.30% Series 1995D due 2011 14,000 14,000 5.45% Series 1995D due 2023 6,300 6,300 5.35% Series 1995E due 2022 13,000 13,000 ----------- ----------- Subtotal 73,300 73,300 ----------- ----------- Variable Rate Notes Floating rate notes due 2001 - 200,000 Floating rate notes due 2001 - 150,000 Floating rate notes due 2001 - 100,000 Floating rate notes due 2003 140,000 - IDRB Series 2000A due 2020 100,000 100,000 PCRB Series 2000B due 2009 15,000 15,000 Water facilities notes maturing 2020 - 80,000 Floating Rate Notes due 2002 100,000 100,000 Floating Rate Notes due 2003 200,000 200,000 ----------- ----------- Subtotal 555,000 945,000 ----------- ----------- Debt Secured by General and Refunding Bonds: 8.25% Series A due 2011 350,000 - 8.00% Series A due 2008 320,000 - ----------- ----------- Subtotal 670,000 - ----------- ----------- Other Notes: 5.75% Series 2001 due 2036 80,000 - 6.00% Series B notes due 2003 210,000 - 8.75% Senior unsecured note Series 2000 due 2005 300,000 300,000 7.93% Senior unsecured notes due 2007 345,000 - ----------- ----------- Subtotal 935,000 300,000 ----------- ----------- Obligations under capital leases 78,313 81,815 ----------- ----------- Current maturities and sinking fund requirements (122,010) (472,531) ----------- ----------- Other 17,267 19,639 ----------- ----------- Total Long-Term Debt 3,376,105 2,133,679 ----------- ----------- TOTAL CAPITALIZATION $ 5,310,313 $ 3,780,763 =========== =========== |
The accompanying notes are an integral part of the financial statements.
NEVADA POWER COMPANY
BALANCE SHEETS
(Dollars in Thousands)
December 31, 2001 2000 ----------------- --------------- ASSETS Utility Plant at Original Cost: Plant in service $ 3,356,584 $ 3,089,705 Less: accumulated provision for depreciation 928,939 855,599 ----------------- --------------- 2,427,645 2,234,106 Construction work-in-progress 134,706 228,856 ----------------- --------------- 2,562,351 2,462,962 ----------------- --------------- Investment in Sierra Pacific Resources (Note 1A) 309,259 471,975 Investments in subsidiaries and other property, net 12,721 13,418 ----------------- --------------- 321,980 485,393 ----------------- --------------- Current Assets: Cash and cash equivalents 8,505 43,858 Accounts receivable less provision for uncollectible accounts: 2001-$30,861; 2000-$11,605 210,333 168,890 Deferred energy costs - electric (Note 1) 281,555 - Federal income tax receivable 18,590 18,728 Materials, supplies and fuel, at average cost 48,511 45,573 Risk management assets (Note 22) 200,829 - Other 6,698 10,205 ----------------- --------------- 775,021 287,254 ----------------- --------------- Deferred Charges: Deferred energy costs - electric (Note 1) 698,510 - Federal income tax receivable 295,818 - Regulatory tax asset 109,859 113,647 Other regulatory assets 31,588 32,583 Risk management assets (Note 22) 49,493 - Risk management regulatory assets - net (Note 22) 351,264 - Other 29,485 25,912 ----------------- --------------- 1,566,017 172,142 ----------------- --------------- $ 5,225,369 $ 3,407,751 ================= =============== CAPITALIZATION AND LIABILITIES Capitalization: Common shareholders' equity including $309,259 and $471,975 of equity in Sierra Pacific Resources in 2001 and 2000 (Note 1A) $ 1,702,322 $ 1,359,712 Accumulated other comprehensive income 520 - NPC obligated mandatorily redeemable preferred trust securities 188,872 188,872 Long-term debt 1,607,967 927,784 ----------------- --------------- 3,499,681 2,476,368 ----------------- --------------- Current Liabilities: Short-term borrowings 130,500 100,000 Current maturities of long-term debt 19,380 252,910 Accounts payable 202,555 157,808 Accrued interest 19,310 16,913 Dividends declared 71 86 Accrued salaries and benefits 12,450 12,297 Deferred taxes on deferred energy costs 98,544 - Risk management liabilities (Note 22) 522,508 - Other current liabilities 17,710 16,450 ----------------- --------------- 1,023,028 556,464 ----------------- --------------- Commitments & Contingencies (Note 18) Deferred Credits: Deferred federal income taxes 223,641 216,753 Deferred investment tax credit 23,533 25,163 Deferred taxes on deferred energy costs 244,479 - Regulatory tax liability 18,604 19,908 Customer advances for construction 61,454 65,588 Accrued retirement benefits 28,104 27,985 Risk management liabilities (Notes 22) 78,558 - Other 24,287 19,522 ----------------- --------------- 702,660 374,919 ----------------- --------------- $ 5,225,369 $ 3,407,751 ================= =============== |
The accompanying notes are an integral part of the financial statements.
NEVADA POWER COMPANY
STATEMENTS OF INCOME (LOSS)
(Dollars in Thousands, Except Per Share Amounts)
Year ended December 31, ------------ ------------ ------------ 2001 2000 1999 ------------ ------------ ------------ OPERATING REVENUES: Electric $ 3,025,103 $ 1,325,470 $ 977,262 OPERATING EXPENSES: Operation: Purchased power 3,026,336 671,396 293,600 Fuel for power generation 441,900 292,787 154,546 Deferral of energy costs-net (937,322) 16,719 97,238 Other 169,442 139,723 141,041 Maintenance 45,136 34,057 50,805 Depreciation and amortization 93,101 85,989 80,644 Taxes: Income taxes 17,775 (12,162) 19,943 Other than income 24,371 23,501 22,462 ------------ ------------ ------------ 2,880,739 1,252,010 860,279 ------------ ------------ ------------ OPERATING INCOME 144,364 73,460 116,983 ------------ ------------ ------------ OTHER INCOME (EXPENSE): Equity in (losses) earnings of Sierra Pacific Resources (Note 1A) (6,672) (31,852) 13,058 Allowance for other funds used during construction (382) 2,456 3,713 Other income (expense) - net 27,272 1,718 (1,824) ------------ ------------ ------------ 20,218 (27,678) 14,947 ------------ ------------ ------------ Total Income Before Interest Charges 164,582 45,782 131,930 ------------ ------------ ------------ INTEREST CHARGES: Long-term debt 81,599 64,513 64,454 Other 13,219 13,732 8,815 Allowance for borrowed funds used during construction and capitalized interest (2,141) (7,855) (8,356) ------------ ------------ ------------ 92,677 70,390 64,913 ------------ ------------ ------------ INCOME (LOSS) BEFORE NPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 71,905 (24,608) 67,017 Preferred dividend requirements of NPC obligated mandatorily redeemable preferred trust securities (15,172) (15,172) (15,172) ------------ ------------ ------------ INCOME (LOSS) BEFORE PREFERRED STOCK DIVIDENDS 56,733 (39,780) 51,845 Preferred stock dividend requirements - - (95) ------------ ------------ ------------ NET INCOME (LOSS) $ 56,733 $ (39,780) $ 51,750 ============ ============ ============ Net Income (Loss) Per Share - Basic $ 0.65 $ (0.51) $ 0.83 ============ ============ ============ - Diluted $ 0.65 $ (0.51) $ 0.83 ============ ============ ============ Weighted Average Shares of Common Stock Outstanding (000's) 87,542 78,435 62,577 ============ ============ ============ Dividends Paid Per Share of Common Stock $ 0.65 $ 1.000 $ 1.165 ============ ============ ============ |
The accompanying notes are an integral part of the financial statements.
NEVADA POWER COMPANY
STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
Year ended December 31, --------------------------------------- 2001 2000 1999 ----------- ---------- ----------- CASH FLOWS FROM OPERATING ACTIVITIES: Income (loss) before preferred dividends $ 56,733 $ (39,780) $ 51,845 Non-cash items included in income: Depreciation and amortization 93,102 85,989 80,643 Deferred taxes and deferred investment tax credit 55,085 (26,528) (18,913) AFUDC and capitalized interest (1,759) (10,311) (12,069) Deferral of energy costs - net (980,065) 14,884 48,313 Other non-cash 264 20,101 16,908 Equity in losses (earnings) of SPR (Note 1A) 6,672 31,852 (13,058) Changes in certain assets and liabilities, net of acquisition: Accounts receivable (41,444) (57,935) (11,795) Materials, supplies and fuel (2,938) (2,465) (3,502) Other current assets 3,507 (25,360) 1,778 Accounts payable 44,747 82,720 34,964 Other current liabilities 3,812 10,001 17,066 Other - net 4,882 30,543 (14,002) ----------- ---------- ----------- Net Cash Flows from Operating Activities (757,402) 113,711 178,178 ----------- ---------- ----------- CASH FLOWS USED IN INVESTING ACTIVITIES: Additions to utility plant (200,852) (204,505) (223,963) AFUDC and other charges to utility plant 1,759 11,622 (2,184) Customer refunds for construction (4,134) (3,753) 5,228 Contributions in aid of construction 6,331 - - ----------- ---------- ----------- Net cash used for utility plant (196,896) (196,636) (220,919) (Investments in) disposal of subsidiaries and other property - net (115) - 1,499 ----------- ---------- ----------- Net Cash Used in Investing Activities (197,011) (196,636) (219,420) ----------- ---------- ----------- CASH FLOWS FROM FINANCING ACTIVITIES: Increase (decrease) in short-term borrowings 30,500 (82,000) 77,000 Proceeds from issuance of long-term debt 815,000 365,000 129,900 Retirement of long-term debt (368,347) (205,152) (60,283) Change in funds held in trust - - 9 Redemption of preferred stock - - (3,265) Investment of SPR 474,921 137,000 18,000 Dividends paid (33,014) (88,308) (121,646) ----------- ---------- ----------- Net Cash Provided by Financing Activities 919,060 126,540 39,715 ----------- ---------- ----------- Net (Decrease) Increase in Cash and Cash Equivalents (35,353) 43,615 (1,527) Beginning balance in Cash and Cash Equivalents 43,858 243 1,770 ----------- ---------- ----------- Ending balance in Cash and Cash Equivalents $ 8,505 $ 43,858 $ 243 =========== ========== =========== Supplemental Disclosures of Cash Flow Information: Cash paid (received) during period for: Interest $ 90,280 $ 71,430 $ 91,196 Income taxes $ (13,702) $ 6,500 $ 38,219 |
The accompanying notes are an integral part of the financial statements.
NEVADA POWER COMPANY
STATEMENTS OF CAPITALIZATION
(Dollars in Thousands)
December 31, 2001 2000 -------------- ------------- Common Shareholder's Equity: Common stock issued $ 1 $ 1 Other paid-in capital 1,367,106 892,185 Retained earnings (deficit) 25,956 (4,449) Equity in Sierra Pacific Resources (Note 1A) 309,259 471,975 -------------- ------------- Total Common Shareholder's Equity 1,702,322 1,359,712 -------------- ------------- Accumulated Other Comprehensive Income 520 - -------------- ------------- Preferred Securities: NPC obligated Mandatorily Redeemable Preferred Securities of NPC's Subsidiary Trust, NVP Capital I, holding solely $122.6 million principal amount of 8.2% Junior Subordinated Debentures of NPC, due 2037 118,872 118,872 NPC obligated Mandatorily Redeemable Preferred Securities of NPC's Trust, NVP Capital III, holding solely $72.2 million principal amount of 7.75% Junior Subordinated Debentures of NPC, due 2038 70,000 70,000 -------------- ------------- Total Preferred Securities 188,872 188,872 -------------- ------------- Long-Term Debt: Unamortized bond premium and discount, net 2 (163) Debt Secured by First Mortgage Bonds: 7.63% Series L due 2002 15,000 15,000 6.70% Series V due 2022 105,000 105,000 6.60% Series W due 2019 39,500 39,500 7.20% Series X due 2022 78,000 78,000 8.50% Series Z due 2023 35,000 35,000 -------------- ------------- Subtotal 272,502 272,337 -------------- ------------- Industrial development revenue bonds 5.90% Series 1997A due 2032 52,285 52,285 5.90% Series 1995B due 2030 85,000 85,000 5.60% Series 1995A due 2030 76,750 76,750 5.50% Series 1995C due 2030 44,000 44,000 6.20% Series 1999B due 2004 130,000 130,000 -------------- ------------- Subtotal 388,035 388,035 -------------- ------------- Pollution Control Revenue Bonds 6.38% due 2036 20,000 20,000 5.80% Series 1997B due 2032 20,000 20,000 5.30% Series 1995D due 2011 14,000 14,000 5.45% Series 1995D due 2023 6,300 6,300 5.35% Series 1995E due 2022 13,000 13,000 -------------- ------------- Subtotal 73,300 73,300 -------------- ------------- Variable Rate Notes Floating rate notes due 2001 - 150,000 Floating rate notes due 2001 - 100,000 Floating rate notes due 2003 140,000 - IDRB Series 2000A due 2020 100,000 100,000 PCRB Series 2000B due 2009 15,000 15,000 -------------- ------------- Subtotal 255,000 365,000 -------------- ------------- Debt Secured by General and Refunding Bonds: 8.25% Series A due 2011 350,000 - -------------- ------------- Other Notes: 6.0% Series B notes due 2003 210,000 - -------------- ------------- Obligation under capital leases 78,313 81,815 -------------- ------------- Current maturities and sinking fund requirements (19,380) (252,911) -------------- ------------- Other, excluding current portion 197 208 -------------- ------------- Total Long-Term Debt 1,607,967 927,784 -------------- ------------- TOTAL CAPITALIZATION $ 3,499,681 $ 2,476,368 ============== ============= |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED BALANCE SHEETS
(Dollars in Thousands)
December 31, 2001 2000 ---------- ---------- ASSETS Utility Plant at Original Cost: Plant in service $2,326,712 $2,180,019 Less: accumulated provision for depreciation 848,578 781,058 ---------- ---------- 1,478,134 1,398,961 Construction work-in-progress 68,750 118,442 ---------- ---------- 1,546,884 1,517,403 ---------- ---------- Investments in subsidiaries and other property, net 57,185 60,047 ---------- ---------- Current Assets: Cash and cash equivalents 11,772 5,348 Accounts receivable less provision for uncollectible accounts: 2001 - $8,474; 2000 - $1,589 194,698 153,547 Deferred energy costs - electric 51,507 -- Deferred energy costs - gas 19,805 -- Federal income tax receivable -- 21,958 Materials, supplies and fuel, at average cost 42,290 29,209 Risk management assets (Note 22) 85,680 -- Other 5,935 7,894 ---------- ---------- 411,687 217,956 ---------- ---------- Deferred Charges: Deferred energy costs - electric 156,268 -- Deferred energy costs - gas 23,248 16,370 Federal income tax receivable 41,040 -- Regulatory tax asset 59,879 61,862 Other regulatory assets 51,146 61,236 Risk management assets (Note 22) 11,565 -- Risk management regulatory assets - net (Note 22) 313,119 -- Other 13,886 12,036 ---------- ---------- 670,151 151,504 ---------- ---------- Net assets of discontinued operations (Note 17) -- 261,479 ---------- ---------- $2,685,907 $2,208,389 ========== ========== CAPITALIZATION AND LIABILITIES Capitalization: Common shareholder's equity $ 692,654 $ 604,795 Accumulated other comprehensive income 247 -- Preferred stock 50,000 50,000 SPPC obligated mandatorily redeemable preferred trust securities -- 48,500 Long-term debt 923,070 605,816 ---------- ---------- 1,665,971 1,309,111 ---------- ---------- Current Liabilities: Short-term borrowings 46,500 108,962 Current maturities of long-term debt 2,630 219,616 Accounts payable 95,555 166,134 Accrued interest 8,408 6,992 Dividends declared 974 23,975 Accrued salaries and benefits 15,466 15,475 Deferred taxes on deferred energy costs 24,959 -- Risk management liabilities (Note 22) 332,793 -- Other current liabilities 3,387 2,932 ---------- ---------- 530,672 544,086 ---------- ---------- Commitments & Contingencies (Note 18) Deferred Credits: Deferred federal income taxes 178,533 179,106 Deferred investment tax credit 28,414 30,088 Deferred taxes on deferred energy costs 62,831 -- Regulatory tax liability 28,098 31,087 Customer advances for construction 46,725 41,776 Accrued retirement benefits 43,028 44,374 Risk management liabilities (Note 22) 77,324 -- Other 24,311 28,761 ---------- ---------- 489,264 355,192 ---------- ---------- $2,685,907 $2,208,389 ========== ========== |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED STATEMENTS OF INCOME
(Dollars in Thousands)
December 31, 2001 2000 1999 ----------- ----------- ----------- OPERATING REVENUES: Electric $ 1,399,134 $ 893,782 $ 609,197 Gas 145,652 100,803 100,177 ----------- ----------- ----------- 1,544,786 994,585 709,374 ----------- ----------- ----------- OPERATING EXPENSES: Operation: Purchased power 1,025,741 444,979 179,781 Fuel for power generation 286,719 233,748 115,065 Gas purchased for resale 136,534 83,199 68,125 Deferral of energy costs - electric - net (198,826) -- -- Deferral of energy costs - gas - net (23,170) (16,164) -- Other 117,627 96,438 92,745 Maintenance 24,363 18,420 20,309 Depreciation and amortization 70,358 69,350 69,762 Taxes: Income taxes 8,507 (672) 33,870 Other than income 17,965 18,152 17,014 ----------- ----------- ----------- 1,465,818 947,450 596,671 ----------- ----------- ----------- OPERATING INCOME 78,968 47,135 112,703 ----------- ----------- ----------- OTHER INCOME (EXPENSE): Allowance for other funds used during construction 856 357 (1,370) Other income (expense) - net 8,489 (2,429) (673) ----------- ----------- ----------- 9,345 (2,072) (2,043) ----------- ----------- ----------- Total Income 88,313 45,063 110,660 ----------- ----------- ----------- INTEREST CHARGES: Long-term debt 55,199 36,865 31,151 Other 7,433 11,312 11,286 Allowance for borrowed funds used during construction and capitalized interest (660) (2,779) (141) ----------- ----------- ----------- 61,972 45,398 42,296 ----------- ----------- ----------- INCOME (LOSS) BEFORE SPPC OBLIGATED MANDATORILY REDEEMABLE PREFERRED TRUST SECURITIES 26,341 (335) 68,364 Preferred dividend requirements of SPPC obligated mandatorily redeemable preferred trust securities (3,598) (3,742) (3,749) ----------- ----------- ----------- INCOME (LOSS) BEFORE PREFERRED DIVIDENDS 22,743 (4,077) 64,615 Preferred dividend requirements and premium paid on redemption (3,700) (3,499) (4,957) ----------- ----------- ----------- NET INCOME (LOSS) FROM CONTINUING OPERATIONS 19,043 (7,576) 59,658 ----------- ----------- ----------- DISCONTINUED OPERATIONS: Income from operations of water business disposed of (net of income taxes of $888, $3,426 and $2,172 in 2001, 2000 and 1999 respectively) 1,022 9,634 6,583 Gain on disposal of water business (net of income taxes of $18,237) 25,845 -- -- ----------- ----------- ----------- NET INCOME $ 45,910 $ 2,058 $ 66,241 =========== =========== =========== |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Dollars in Thousands)
Year ended December 31, --------------------------- 2001 2000 1999 ------- ------- ------- NET INCOME $45,910 $ 2,058 $66,241 OTHER COMPREHENSIVE INCOME, NET OF TAX: Adoption of SFAS No. 133- Accounting for Derivative Instruments and Hedging Activities: Cumulative effect upon adoption of change in 211 -- -- accounting principle as of January 1 Change in market value of risk management and liabilities as of December 31 36 ------- ------- ------- OTHER COMPREHENSIVE INCOME 247 -- -- ------- ------- ------- COMPREHENSIVE INCOME $46,157 $ 2,058 $66,241 ======= ======= ======= |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDER'S EQUITY
(Dollars in Thousands)
Year ended December 31, 2001 2000 1999 --------- --------- --------- Common Stock: Balance at Beginning of Year and End of Year $ 4 $ 4 $ 4 --------- --------- --------- Other Paid-In Capital: Balance at Beginning Year 598,684 584,684 562,684 Additional investment by parent company 104,949 14,000 22,000 --------- --------- --------- Balance at End of Year 703,633 598,684 584,684 --------- --------- --------- Retained (Deficit) Earnings: Balance at Beginning of Year 6,107 89,050 98,679 Income (Loss) before preferred dividends of continuing operations 22,743 (4,077) 64,615 Income from discontinued operations (before preferred dividend allocation of $200, $401, and $528 in 2001, 2000, and 1999, respectively) 1,222 10,034 7,111 Gain on disposal of water business 25,845 -- -- Preferred stock dividends declared and premium on redemption (3,900) (3,900) (5,355) Common stock dividends declared (63,000) (85,000) (76,000) --------- --------- --------- Balance at End of Year (10,983) 6,107 89,050 --------- --------- --------- Total Common Shareholder's Equity at End of Year $ 692,654 $ 604,795 $ 673,738 ========= ========= ========= |
The accompanying notes are an integral part of the financial statements
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in Thousands)
Year Ended December 31, 2001 2000 1999 --------- --------- --------- Cash Flows From Operating Activities: Income (loss) from continuing operations before preferred dividends $ 22,743 $ (4,077) $ 64,615 Income from discontinued operations before preferred dividends 1,222 10,035 7,111 Gain on disposal of water business 25,845 -- -- Non-cash items included in income: Depreciation and amortization 73,818 76,685 77,373 Deferred taxes and investment tax credits 57,382 7,935 5,595 AFUDC and capitalized interest (1,526) (3,547) 1,033 Deferral of energy costs - electric - net (207,775) -- -- Deferral of energy costs - gas - net (26,683) -- -- Early retirement and severance amortization 3,121 4,196 4,194 Gain on disposal of water business (44,081) -- -- Other non-cash (386) 10,871 8,644 Changes in certain assets and liabilities: Accounts receivable (36,835) (41,604) 685 Materials, supplies and fuel (12,728) 508 (4,294) Other current assets 1,836 (26,749) (411) Accounts payable (70,579) 87,643 12,459 Other current liabilities 2,380 1,231 (23,257) Other-net (1,333) (11,117) (31,418) --------- --------- --------- Net Cash Flows from Operating Activities (213,579) 112,010 122,329 --------- --------- --------- Cash Flows From (Used in) Investing Activities: Additions to utility plant (133,604) (155,269) (142,306) AFUDC and other charges to utility plant 1,526 3,605 (768) Customer refunds for construction 4,949 2,864 5,120 Contributions in aid of construction 21,150 16,446 21,823 --------- --------- --------- Net cash used for utility plant (105,979) (132,354) (116,131) Proceeds from sale of assets of water business 318,882 -- -- Disposal of (investments in) subsidiaries and other property - net 2,747 2,292 (28,720) --------- --------- --------- Net Cash From (Used in) Investing Activities 215,650 (130,062) (144,851) --------- --------- --------- Cash Flows From Financing Activities (Decrease) increase in short-term borrowings (62,462) (5,915) 1,972 Proceeds from issuance of long-term debt 400,000 200,000 124,495 Retirement of long-term debt (299,732) (102,797) (33,270) Redemption of preferred stock (48,500) -- (23,115) Investment by parent company 104,948 14,000 22,000 Dividends paid and premiums on preferred redemption (89,901) (84,899) (81,746) --------- --------- --------- Net Cash Provided by Financing Activities 4,353 20,389 10,336 --------- --------- --------- Net Increase (Decrease) in Cash and Cash Equivalents 6,424 2,337 (12,186) Beginning Balance in Cash and Cash Equivalents 5,348 3,011 15,197 --------- --------- --------- Ending Balance in Cash and Cash Equivalents $ 11,772 $ 5,348 $ 3,011 ========= ========= ========= Supplemental Disclosures of Cash Flow Information: Cash paid (received) during year for: Interest $ 66,597 $ 57,331 $ 54,303 Income taxes (25,632) 9,644 28,604 |
The accompanying notes are an integral part of the financial statements.
SIERRA PACIFIC POWER COMPANY
CONSOLIDATED STATEMENTS OF CAPITALIZATION
(Dollars in Thousands)
December 31, 2001 2000 ----------- ----------- Common Shareholder's Equity: Common stock, $3.75 par value, 1,000 shares authorized, issued and outstanding $ 4 $ 4 Other paid-in capital 703,633 598,684 Retained (deficit) earnings (10,983) 6,107 ----------- ----------- Total Common Shareholder's Equity 692,654 604,795 ----------- ----------- Accumulated Other Comprehensive Income 247 -- ----------- ----------- Cumulative Preferred Stock: Not subject to mandatory redemption $25 stated value Class A Series 1; $1.95 dividend 50,000 50,000 ----------- ----------- Preferred Securities SPPC-obligated mandatorily redeemable preferred securites of SPPC's subsidiary trust, Sierra Pacific Power Capital I, holding solely $50 million principal amount of 8.60% junior subordinated debentures of the Company, due 2036 -- 48,500 ----------- ----------- Long Term Debt: Unamortized bond premium and discount, net (961) (750) Debt Secured by First Mortgage Bonds 2.00% Series Z due 2004 56 72 2.00% Series O due 2011 1,281 1,374 6.35% Series FF due 2012 1,000 1,000 6.55% Series AA due 2013 39,500 39,500 6.30% Series DD due 2014 45,000 45,000 6.65% Series HH due 2017 75,000 75,000 6.65% Series BB due 2017 17,500 17,500 6.55% Series GG due 2020 20,000 20,000 6.30% Series EE due 2022 10,250 10,250 6.95% to 8.61% Series A MTN due 2022 110,000 110,000 7.10% and 7.14% Series B MTN due 2023 58,000 58,000 6.62% to 6.83% Series C MTN due 2006 50,000 50,000 5.90% Series JJ due 2023 9,800 9,800 5.90% Series KK due 2023 30,000 30,000 5.00% Series Y due 2024 3,072 3,138 6.70% Series II due 2032 21,200 21,200 5.47% Series D MTN due 2001 -- 17,000 5.50% Series D MTN due 2003 5,000 5,000 5.59% Series D MTN due 2003 13,000 13,000 ----------- ----------- Subtotal 508,698 526,084 ----------- ----------- Variable Rate Notes Water facilities notes maturing 2020 -- 80,000 Floating rate notes due 2001 -- 200,000 ----------- ----------- Subtotal -- 280,000 ----------- ----------- Debt Secured by General and Refunding Bonds 8.00% Series A due 2008 320,000 -- ----------- ----------- Other Notes: 5.75% Series 2001 due 2036 80,000 -- ----------- ----------- Other 17,002 19,348 ----------- ----------- Current maturities and sinking fund requirements (2,630) (219,616) ----------- ----------- Total Long-Term Debt 923,070 605,816 ----------- ----------- TOTAL CAPITALIZATION $ 1,665,971 $ 1,309,111 =========== =========== |
The accompanying notes are an integral part of the financial statements.
NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
The significant accounting policies for both utility and non-utility operations are as follows:
General
The consolidated financial statements include the accounts of Sierra Pacific Resources (SPR) and its wholly-owned subsidiaries, Nevada Power Company (NPC), Sierra Pacific Power Company (SPPC), Tuscarora Gas Pipeline Company (TGPC), Sierra Pacific Communications (SPC), Lands of Sierra, Inc. (LOS), Sierra Energy Company dba e.three (e.three), Nevada Electric Investment Company (NEICO), Sierra Pacific Energy Company (SPE), Sierra Water Development Company (SWDC) and, Sierra Gas Holding Company (SGHC). All significant intercompany balances and intercompany transactions have been eliminated in consolidation. See Note 2 for additional information regarding the presentation of consolidated financial results pursuant to the 1999 merger of SPR and NPC.
NPC is an operating public utility that provides electric service in Clark County in southern Nevada. The assets of NPC represent 60% of the consolidated assets of SPR at December 31, 2001. NPC provides electricity to approximately 639,000 customers in the communities of Las Vegas, North Las Vegas, Henderson, Searchlight, Laughlin and adjoining areas. Service is also provided to Nellis Air Force Base and the Department of Energy at Mercury and Jackass Flats at the Nevada Test Site. The consolidated financial statements of SPR include the accounts of NPC's wholly owned subsidiaries, NVP Capital I and NVP Capital III.
SPPC is an operating public utility that provides electric service in northern Nevada and northeastern California. SPPC also provides natural gas service in the Reno/Sparks area of Nevada. The assets of SPPC represent 33% of the consolidated assets of SPR at December 31, 2001. SPPC provides electricity to approximately 315,000 customers in a 50,000 square mile service area including western, central and northeastern Nevada, including the cities of Reno, Sparks, Carson City, Elko, and a portion of eastern California, including the Lake Tahoe area. The consolidated financial statements of SPR include the accounts of SPPC's wholly owned subsidiaries, Pinon Pine Corporation, Pinon Pine Investment Company, GPSF-B, SPPC Funding LLC, and Sierra Pacific Power Capital I.
The Utilities' accounts for electric operations and SPPC's accounts for gas operations are maintained in accordance with the Uniform System of Accounts prescribed by the Federal Energy Regulatory Commission ("FERC").
TGPC is a partner in a joint venture that developed, constructed, and operates a natural gas pipeline serving the expanding gas market in the Reno area and certain northeastern California markets. TGPC accounts for its joint venture interest under the equity method. e.three provides comprehensive energy services in commercial and industrial markets on a regional basis. SPE markets a package of telecommunication products and services. SPC was formed in 1999 to provide telecommunications services using fiber optic cable technology in both northern and southern Nevada. Also, SPC and a subsidiary of Montana Power Company are in a partnership that is constructing a fiber optic line between Salt Lake City, Utah and Sacramento, CA.
The preparation of consolidated financial statements in conformity with generally accepted accounting principles in the United States of America requires management to make estimates and assumptions that affect the reported amounts of certain assets and liabilities. These estimates and assumptions also affect the disclosure
of contingent assets and liabilities at the date of the financial statements and the reported amounts of certain revenues and expenses during the reporting period. Actual results could differ from these estimates.
Certain reclassifications of prior year information have been made for comparative purposes but have not affected previously reported net income or common shareholders' equity.
Deferral of Energy Costs
Nevada and California statutes permit regulated utilities to, from time-to-time, adopt deferred energy accounting procedures. The intent of these procedures is to ease the effect of fluctuations in the cost of purchased gas, fuel and purchased power. Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates, that excess is not recorded as a current expense on the income statement but rather is deferred and recorded as an asset on the balance sheet. Conversely, a liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs. These excess amounts are reflected in adjustments to rates and recorded as revenue or expense in future time periods. AB 369 requires the Utilities to use deferred energy accounting for their respective electric operations beginning on March 1, 2001, and to file applications to clear their respective deferred energy account balances at least every 12 months. See Note 3 for additional information on the deferred energy accounting provisions of AB 369.
NPC utilized deferred energy accounting procedures in 1999, and part of 2000. NPC ceased utilizing deferred energy accounting effective August 1, 2000, and resumed those procedures on March 1, 2001. During 1999, SPPC did not employ deferred energy accounting procedures, but resumed those procedures for natural gas operations as of January 1, 2000, and for its electric operations on March 1, 2001.
Utility Plant
In addition to direct labor and material costs, the Utilities also charge the following to the cost of constructing utility plant: the cost of time spent by administrative employees in planning and directing construction work; property taxes; employee benefits (including such costs as pensions, postretirement and postemployment benefits, vacations and payroll taxes); and an allowance for funds used during construction (AFUDC).
The original cost of plant retired or otherwise disposed of and the cost of removal less salvage is generally charged to the accumulated provision for depreciation. The cost of current repairs and minor replacements is charged to operating expenses when incurred. The cost of renewals and betterments is capitalized.
Allowance For Funds Used During Construction and Capitalized Interest
As part of the cost of constructing utility plant, the Utilities capitalize AFUDC. AFUDC represents the cost of borrowed funds and, where appropriate, the cost of equity funds used for construction purposes in accordance with rules prescribed by the FERC and the Public Utility Commission of Nevada ("PUCN"). AFUDC is capitalized in the same manner as construction labor and material costs, with an offsetting credit to "other income" for the portion representing the cost of equity funds and as a reduction of interest charges for the portion representing borrowed funds. Recognition of this item as a cost of utility plant is in accordance with established regulatory ratemaking practices. Such practices permit the utility to earn a fair return on, and recover in rates charged for utility services, all capital costs. This is accomplished by including such costs in the rate base and in the provision for depreciation. NPC's AFUDC rates used during 2001, 2000, and 1999 were 8.32%, 8.34%, and 8.55%, respectively. SPPC's AFUDC rates used during 2001, 2000, and 1999 were 7.94%,
7.17%, and 6.09%, respectively. As specified by the PUCN, certain projects were assigned a lower AFUDC rate due to specific low-interest-rate financings directly associated with those projects.
Depreciation
Depreciation is calculated using the straight-line composite method over the estimated remaining service lives of the related properties. NPC's depreciation provision for 2001, 2000, and 1999, as authorized by the PUCN and stated as a percentage of the original cost of depreciable property, was approximately 2.9%. SPPC's depreciation provision for 2001, 2000, and 1999, as authorized by the PUCN and stated as a percentage of the original cost of depreciable property, was approximately 3.21%, 3.21%, and 3.14%, respectively.
Cash and Cash Equivalents
Cash is comprised of cash on hand and working funds. Cash equivalents consist of high quality investments in money market funds.
Regulatory Accounting and Other Regulatory Assets
The Utilities' rates are currently subject to the approval of the PUCN and are designed to recover the cost of providing generation, transmission and distribution services. As a result, the Utilities qualify for the application of Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the Effects of Certain Types of Regulation", issued by the Financial Accounting Standards Board (FASB). This statement recognizes that the rate actions of a regulator can provide reasonable assurance of the existence of an asset and requires the capitalization of incurred costs that would otherwise be charged to expense where it is probable that future revenue will be provided to recover these costs. SFAS No. 71 prescribes the method to be used to record the financial transactions of a regulated entity. The criteria for applying SFAS No. 71 include the following: (i) rates are set by an independent third party regulator, (ii) approved rates are intended to recover the specific costs of the regulated products or services, and (iii) rates that are set at levels that will recover costs can be charged to and collected from customers. SFAS No. 101, "Regulated Enterprises-Accounting for the Discontinuation of Application of FASB Statement No. 71", requires that an enterprise whose operations cease to meet the qualifying criteria of SFAS No. 71 discontinue the application of that statement by eliminating the effects of any actions of regulators that had been previously recognized.
In conformity with SFAS No. 71, the accounting for the Utilities conforms to generally accepted accounting principles as applied to regulated public utilities and as prescribed by the agencies and commissions of the jurisdictions in which they operate. In accordance with these principles, certain costs that would otherwise be charged to expense or capitalized as plant costs are deferred as regulatory assets based on expected recovery from customers in future rates. Management's expected recovery of deferred costs is based upon specific ratemaking decisions or precedent for each item. The following other regulatory assets were included in the consolidated balance sheets of SPR as of December 31 (dollars in thousands):
DESCRIPTION 2001 2000 AMORTIZATION PERIODS --------------------------------------- ---- ---- --------------------------- Early retirement and severance offers $ 7,701 $ 12,567 Various through 2004 Loss on reacquired debt 32,882 32,548 Various through 2030 Plant assets 3,783 3,964 Various through 2031 Merger transition costs 10,543 8,275 To be determined Merger severance/relocation 21,851 22,434 To be determined Merger goodwill 19,675 11,533 To be determined Other costs 6,524 14,267 Various ---------- --------- Total $ 102,959 $ 105,588 ========= ========= |
Currently, the electric utility industry is predominantly regulated on a basis designed to recover the cost of providing electric power to its retail and wholesale customers. If cost-based regulation were to be discontinued in the industry for any reason, including competitive pressure on the cost-based prices of electricity, profits could be reduced, and utilities might be required to reduce their asset balances to reflect a market basis less than cost. Discontinuance of cost-based regulation would also require affected utilities to write off their associated regulatory assets. Management cannot predict the potential impact, if any, of these competitive forces on the Utilities' future financial position and results of operations.
Management periodically assesses whether the requirements for application of SFAS 71 are satisfied. The provisions of AB 369, signed into law in April 2001, include the repeal of all statutes authorizing retail competition in Nevada's electric utility industry. Accordingly, the Utilities continue to apply regulatory accounting to the generation, transmission and distribution portions of their businesses.
Federal Income Taxes and Investment Tax Credits
SPR and its subsidiaries file a consolidated federal income tax return. Current income taxes are allocated based on SPR's and each subsidiary's respective taxable income or loss and investment tax credits as if each subsidiary filed a separate return. Deferred taxes are provided on temporary differences at the statutory income tax rate in effect as of the most recent balance sheet date.
SPR accounts for income taxes in accordance with SFAS No. 109, "Accounting for Income Taxes." SFAS No. 109 requires recognition of deferred tax liabilities and assets for the future tax consequences of events that have been included in the consolidated financial statements or tax returns. Under this method, deferred tax liabilities and assets are determined based on the difference between the financial statement and tax bases of assets and liabilities using enacted tax rates in effect for the year in which the differences are expected to reverse.
For regulatory purposes, the Utilities are authorized to provide for deferred taxes on the difference between straight-line and accelerated tax depreciation on post-1969 utility plant expansion property, deferred energy, and certain other differences between financial reporting and taxable income, including those added by the Tax Reform Act of 1986 (TRA). In 1981, the Utilities began providing for deferred taxes on the benefits of using the Accelerated Cost Recovery System for all post-1980 property. In 1987, the TRA required the Utilities to begin providing deferred taxes on the benefits derived from using the Modified Accelerated Cost Recovery System.
Investment tax credits are no longer available to the Utilities. The deferred investment tax credits are being amortized over the estimated service lives of the related properties.
Revenues
Operating revenues include billed and unbilled utility revenues. The accrual for unbilled revenues represents amounts owed to the Utilities for service provided to customers for which the customers have not yet been billed. These unbilled amounts are also included in accounts receivable.
Recent Pronouncements
Financial Accounting Standards Board
In June 2001, the FASB issued three new pronouncements, SFAS No. 141, "Business Combinations," SFAS No. 142, "Goodwill and Other Intangible Assets," and SFAS No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 141 requires that the purchase method of accounting be used for all business combinations initiated after June 30, 2001. SFAS No. 142, adopted January 1, 2002, changes the accounting for goodwill from an amortization method to one requiring at least an annual review for impairment. Due to the regulatory treatment anticipated for most of SPR's goodwill, Management does not expect SFAS No. 142 to have a material effect on the financial position or results of operations of SPR, NPC, and SPPC. SFAS No. 143, effective for fiscal years beginning after June 15, 2002, requires an entity to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. Management does not expect the adoption of SFAS No. 143 to have a material effect on the financial position or results of operations of SPR, NPC, and SPPC.
In August 2001, the FASB issued SFAS No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets." This standard provides guidance on the impairment of long-lived assets and for long-lived assets to be disposed of. The standard supersedes the current authoritative literature on impairments as well as disposal of a segment of a business and was adopted January 1, 2002.
Note 1A. FINANCIAL STATEMENTS OF NEVADA POWER COMPANY
As described in Note 2 that follows, NPC was deemed to be the acquirer of SPR for accounting purposes as reflected in the SPR Consolidated Financial Statements. However, after the merger with SPR and as a result of the structure of the transactions, NPC is a separate legal entity, which is a wholly owned subsidiary of SPR. As a legal matter, NPC does not own any equity interest in SPR. The audited NPC Financial Statements accommodate the presentation of financial information of NPC on a stand-alone basis by summarizing all non-NPC financial information into a few items on each of the Financial Statements. These summarized items are repeated below (in 000's):
Non-NPC financial items on the NPC Financial Statements
NPC Balance Sheet: December 31, 2001 December 31, 2000 ------------------ ----------------- ----------------- Investment in Sierra Pacific Resources $309,259 $471,975 Equity in Sierra Pacific Resources $309,259 $471,975 |
The Investment in Sierra Pacific Resources reflects the net assets, after deducting for all liabilities and preferred stock of Sierra Pacific Resources not related to NPC. The Equity in Sierra Pacific Resources reflects the sum of paid-in-capital and retained earnings of SPR, without the benefit of NPC.
These line items are presented under the rules of purchase accounting and do not represent any asset to which holders of NPC's securities may look for recovery of their investment. These items must be disregarded for determining the ability of NPC to satisfy its obligations or to pay dividends (preferred or common), for
calculating NPC's ratios of earnings to fixed charges and preferred stock dividends, and for all of NPC's financial covenants and earnings tests including those under its charter and mortgage.
NPC Income Statement: Year Ended Year Ended Year Ended --------------------- ---------- ---------- ---------- December 31, 2001 December 31, 2000 December 31, 1999 ----------------- ----------------- ----------------- Equity in (Losses) Earnings of Sierra Pacific Resources $(6,672) $(31,852) $13,058 |
The Equity in (Losses) Earnings of Sierra Pacific Resources represents the net income (loss) of SPR after SPPC preferred stock dividends.
This line item is presented under the rules of purchase accounting and does not represent any item of revenue or income to which holders of NPC's securities may look for recovery of their investment. This item must be disregarded for determining the ability of NPC to satisfy its obligations or its ability to pay dividends (preferred or common), for calculating NPC's ratios of earnings to fixed charges and preferred dividends, and for all of NPC's financial covenants and earnings tests including those under its charter and mortgage.
NPC Statement of Cash Flow: Year Ended Year Ended Year Ended --------------------------- ---------- ---------- ---------- December 31, 2001 December 31, 2000 December 31, 1999 ----------------- ----------------- ----------------- Equity in (Losses) Earnings of Sierra Pacific Resources $(6,672) $(31,852) $13,058 |
As in the Income Statement, the Equity in (Losses) Earnings of Sierra Pacific Resources represents the net income (loss) of SPR, after SPPC preferred stock dividends.
This line item is presented under the rules of purchase accounting and does not represent any item of cash flow to which holders of NPC's securities may look for recovery of their investment. This item must be disregarded for determining the ability of NPC to satisfy its obligations or its ability to pay dividends (preferred or common), for calculating NPC's ratios of earnings to fixed charges and preferred dividends, and for all of NPC's financial covenants and earnings tests including those under its charter and mortgage.
NPC Statement of Capitalization: December 31, 2001 December 31, 2000 -------------------------------- ----------------- ----------------- Equity in Sierra Pacific Resources $309,259 $471,975 |
The Equity in Sierra Pacific Resources reflects the sum of paid-in-capital and retained earnings of SPR on NPC's books.
This line item is presented under the rules of purchase accounting and does not represent any item of cash flow to which holders of NPC's securities may look for recovery of their investment. This item must be disregarded for determining the ability of NPC to satisfy its obligations or its ability to pay dividends (preferred or common), for calculating NPC's ratios of earnings to fixed charges and preferred dividends, and for all of NPC's financial covenants and earnings tests including those under its charter and mortgage.
NOTE 2. SIERRA PACIFIC RESOURCES AND NEVADA POWER MERGER
On July 28, 1999, the merger between SPR and NPC was consummated. The merger was accounted for as a reverse purchase under generally accepted accounting principles, with NPC considered the acquiring entity even though SPR is the surviving legal entity. In addition, for accounting purposes the merger was deemed to have occurred on August 1, 1999. As a result of this reverse purchase accounting treatment: (i) the historical financial statements of SPR for periods prior to the date of the merger are no longer the financial statements of SPR, and therefore, are no longer presented; (ii) the historical financial statements of SPR for periods prior to the date of the merger are those of NPC; and (iii) based on a merger date of August 1, 1999, the Consolidated Statements of Income for the twelve months ended December 31, 1999, include five months (August through
December 1999) of operating activity for SPR and its subsidiaries other than NPC. The same statements include the operating results of NPC for the entire periods presented
Through December 31, 2001, SPR incurred a total of $60.2 million in capitalized costs since merger work began. The capitalized merger amounts consist of $38.4 million of transaction and transition costs and $21.8 million of employee separation costs.
Employee severance, relocation, and related costs for SPR were $17.3 million, of which $.4 million remains unpaid as of December 31, 2001. Other costs incurred in connection with employee separations included pension and postretirement benefits net of plan curtailment gains of $4.5 million.
In accordance with the terms of the merger, each outstanding share of SPR's common stock was converted into the right to receive either $37.55 in cash or 1.44 shares of newly issued SPR common stock. Each outstanding share of NPC common stock was converted to the right to receive either $26.00 in cash or 1.00 share of newly issued SPR common stock. 4,037,000 shares of SPR and 11,716,611 shares of NPC common stock were exchanged for $151.6 million and $304.6 million, respectively. The remaining shares of each company were converted to newly issued shares of SPR common stock. SPR stockholders and NPC stockholders received 38,866,054 and 39,548,506 shares, respectively, of newly issued SPR common stock, resulting in 78,414,560 outstanding shares of SPR on August 1, 1999.
The total consideration paid to SPR common stockholders was equal to cash of $151.6 million and 38,866,054 shares of newly issued SPR common stock at a price of $24.18 per share based on the average closing price of NPC common stock between April 22, 1998 and May 6, 1998. The eleven-day average price of NPC common stock used in determining the total stock consideration represents the market price over a reasonable period of time before and after the transaction was announced on April 29, 1998. Goodwill of $331.2 million was recorded in connection with the merger. The order of the PUCN approving the merger allowed SPR to defer merger costs (including goodwill) allocable to the regulated Utilities for a three-year period. Accordingly, goodwill amortization through December 31, 2001, associated with the regulated Utilities has been reclassified to a regulatory asset.
On October 1, 2001, and November 30, 2001, NPC and SPPC, respectively, filed applications with the PUCN for general rate increases that included, among other items, a request to recover deferred merger costs, including goodwill. The Utilities have proposed to recover merger transition and transaction costs over ten years and goodwill over forty years. Decisions on the NPC and SPPC cases are expected no later than April 1, 2002, and June 1, 2002, respectively. See Note 3 "Regulatory Actions" for additional information about these rate cases.
NOTE 3. REGULATORY ACTIONS
The Utilities are subject to the jurisdiction of the PUCN and, in the case of SPPC, the California Public Utility Commission (CPUC) with respect to rates, standards of service, siting of and necessity for, generation and certain transmission facilities, accounting, issuance of securities and other matters with respect to electric distribution and transmission operations. NPC and SPPC submit integrated resource plans to the PUCN for approval.
Under federal law, the Utilities are subject to certain jurisdictional regulation, primarily by the FERC. The FERC has jurisdiction under the Federal Power Act with respect to rates, service, interconnection, accounting, and other matters in connection with the Utilities' sale of electricity for resale and interstate
transmission. The FERC also has jurisdiction over the natural gas pipeline companies from which the Utilities take service.
As a result of regulation, many of the fundamental business decisions of the Utilities, as well as the rate of return they are permitted to earn on their utility assets, are subject to the approval of governmental agencies.
On April 18, 2001, the Governor of Nevada signed into law AB 369. The provisions of AB 369 include a moratorium on the sale of generation assets by electric utilities, the repeal of electric industry restructuring, and a reinstatement of deferred energy accounting for fuel and purchased power costs incurred by electric utilities. Set forth below is a summary of key provisions of AB 369.
Generation Divestiture Moratorium
AB 369 prohibits all divestiture of generation assets by electric utilities until July 2003. After January 1, 2003, NPC or SPPC may seek PUCN permission to sell one or more generation assets with the sale to be effective on or after July 1, 2003. The PUCN may approve the request to divest only if it finds the transaction to be in the public interest. The PUCN may base its approval of the request upon such terms, conditions, or modifications as it deems appropriate.
AB 369 directs the PUCN to take all steps necessary to obtain federal approval for the prohibition on divestiture and to vacate any of its own orders that had previously approved generation divestiture transactions.
Deferred Energy Accounting
AB 369 required the Utilities to use deferred energy accounting for their respective electric operations beginning on March 1, 2001. The intent of deferred energy accounting is to ease the effect of fluctuations in the cost of purchased power and fuel. Under deferred energy accounting, to the extent actual fuel and purchased power costs exceed fuel and purchased power costs recoverable through current rates, that excess is not recorded as a current expense on the income statement but rather is deferred and recorded as an asset on the balance sheet. Conversely, a liability is recorded to the extent fuel and purchased power costs recoverable through current rates exceed actual fuel and purchased power costs. These excess amounts are reflected in adjustments to rates and recorded as revenue or expense in future time periods, subject to PUCN review. AB 369 provides that the PUCN may not allow the recovery of any costs for purchased fuel or purchased power "that were the result of any practice or transaction that was undertaken, managed or performed imprudently by the electric utility." In reference to deferred energy accounting, AB 369 specifies that fuel and purchased power costs include all costs incurred to purchase fuel, to purchase capacity, and to purchase energy. The Utilities also record, and are eligible to recover, a carrying charge on such deferred balances.
AB 369 requires that each Utility file an application to clear its deferred energy account balances after the end of each 12-month period, but allows the balances from each 12-month period to be recovered over an adjustment period of up to three years in order to reduce the volatility of rate changes. In addition, after the initial deferred energy case, each utility is allowed to file an application to clear its deferred energy account balances after the end of a six-month period if the proposed net increase or decrease in fuel and purchased power revenues for the six-month period is more than 5%. If a utility using deferred energy accounting realizes a rate of return greater than the rate authorized by the PUCN, the portion that exceeds the authorized rate of return will be transferred to the next deferred energy adjustment period.
Before an electric utility may clear its deferred accounts, AB 369 requires the PUCN to determine whether the costs for purchased fuel and purchased power that the electric utility recorded in its deferred
accounts are recoverable and whether the revenues that the electric utility collected from customers in Nevada for purchased fuel and purchased power are properly recorded and credited in its deferred accounts. AB 369 prohibits the PUCN from allowing an electric utility to recover any costs for purchased fuel and purchased power that were the result of any practice or transaction that was undertaken, managed or performed imprudently by the electric utility. To the extent that the PUCN finds that any amount included in either Utility's deferred account was imprudently incurred, the PUCN will not permit that amount to be recovered through higher rates, and an equivalent amount of the Utility's deferred energy costs asset will be required to be written off. Such a write-off could cause a substantial loss to be incurred by the Utility, could cause its securities to be downgraded by the rating agencies, and could make it significantly more difficult to finance the operations of the Utility and to buy fuel and purchased power from third parties.
In addition, as discussed under "Required Filings" below, the PUCN must determine whether the rates that went into effect on March 1, 2001, pursuant to the CEP as filed by the Utilities with the PUCN on January 29, 2001, are just and reasonable and reflect prudent business practices.
Transition of Rates to Deferred Energy Accounting
All rates in effect on April 1, 2001, including the cumulative increases under the Global Settlement and the CEP Riders, remain in effect until the PUCN issues final orders on future general and initial deferred energy rate applications. (See "Required Filings," below). No further applications can be made for the Fuel and Purchased Power (F&PP) riders that were part of the July 2000 Global Settlement described in SPR's Annual Report on Form 10-K for the year ended December 31, 2000.
The Utilities are not permitted to recover any shortfall incurred before March 1, 2001, resulting from the difference between actual fuel and purchased power costs and the rates permitted by the Global Settlement. Although the F&PP riders were in effect during this period, the riders were based on trailing 12-month average costs and were subject to caps and, therefore, did not allow the Utilities full recovery for fuel and purchased power costs due to the rapid rise in energy prices.
AB 369 prohibits the PUCN from taking any further action on the CEP, and provides that, except for the CEP Rider rate increases put in effect on April 1, 2001, the CEP will be deemed to have been withdrawn by the Utilities. Additionally, approximately $20 million of revenue collected by the Utilities based on the CEP before April 1, 2001 was credited to the deferred energy accounts, which caused the accounts to start in an over-collected position.
Required Filings
The Utilities have both filed a general rate application and a deferred energy application on the dates listed below:
General Rate Case Deferred Energy Filing ----------------- ---------------------- File Date Effective Date File Date Effective Date Nevada Power Company Oct. 1, 2001 April 1, 2002 Dec. 1, 2001 April 1, 2002 Sierra Pacific Power Company Dec. 1, 2001 June 1, 2002 Feb. 1, 2002 June 1, 2002 |
In connection with clearing the Utilities' deferred energy accounts, the PUCN must investigate and determine whether the Utilities' rates that went into effect on March 1, 2001, pursuant to the CEP, are just and reasonable and reflect prudent business practices. The rates in effect on April 1, 2001, remain in effect until the PUCN issues final orders on the general and initial deferred energy rate applications referred to above. The PUCN is prohibited from adjusting rates during this time period unless an adjustment is absolutely necessary to avoid a finding that the rates are confiscatory and, therefore, in violation of the United States or Nevada
Constitutions. If adjustments are necessary, they may only be made to the extent necessary to avoid an unconstitutional result.
After the initial general rate applications described above, each Utility will be required to file future general rate applications at least every 24 months.
Restrictions on Mergers and Acquisitions
AB 369 imposes certain restrictions on mergers and acquisitions involving Nevada electric utilities. In particular, the PUCN may not approve a merger or acquisition involving an electric utility unless the utility complies with the generation divestiture provisions of AB 369.
In addition, AB 369 includes provisions that would have significantly affected the required regulatory approvals for the proposed acquisition of PGE from Enron. On April 26, 2001, Enron and SPR terminated, by mutual agreement, the proposed purchase and sale of PGE.
AB 369 also provides that if an electric utility holding company acquires an interest in an out-of-state public utility prior to July 1, 2003, each electric utility in which the holding company holds a controlling interest shall not be entitled to the benefit of deferred energy accounting. Thus, in the event that SPR acquires an out-of-state public utility, NPC and SPPC would lose the ability to utilize deferred energy accounting.
Repeal of Electric Industry Restructuring
AB 369 repeals all statutes authorizing retail competition in Nevada's electric utility industry and voids any license issued to an alternative seller in connection with retail electric competition.
Other Legislation
SB 372, which increased renewable energy portfolio requirements, was enacted in the 2001 Nevada legislative session. Renewable resources include biomass, wind, solar, and geothermal projects. In 2003, the Utilities will be required to purchase five percent of their energy from renewable resources. These requirements increase to 15% by 2013. Prior law capped renewable energy requirements at one percent. Currently, SPPC obtains approximately nine percent of its energy from renewable resources, while NPC obtains less than one percent from renewables. SB 372 requires the PUCN to establish standards for renewable energy contracts, including prices and other terms and conditions. If sufficient renewable energy contracts that meet PUCN standards are not available, the Utilities will not be required to meet the portfolio requirements. All renewable energy contracts meeting PUCN standards will be recoverable in the deferred energy accounts.
The 2001 Nevada legislature passed another key piece of legislation for the Nevada energy industry, AB 661. AB 661 allows commercial and governmental customers with an average demand greater than 1 MW to select new energy suppliers. The Utilities would continue to provide transmission, distribution, metering and billing services to such customers. AB 661 requires customers wishing to choose a new supplier to receive the approval of the PUCN and meet public interest standards. In particular, departing customers must secure new energy resources that are not under contract to the Utilities, remaining customers or the utility cannot be negatively impacted by the departure, and the departing customers must pay any deferred energy balances. The PUCN has adopted regulations prescribing the criteria that will be used to determine if there will be negative impacts to remaining customers or the utility. Certain limits are placed upon the departure of NPC customers until 2003; most significantly, the amount of load departing is limited to approximately 1100 MW in peak conditions. AB 661 permits customers to file applications with the PUCN beginning in the fourth quarter of 2001. Customers must provide 180-day notice to the Utilities and could begin to receive service from new
suppliers by mid-2002. On January 10, 2002, an approximately 130 MW SPPC customer submitted an application to the PUCN under AB 661. The customer, SPPC, and PUCN staff are negotiating a stipulation regarding settlement of the terms and conditions under which this customer will be permitted to procure energy from an alternative source other than SPPC. The terms and conditions of the stipulation are expected to comply with the provisions of AB 661 in that SPPC and its remaining customers will not be negatively impacted by the customer's departure. A hearing on the stipulation has been set for March 20, 2002.
AB 661 also contains new electric and gas energy surcharges for low-income assistance and weatherization programs. These surcharges are recoverable directly from customers as separate line items on their bills with the Utilities remitting collected surcharges to the PUCN. Various state agencies will administer the disposition of the funds.
Nevada Power Company General Rate Case (NPC)
On October 1, 2001, NPC filed an application with the PUCN seeking an electric general rate increase. This application was mandated by AB 369, which was enacted by the Nevada legislature in April 2001. On December 21, 2001, NPC filed a Certification to its general rate filing updating costs and revenues pursuant to Nevada regulations. In the certification filing, NPC requested an increase in its general rates charged to all classes of electric customers designed to produce an increase in annual electric revenues of $22.7 million, which is an overall 1.7% rate increase. The application also seeks a return on common equity ("ROE") for Nevada Power's total electric operations of 12.25% (a reduction from NPC's last-authorized ROE for bundled electric operations of 12.50%) and an overall rate of return ("ROR") of 9.30% (a reduction from NPC's last-authorized ROR for bundled electric operations of 10.02%). Public hearings on NPC's general rate case began on February 4, 2002. Various parties have intervened in NPC's general rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, MGM/Mirage, and the Nevada Coalition Of Commercial Energy Consumers. The reduction of NPC's revenue requirements proposed by the intervenors ranges from $50 million to $107 million.
Nevada Power Company Deferred Energy Case (NPC)
On November 30, 2001, NPC filed an application with the PUCN seeking to clear deferred balances for purchased fuel and power costs accumulated between March 1, 2001 through September 30, 2001. This application was mandated by AB 369, which was enacted by the Nevada Legislature in April 2001. The application seeks to establish a Deferred Energy Accounting Adjustment ("DEAA") rate to clear accumulated purchased fuel and power costs of $922 million and spread the cost recovery over a not more than three-year period. It also seeks to recalculate the Base Tariff Energy Rate to reflect anticipated ongoing purchased fuel and power costs. The total rate increase resulting from the DEAA would amount to 21%. NPC has proposed an alternate plan in which full recovery of the deferred balance would be amortized over a period greater than three years, but not to exceed six years. Public hearings began March 4, 2002. Various parties have intervened in NPC's deferred energy rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, MGM/Mirage, the Southern Nevada Water Authority, the Nevada Energy Buyers Group, and the Nevada Coalition Of Commercial Energy Consumers. The disallowance of NPC's deferred energy balance that is proposed by the intervenors ranges from $85 million to $980 million.
Sierra Pacific Power Company General Rate Case (SPPC)
On November 30, 2001, SPPC filed an application with the PUCN seeking an electric general rate increase. This application was mandated by AB 369, which was enacted by the Nevada Legislature in April 2001. On February 28, 2002, SPPC filed a certification to its general rate filing, updating costs and revenues pursuant to Nevada regulations. In the certification filing, SPPC requested an increase in its general rates charged to all classes of electric customers, which were designed to produce an increase in annual electric
revenues of $15.9 million representing an overall 2.4% rate increase. The application also seeks an ROE for SPPC's total electric operations of 12.25% (an increase from SPPC's last authorized ROE for bundled electric operations of 12.0%) and an overall ROR of 9.42% (a reduction from SPPC's last authorized ROR for bundled electric operations of 10%). Public hearings for SPPC's general rate case are scheduled to begin on April 8, 2002. Various parties have intervened in SPPC's general rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, and Barrick Goldstrike Mines, among others. Intervenor testimony will not be filed until March 22, 2002.
Sierra Pacific Power Company Deferred Energy Case (SPPC)
On February 1, 2002, SPPC filed an application with the PUCN seeking to clear deferred balances for purchased fuel and power costs accumulated between March 1, 2001 and November 30, 2001. This application was mandated by AB 369. The application seeks to establish a DEAA rate to clear accumulated purchased fuel and power costs of $205 million and spread the cost recovery over a not more than three-year period. It also seeks to recalculate the Base Tariff Energy Rate to reflect anticipated ongoing purchased fuel and power costs. The total rate increase resulting from the DEAA would amount to 9.8%. SPPC has proposed an alternate plan in which full recovery of the deferred balance would be amortized over a period greater than three years, but not to exceed six years. Public hearings are scheduled to begin in April 2002. Various parties have intervened in SPPC's deferred energy rate case including the Staff of the PUCN, the Bureau of Consumer Protection from the Nevada Attorney General's office, and Barrick Goldstrike Mines, among others. Intervenor testimony will not be filed until April 22, 2002.
Finance Authority (NPC, SPPC)
On September 20, 2001, the PUCN approved the June 19, 2001 applications by the Utilities for authority to issue long or short-term debt on either a secured or unsecured basis in an aggregate amount not to exceed $200 million for NPC and $100 million for SPPC through the end of 2002. NPC has issued all of its $200 million of authorized debt. SPPC has not issued any debt under this authority and has the full amount of the $100 million of authorized debt available for future issuances. On September 20, 2001, the PUCN also approved the Utilities' June 19, 2001 applications to amend an order issued by the PUCN allowing each of the Utilities to issue unsecured short-term promissory notes in an amount not to exceed $250 million through the period ending December 31, 2001. In the applications, the Utilities requested that the PUCN amend its previous order to provide the Utilities with the flexibility to issue secured promissory notes in addition to, or in lieu of, the authorized unsecured promissory notes.
On October 1, 2001, NPC and SPPC each filed an application with the PUCN requesting authority to issue secured or unsecured promissory notes in aggregate amounts not to exceed $250 million through December 31, 2004. On October 9, 2001, the Utilities filed amended applications reducing the time period to December 31, 2003. On November 29, 2001, the PUCN issued a compliance order approving the requests. Currently, NPC has $50 million and SPPC has $100 million of short-term debt authority remaining from these PUCN authorizations.
Natural Gas Rate Increase (SPPC)
On June 29, 2001, SPPC filed with the PUCN a Purchase Gas Adjustment (PGA) seeking recovery of $41.4 million in accumulated, unrecovered purchased gas expenses, and an increase in the going-forward rate to $.71 per therm. Public hearings were held on October 22 and 23, 2001. On November 5, 2001, the PUCN granted SPPC's application and approved recovery of the entire $41.4 million accumulated deferred balance over a three-year period and an increase in the going-forward rate to $.6648 per therm. Any over or under-recovery of future energy costs will be the subject of a future PGA application. SPPC will file its next PGA on July 1, 2002.
Price Mitigation Plan
On June 19, 2001, the FERC adopted a price mitigation plan applicable to spot market wholesale power sales in California and throughout the western United States during the period June 20, 2001 through September 30, 2002. The price mitigation plan establishes a mechanism with which to determine the maximum amount that may be charged for power sold during this period. The intent of the mitigation plan is to simulate the price that might be charged for electricity sold under competitive market conditions. Sellers that do not wish to establish rates on the basis of this price mitigation plan may propose cost-of-service rates covering all of their generating units in the WSCC for the duration of the mitigation plan. Although the Utilities are not able to predict at this time the long-term effect that the FERC price mitigation and other market developments plan may have on their results of operations, management believes that, under certain market conditions, the FERC plan adversely affects the availability of spot market power to the Utilities and reduces the price at which the Utilities can sell power on the wholesale market. Another potential result from these price mitigation measures could be the delay and/or cancellation of proposed power plants throughout the western United States. If these results occur, the long-term supply of energy could be reduced. Numerous parties, including NPC and several northwest utilities, appealed the June 19 and July 25, 2001 orders from the FERC to the District of Columbia Court of Appeals on the basis that the price caps are unfair to electric customers who reside outside of California. In a report to Congress on January 31, 2002, the FERC said the price mitigation plan had little if any influence on prices at which Western utilities were able to resell power. SPR is not persuaded by the FERC's report and continues to believe that the FERC's price caps have negatively impacted electric customers outside California. The parties to the appeal await action by the Court.
Wholesale Sales Tariffs
On March 13, 2001, the Utilities each filed an application for an order approving market-based rates. The market-based authority would apply to sales of electric energy and capacity outside of the Utilities' control areas. On May 11, 2001, SPPC and NPC received approval for market-based rates subject to a compliance order. SPPC's and NPC's compliance filing was accepted on August 10, 2001.
Rate Stabilization Plan
SPPC serves approximately 44,500 customers in California. On June 29, 2001, SPPC filed with the CPUC a Rate Stabilization Plan, which includes two phases. Phase One, which was also filed June 29, 2001, is an emergency electric rate increase of $10.2 million annually or 26%. If granted, the typical residential monthly electric bill for a customer using 650 kilowatt-hours would increase from approximately $47.12 to $60.12. On August 14, 2001, a pre-hearing conference was held, and a procedural order was established. On September 27,2001, the Administrative Law Judge issued an order stating that no interim or emergency relief could be granted until the end of the "rate freeze" period mandated by the California restructuring law for recovery of stranded costs. In accordance with the judge's request, on October 26, 2001, SPPC filed an amendment to its application declaring the rate freeze period to be over.
Phase Two, which is scheduled to be filed with the CPUC in April 2002, will be a general rate case to recover costs for expenses other than fuel and purchased power. SPPC will also ask the CPUC to reinstate the Energy Cost Adjustment Clause, which would allow SPPC to file for periodic rate adjustments to reflect its actual costs for fuel and purchased power. Phase Two will also include a proposal pertaining to the termination of the 10% rate reduction mandated by AB 1890. On December 5 and 11, 2001 hearings on Phase One were held and on January 11, 2002, opening briefs were filed. Reply briefs were filed on January 25, 2002. A proposed draft decision is expected by the end of March 2002. SPPC will file Phase Two on April 1, 2002.
NOTE 4. EARNINGS PER SHARE
The following table outlines the calculation for Diluted EPS. The difference between Basic EPS and Diluted EPS is due to common stock equivalent shares resulting from stock options, the employee stock purchase plan, performance shares and a non-employee director stock plan. Common stock equivalents were determined using the treasury stock method. Also see Note 7, Common Stock and Other Paid-in Capital.
Year ended December 31, -------------------------------------------- 2001 2000 1999 ------------ ------------ ------------ Basic EPS Numerator ($000) Income (loss) from continuing operations $ 29,866 $ (49,414) $ 48,210 Income from discontinued operations 1,022 9,634 3,540 Gain on disposal of water business 25,845 -- -- ------------ ------------ ------------ Net income (loss) $ 56,733 $ (39,780) $ 51,750 ============ ============ ============ Denominator Weighted average number of shares outstanding 87,542,441 78,435,405 62,577,385 ============ ============ ============ Per-Share Amounts: Income (loss) from continuing operations $ 0.34 $ (0.63) $ 0.77 Income from discontinued operations 0.01 0.12 0.06 Gain on disposal of water business 0.30 -- -- ------------ ------------ ------------ Net income (loss) $ 0.65 $ (0.51) $ 0.83 ============ ============ ============ Diluted EPS Numerator ($000) Income (loss) from continuing operations $ 29,866 $ (49,414) $ 48,210 Income from discontinued operations 1,022 9,634 3,540 Gain on disposal of water business 25,845 -- -- ------------ ------------ ------------ Net income (loss) $ 56,733 $ (39,780) $ 51,750 ============ ============ ============ Denominator Weighted average number of shares outstanding before dilution 87,542,441 78,435,405 62,577,385 Stock options/1/ 14,021 5,645 20,447 Executive long term incentive plan- performance shares/1/ 43,693 35,393 26,118 Non-Employee Director stock plan/1/ 9,355 5,885 5,736 Employee stock purchase plan/1/ 2,862 2,807 1,790 ------------ ------------ ------------ 87,612,372 78,485,135 62,631,476 ------------ ------------ ------------ Per-Share Amounts/1/: Income (loss) from continuing operations $ 0.34 $ (0.63) $ 0.77 Income from discontinued operations 0.01 0.12 0.06 Gain on disposal of water business 0.30 -- -- ------------ ------------ ------------ Net income (loss) $ 0.65 $ (0.51) $ 0.83 ============ ============ ============ |
/1/ Because of a net loss for the year ended December 31, 2000, stock equivalents would be anti-dilutive. Accordingly, Diluted EPS for that period is computed using the weighted average number of shares outstanding before dilution.
NOTE 5. INVESTMENTS IN SUBSIDIARIES AND OTHER PROPERTY
Investments in subsidiaries and other property consisted of (dollars in thousands):
Sierra Pacific Resources ------------------------ December 31, 2001 2000 -------- -------- Investment in Pinon Pine, LLC $ 55,319 $ 58,049 Investment in TGTC 18,799 17,164 Investment in Sierra Touch America 9,917 2,675 Cash Value-Life Insurance 12,580 13,393 Acquisition Costs 220 12,451 Other Investments 32,057 31,330 -------- -------- $128,892 $135,062 ======== ======== Nevada Power ------------ December 31, 2001 2000 -------- -------- Cash Value-Life Insurance $ 12,580 $ 13,393 Other 141 25 -------- -------- $ 12,721 $ 13,418 ======== ======== Sierra Pacific Power -------------------- December 31, 2001 2000 -------- -------- Investment in Pinon Pine, LLC $ 55,319 $ 58,049 Other 1,866 1,998 -------- -------- $ 57,185 $ 60,047 ======== ======== |
SPPC, through its wholly owned subsidiaries, Pinon Pine Corp., Pinon Pine Investment Co., and GPSF-B, owns Pinon Pine Company, L.L.C. (the "LLC"). The LLC was formed to take advantage of federal income tax credits associated with the alternative fuel (syngas) produced by the coal gasifier available under ss. 29 of the Internal Revenue Code. The entire project, which includes an LLC-owned gasifier and an SPPC-owned power island and post-gasification facility to partially cool and clean the syngas, is referred to collectively as the Pinon Pine Power Project ("Pinon Pine"). Construction of Pinon Pine was completed in June 1998.
Pinon Pine is a project co-funded by the Department of Energy (DOE) under an agreement between SPPC and DOE that expired December 31, 2000. Through December 31, 2001, the DOE funded $167 million for construction, operation, and maintenance of the project. Included in the Consolidated Balance Sheets of SPR and SPPC is the net book value of the gasifier and related assets, which is approximately $105 million as of December 31, 2001, of which $50 million is included in Utility Plant, and $55 million is included in Investments in subsidiaries and other property.
To date, SPPC has not been successful in obtaining sustained operation of the gasifier. SPPC has retained an independent engineering consulting firm, to complete a comprehensive study of the Pinon Pine gasification plant by mid-2002. The study will evaluate the potential modifications required to make the facility operational and reliable using several technology scenarios. The evaluation of each scenario will include an estimate of the additional capital expenditures necessary for reliable operation of the facility, and the risks associated with that technology.
Although not anticipated, if analysis of the study by SPPC's management indicates there is no economically feasible use of the Pinon Pine assets, SPPC intends to pursue recovery of Pinon Pine, net of salvage, as a regulatory asset. The request for recovery would be based, in part, on the PUCN's approval of Pinon Pine in an earlier resource plan. In that event, if SPPC is unsuccessful in obtaining recovery, there could be a material adverse effect on SPPC's and SPR's financial condition and results of operations.
NOTE 6. JOINTLY OWNED FACILITIES
At December 31, 2001, SPR (through its utility subsidiaries NPC and SPPC) owned the following undivided interests in jointly owned electric utility facilities:
% Owned Construction by Accumulated Net Plant in Work in Generating Facility Subsidiary Plant in Service Depreciation Service Progress Subsidiary ---------------------------------------------------------------------------------------------------------------------- Navajo Station 11.3 $225,748 $ 97,933 $127,815 $ 3,804 NPC Mohave Facility 14.0 84,570 37,133 47,437 1,655 NPC Reid Gardner No. 4 32.2 126,107 54,580 71,527 278 NPC Valmy Station 50.0 281,768 126,370 155,398 21 SPPC -------- -------- -------- ------- TOTAL $718,193 $316,016 $402,177 $ 5,758 ======== ======== ======== ======= |
The above amounts for Navajo and Mohave include NPC's share of transmission systems and general plant equipment and, in the case of Navajo, NPC's share of the jointly owned railroad which delivers coal to the plant. Each participant provides its own financing for all of these jointly owned facilities. NPC's share of operating expenses for these facilities is included in the corresponding operating expenses in the Consolidated Statements of Income.
The Mohave Generating Station is jointly owned by Southern California Edison (56%), Los Angeles Department of Water and Power (20%), NPC (14%) and Salt River Project (10%). According to the terms of the operating agreement, if any of the participants default on their contractual obligations for a period of six (6) months, thereafter the output of the station is reduced by the defaulting participant's percentage of ownership. The non-defaulting participants would then assume the station's reduced variable costs and ongoing fixed operating costs in accordance with their respective ownership percentages. The non-defaulting participants would submit the dispute or default to a board of arbitrators, which would determine what remedies are necessary to resolve the dispute or remedy the default. At December 31, 2001, none of the participants had defaulted on their contractual obligations.
SPPC and Idaho Power Company each own an undivided 50% interest in the Valmy generating station, with each company being responsible for financing its share of capital and operating costs. SPPC is the operator of the plant for both parties. SPPC's share of direct operation and maintenance expenses for Valmy is included in the accompanying Consolidated Statements of Income.
NOTE 7. COMMON STOCK AND OTHER PAID-IN CAPITAL
As of December 31, 2001, 3,508,039 shares of common stock were reserved
for issuance under the Common Stock Investment Plan (CSIP), Employees' Stock
Purchase Plan (ESPP), Non-Employee Director Stock Plan and Executive Long-Term
Incentive Plan (ELTIP). The ELTIP for key management employees allows for the
issuance of SPR's common shares to key employees through December 31, 2003. This
Plan permits the following types of grants, separately or in combination:
nonqualified and qualified stock options; stock appreciation rights; restricted
stock; performance units; performance shares and bonus stock. SPR also provides
an ESPP to all of its employees meeting minimum service requirements. Employees
can choose twice each year to have up to 15% of their base earnings withheld to
purchase SPR common stock. The purchase price of the stock is 90% of the market
value on the offering date or 100% of the market price on the execution date, if
less. The Non-employee Director Stock Plan provides that a portion of SPR's
outside directors' annual retainer be paid in SPR common stock. SPR records the
costs of these plans in accordance with Accounting Principles Board Opinion
Number 25.
As a part of the August 1, 1999, merger, the NPC ELTIP was terminated and existing SPR plans were adopted by the surviving company.
On September 21, 1999, the Board of Directors of SPR (the "SPR Board") declared a dividend distribution of one right (an "SPR Right") for each outstanding share of SPR common stock to shareholders of record at the close of business on October 31, 1999. By issuing the new SPR Rights, the SPR Board extended the benefits and protections afforded to shareholders under the Rights Agreement, dated as of October 31, 1989, which expired on October 31, 1999. Each SPR Right, initially evidenced by and traded with the shares of SPR Common Stock, entitles the registered holder (other than an "Acquiring Person" as defined in the Rights Agreement) to purchase at an exercise price of $75.00, $150.00 worth of common stock at its then-market value, subject to certain conditions and approvals set forth in the Rights Agreement. If, at any time while there is an Acquiring Person, SPR engages in a merger or other business combination transaction or series of related transactions in which the Common Stock is changed or exchanged or 50% or more of its assets or earning power is transferred, each SPR Right (not previously voided by the occurrence of a Flip-in Event, as described in the Rights Agreement) will entitle its holder to purchase, at the SPR Right's then-current Exercise Price, common stock of such Acquiring Person having a calculated value of twice the SPR Right's then-current Exercise Price. The SPR Rights are not exercisable until the Distribution Date and expire on October 31, 2009, unless previously redeemed by SPR. Following an SPR Distribution Date, the SPR Rights will trade separately from the SPR Common Stock and will be evidenced by separate certificates. Until an SPR Right is exercised, the holder thereof will have no rights as a shareholder of SPR, including, without limitation, the right to receive dividends. The purpose of the plan is to help ensure that SPR's shareholders receive fair and equal treatment in the event of any proposed hostile takeover of SPR.
On August 15, 2001, SPR completed a public offering of 23,575,000 shares of its common stock, yielding net proceeds of approximately $340 million, all of which were contributed to NPC as an additional equity investment.
On November 16 and 21, 2001, SPR completed a public offering of 6,900,000 of its Corporate PIES, yielding net proceeds of approximately $345 million. Each Corporate PIES unit consists of a forward stock purchase contract and a senior unsecured note issued by SPR with a face amount of $50. The senior notes are pledged as collateral to secure each holder's obligation to purchase shares of SPR common stock under the stock purchase contract. The senior note may be released from the pledge arrangement if a holder opts to create Treasury PIES by delivering a like principal amount of U.S. Treasury securities to the Securities Intermediary in substitution for the senior notes.
Each stock purchase contract obligates the holder to purchase SPR common stock on or before November 15, 2005, the Purchase Contract Settlement Date. The number of shares each investor is entitled to receive will depend on the average closing price of SPR common stock over a 20-day trading period prior to the settlement. Prior to the Purchase Contract Settlement Date, holders of Corporate PIES have the option to pay $50 per Corporate PIES to settle their purchase contract obligations. If the holders do not elect to make a cash payment, the proceeds from the remarketing of the senior notes will be used to satisfy their purchase contract obligations.
The purchase contracts are forward transactions in SPR common stock. Upon issuance, a liability for the present value of the purchase contract adjustment payments, approximately $13.7 million, was recorded in Other deferred credits, with a corresponding reduction to Other paid-in capital. See further discussion regarding these senior notes and the purchase contract adjustment payments at Note 9 - Long-Term Debt. Upon settlement of a purchase contract, SPR will receive the stated amount of $50 on the purchase contract and will issue the required number of shares of common stock. The stated amount received will be credited to stockholders' equity and allocated between the Common stock and Other paid-in capital accounts.
Prior to the issuance of common stock upon settlement of the purchase contracts, SPR expects that the PIES will be reflected in SPR `s earnings per share calculations using the treasury stock method. Under this method, the number of shares of common stock used in calculating earnings per share is deemed to be increased by the excess, if any, of the number of shares of common stock issuable upon settlement of the purchase contracts over the number of shares that could be purchased by SPR in the market at the average closing price during the relevant period using the proceeds receivable upon settlement. As a result, SPR expects there will be no dilutive effect on its earnings per share except during periods when the average closing price per share of common stock is above the threshold appreciation price.
The changes in common stock and additional paid-in capital for 2001, 2000, and 1999, are as follows (dollars in thousands):
Shares Issued Amount ------------------------------------ ------------------------------------ 2001 2000 1999 2001 2000 1999 ---------- ------ ---------- --------- ---------- ---------- Public Offering 23,575,000 - - $340,364 $ - $ - Merger Exchange - - 78,414,560 - - 66,540 CSIP/DRP - 5,389 - - 237 - ESPP and other 60,319 55,268 - 830 1,055 - ---------- ------ ---------- --------- ---------- ---------- 23,635,319 60,657 78,414,560 $341,194 $ 1,292 $ 66,540 ========== ====== ========== ========= ========== ========== |
NOTE 8. PREFERRED STOCK AND PREFERRED TRUST SECURITIES
SPPC's preferred stock is superior to SPPC's common stock with respect to dividend payments (which are cumulative) and liquidation rights.
The following table indicates the dollar amount and number of shares of SPPC preferred stock outstanding at December 31 of each year:
Amount Shares Outstanding ------------------------ -------------------------- (Dollars in thousands) 2001 2000 2001 2000 ------------------------ -------------------------- Preferred Stock Not subject to mandatory redemption: SPPC Class A Series I 50,000 50,000 2,000,000 2,000,000 ------------------------ -------------------------- Total Preferred Stock $ 50,000 $ 50,000 2,000,000 2,000,000 ======================== ========================== |
The following table indicates the principal amount and number of shares of NPC and SPPC preferred trust securities outstanding at December 31 of each year:
Amount Shares Outstanding ------------------------ -------------------------- (Dollars in thousands) 2001 2000 2001 2000 ------------------------ -------------------------- Preferred Trust Securities Subject to mandatory redemption: Preferred Securities of Nevada Power Co Capital I $ 118,872 $ 118,872 147,058 147,058 Preferred Securities of Nevada Power Co Capital III 70,000 70,000 86,598 86,598 ------------------------ -------------------------- Subtotal 188,872 188,872 233,656 233,656 Preferred Securities of Sierra Pacific Power Company Capital I - 48,500 - 1,940,000 ------------------------ -------------------------- Total Preferred Trust Securities $ 188,872 $ 237,372 233,656 2,173,656 ======================== ========================== |
SPR has issued neither preferred stock nor preferred trust securities.
Preferred Trust Securities
On April 2, 1997, NVP Capital I (Trust), a wholly owned subsidiary of NPC, issued 4,754,860 8.2% QUIPS at $25 per security. NPC owns all of the Series A common securities, 147,058 shares issued by the Trust for $3.7 million. The QUIPS and the common securities represent undivided beneficial ownership interests in the assets of the Trust, a statutory business trust formed under the laws of the state of Delaware. The existence of the Trust is for the sole purpose of issuing the QUIPS and the common securities and using the proceeds thereof to purchase from NPC its 8.2% Junior Subordinated Deferrable Interest Debentures (QUIDS) due March 31, 2037, extendible to March 31, 2046, under certain conditions, in a principal amount of $122.6 million. The sole asset of the Trust is the QUIDS. Holders of the Series A QUIPS are entitled to receive preferential cumulative cash distributions accruing from the date of original issuance and payable quarterly on the last day of March, June, September and December of each year. The Series A QUIPS are subject to mandatory redemption, in whole or in part, upon repayment of the Series A QUIDS at maturity or their earlier redemption in an amount equal to the amount of related Series A QUIDS maturing or being redeemed. The QUIPS are redeemable at $25 per preferred security plus accumulated and unpaid distributions thereon to the date of redemption. NPC's obligations provide a full and unconditional guarantee of the Trust's obligations under the QUIPS. Financial statements of the Trust are consolidated with NPC's. Separate financial statements are not filed because the Trust is wholly owned by NPC and essentially has no independent operations, and NPC's guarantee of the Trust's obligations is full and unconditional. The $118.9 million in net proceeds was used for general corporate utility purposes and the repayment of short-term debt.
In October 1998, NVP Capital III (Trust), a wholly-owned subsidiary of Nevada Power Company, issued 2,800,000, 7 3/4% Cumulative Quarterly Trust Issued Preferred Securities at $25 per security. NPC owns the entire common securities, 86,598 shares issued by the Trust for $2.2 million. The Trust Issued Preferred Securities and the common securities represent undivided beneficial ownership interests in the assets of the Trust, a statutory business trust formed under the laws of the state of Delaware. The existence of the Trust is for the sole purpose of issuing the Trust Issued Preferred Securities and the common securities and using the proceeds thereof to purchase from NPC its 7 3/4% Junior Subordinated Deferrable Interest Debentures due September 30, 2038, extendible to September 30, 2047, under certain conditions, in a principal amount of $72.2 million. The sole asset of the Trust is the deferrable interest debentures. Holders of the Trust Issued Preferred Securities are entitled to receive preferential cumulative cash distributions accruing from the date of original issuance and payable quarterly on the last day of March, June, September and December of each year. The Trust Issued Preferred Securities are subject to mandatory redemption, in whole or in part, upon repayment of the deferrable interest debentures at maturity or their earlier redemption in an amount equal to the amount of related deferrable interest debentures maturing or being redeemed. The Trust Issued Preferred Securities are redeemable at $25 per preferred security plus accumulated and unpaid distributions thereon to the date of redemption. NPC's obligations provide a full and unconditional guarantee of the Trust's obligations under the Trust Issued Preferred Securities. Financial statements of the Trust are consolidated with NPC's. Separate financial statements are not filed because the Trust is wholly owned by NPC and essentially has no independent operations, and NPC's guarantee of the Trust's obligations is full and unconditional. The $70 million in net proceeds was used for general corporate utility purposes including the repayment of short-term debt.
Preferred Stock
On July 23, 1999, NPC redeemed the 4.7%, 5.2% and 5.4% Series Redeemable Cumulative Preferred Stock. The total par value and premium was $3.5 million and was paid in accordance with the merger agreement with Sierra Pacific Resources.
Preferred Trust Securities
On July 29, 1996, Sierra Power Capital I (the Trust), a wholly owned subsidiary of SPPC, issued $48.5 million (1,940,000 shares) of 8.60% Trust Originated Preferred Securities (the Preferred Securities). SPPC owns all the common securities of the Trust; 60,000 shares totaling $1.5 million (Common Securities). The Preferred Securities and the Common Securities (the Trust Securities) represent undivided beneficial ownership interests in the assets of the Trust. The existence of the Trust is for the sole purpose of issuing the Trust Securities and using the proceeds thereof to purchase from SPPC its 8.60% Junior Subordinated Debentures due July 30, 2036, in a principal amount of $50 million. The sole asset of the Trust is SPPC's junior subordinated debentures. SPPC's obligations provide a full and unconditional guarantee of the Trust's obligations under the Preferred Securities.
On November 29, 2001 SPPC redeemed all of the outstanding 8.60% Trust Originated Preferred Securities of its wholly owned subsidiary, Sierra Pacific Power Capital Trust 1, at a price of $25.00 per preferred security. Financial statements of the Trust are consolidated with SPPC's. Separate financial statements are not filed because the Trust is wholly owned by SPPC and essentially has no independent operation, and SPPC's guarantee of the Trust's obligations is full and unconditional.
Preferred Stock
SPPC's Restated Articles of Incorporation, as amended on August 19, 1992, authorize an aggregate total of 11,780,500 shares of preferred stock at any given time.
On November 1, 1999, SPPC paid $23.5 million, par value and premium, to redeem Series A, $2.44 Dividend (4.88%), Series B, $2.36 Dividend (4.72%) and Series C, $3.90 Dividend (7.8%).
On February 15, 2001, SPPC received consents from the holders of a majority of its preferred stock to increase the amount of unsecured indebtedness that SPPC may issue. Under SPPC's Restated Articles of Incorporation, SPPC cannot, without the consent of a majority of the total number of votes which may be cast by the holders of SPPC's preferred stock, issue unsecured debt securities with maturities of greater than 12 months for any purpose (other than refunding outstanding unsecured debt or retiring outstanding shares of preferred stock) if such unsecured indebtedness would exceed 20% of the aggregate of (1) the total principal amount of all bonds and other securities representing secured indebtedness then outstanding and (2) the total capital and surplus of SPPC then stated on its books. As of September 30, 2000, prior to the consent solicitation, SPPC could issue approximately $14 million in additional unsecured debt under this limitation. Pursuant to the consent solicitation, SPPC received the consent of the holders of a majority of its preferred stock to issue up to $400 million in long-term unsecured indebtedness in excess of the present limitation. As of December 31, 2001, SPPC would have been able to issue approximately $634 million of additional unsecured indebtedness. Upon receipt of the required number of consents, SPPC paid a participation premium in the amount of $.50 per share consented to each holder of shares of preferred stock whose valid, unrevoked consent was received prior to the specified return date. The aggregate amount of the participation premium paid was $.9 million. The only series of preferred stock of SPPC currently outstanding is its Class A, Series 1 Preferred Stock, of which 2 million shares are outstanding.
NOTE 9. LONG-TERM DEBT
Substantially all utility plant is subject to the liens of NPC's and SPPC's indentures under which their first mortgage bonds and General and Refunding Mortgage bonds are issued.
Nevada Power Company
On April 20, 2000, NPC utilized a $100 million capital contribution from SPR to retire $85 million of NPC's First Mortgage Bonds that matured on May 1, 2000, and to reduce outstanding commercial paper balances under NPC's commercial paper program that was established in July 1999.
On June 22, 2000, Clark County, Nevada issued for NPC's benefit $100 million Industrial Development Refunding Revenue Bonds, Series 2000A, due June 1, 2020. The interest rate is currently being determined by a Dutch Auction based on an auction period of seven days. The Series A bonds were issued to refund $100 million of Clark County's 7.80% Industrial Development Revenue Bonds Series 1990 on June 30, 2000.
On July 28, 2000, Clark County, Nevada issued for NPC's benefit $15 million Pollution Control Refunding Revenue Bonds, Series 2000B, due October 1, 2009. The interest rate is currently being determined by a Dutch Auction based on an auction period of seven days. The Series B bonds were issued to refund a like principal amount of Clark County's 7.80% Pollution Control Revenue Bonds Series 1989 on October 2, 2000.
The method of determining the interest rate on the Series A and Series B Bonds may be converted from time to time in accordance with the related Indenture so that such bonds would, thereafter, bear interest at a daily, weekly, flexible, term or auction rate. Both Series A and Series B Bonds are insured by AMBAC Assurance Corporation ("AMBAC"). On August 3, 2001, NPC issued $115 million of its Series BB and Series
CC First Mortgage Bonds to AMBAC to secure NPC's reimbursement obligations under the Series 2000A and 2000B Clark County Bonds insurance agreements.
On May 24, 2001, NPC issued $350 million of its 8.25% General and Refunding Mortgage Bonds, Series A, due June 1, 2011. The bonds were issued with registration rights under and secured by a General and Refunding Mortgage Indenture dated as of May 1, 2001 that is subject to the prior lien of NPC's Indenture of Mortgage dated as of October 1, 1953. The proceeds of the issuance were used to refinance or discharge outstanding indebtedness including commercial paper, short-term debt, and current maturities of long-term debt. On January 29, 2002, NPC successfully completed the exchange of these bonds for identical bonds, registered under the Securities Act of 1933.
On June 12, 2001, $150 million of NPC's floating rate notes matured and were paid in full. The floating rate notes were issued on June 9, 2000, and the net proceeds of the $150 million issue were used to redeem $100 million of floating rate notes on July 14, 2000, and to reduce NPC's commercial paper outstanding under its commercial paper program.
On August 20, 2001, $100 million of NPC's floating rate notes matured and were paid in full. The floating rate notes were issued August 18, 2000, and the net proceeds of the $100 million issue were used to reduce NPC's commercial paper outstanding under its commercial paper program.
On September 20, 2001 and October 15, 2001, NPC issued an aggregate total of $210 million of 6% unsecured notes due September 15, 2003. Interest on the notes is payable on March 15 and September 15 of each year. These notes are not entitled to any sinking fund and are non-callable. The proceeds of the issuance were used to refinance or discharge outstanding indebtedness including commercial paper, short-term debt, and current maturities of long-term debt.
On October 18, 2001, NPC issued $140 million of its General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003. The proceeds of the issuance were used to refinance or discharge outstanding indebtedness including commercial paper, short-term debt, and current maturities of long-term debt.
Sierra Pacific Power Company
On April 27, 2001, Washoe County, Nevada issued for SPPC's benefit $80 million of Water Facilities Refunding Revenue Bonds, Series 2001, due March 1, 2036. The bonds bear interest at a term rate of 5.75% per annum from their date of issuance to April 30, 2003. Beginning May 1, 2003, the method of determining the interest rate on the bonds may be converted from time to time in accordance with the related Indenture so that such bonds would, thereafter, bear interest at a daily, weekly, flexible, term or auction rate. The bonds were issued to refund $80 million of Washoe County variable rate Water Facilities Revenue Bonds (Sierra Pacific Power Company Project) Series 1990 on April 30, 2001. SPPC's obligations in respect of the Series 1990 bonds had been supported by a letter of credit that was terminated in connection with the redemption of those bonds. On June 11, 2001, SPPC completed the sale of its water business assets including the Project financed by the sale of the bonds. Although SPPC no longer owns the Project, SPPC will continue to bear the obligations and payments for the bonds under the terms of the Financing Agreement dated as of March 1, 2001, between SPPC and Washoe County, Nevada.
On May 24, 2001, SPPC issued $320 million of its 8.00% General and Refunding Mortgage Bonds, Series A, due June 1, 2008. The bonds were issued with registration rights under and secured by a General and Refunding Mortgage Indenture dated as of May 1, 2001 that is subject to the prior lien of SPPC's Indenture of Mortgage dated as of December 1, 1940. The proceeds of the issuance were used to refinance or discharge outstanding indebtedness including commercial paper, short-term debt, and current maturities of long-term debt. On January 29, 2002, SPPC successfully completed the exchange of these bonds for identical bonds, registered under the Securities Act of 1933.
On June 12, 2001, $200 million of SPPC's floating rate notes matured and were paid in full. The floating rate notes were issued on June 9, 2000, and the net proceeds of the $200 million issue were used to redeem $100 million of floating rate notes on July 14, and the remaining proceeds were used to reduce the amount of SPPC's commercial paper outstanding under the program established in July 1999.
On December 17, 2001, $17 million of SPPC's MTN Series D matured and were paid in full.
Sierra Pacific Resources
On March 31, 2000, $10 million of SPR's Series E senior notes matured and were paid in full.
On April 20, 2000, SPR issued an aggregate of $300 million floating rate notes, $200 million of which matures on April 20, 2003 and the remaining $100 million of which matures on April 20, 2002. Interest on the notes is payable quarterly. The interest rate on the notes for each interest period is a floating rate, subject to adjustment every three months, equal to the LIBOR for three-month U.S. dollar deposits plus a spread of 0.60% for the notes maturing in 2003, and a spread of 0.65% for the notes maturing in 2002.These notes are not entitled to any sinking fund. The notes due 2002 will be redeemable in whole, without premium, at the option of SPR beginning April 20, 2001, and on each interest payment date thereafter. The net proceeds of the $200 million issue were used to retire an equal amount of commercial paper of SPR issued under the line of credit established in July 1999 that was used as temporary funding for the cash portion of the NPC merger consideration. The net proceeds of the $100 million issue were used to make a capital contribution to NPC. On September 26, 2000, SPR entered into a forward swap relating to its $200 million floating rate notes that will mature on April 20, 2003, effectively locking in a LIBOR rate of 6.655%, which will result in an interest rate of 7.255% on the notes until their maturity. This transaction became effective on October 20, 2000.
On May 9, 2000, SPR issued $300 million of its 8.75% Notes due 2005. Interest on the notes is payable semi-annually. The notes are not subject to any sinking fund and are redeemable in whole or in part at any time upon payment of the principal amount of the notes being redeemed, plus accrued interest and a make-whole premium. The net proceeds from the issuance of these notes were used to retire an equal amount of commercial paper issued by SPR under its commercial paper program that was established in July 1999 and was cancelled in June 2001.
On November 16 and 21, 2001, SPR issued an aggregate of $345 million senior unsecured notes in connection with the public offering of 6,900,000 of its Corporate PIES. Each Corporate PIES unit consists of a forward stock purchase contract and a senior unsecured note issued by SPR with a face amount of $50. The senior notes are pledged as collateral to secure each holder's obligation to purchase shares of SPR common stock under the stock purchase contract. The senior note may be released from the pledge arrangement if a holder opts to create Treasury PIES by delivering a like principal amount of U.S. Treasury securities to the Securities Intermediary in substitution for the senior notes.
Each stock purchase contract obligates the holder to purchase SPR common stock on or before November 15, 2005, the Purchase Contract Settlement Date. The number of shares each investor is entitled to receive will depend on the average closing price of SPR common stock over a 20-day trading period prior to the settlement. See further discussion regarding the forward stock purchase contract at Note 7 Common Stock And Other Paid-In-Capital.
Each holder of Corporate PIES is entitled to receive quarterly payments consisting of purchase contract adjustment payments and interest on the senior unsecured notes. The Corporate PIES have a combined rate of 9.0%, which is comprised of the coupon on the senior note of 7.93% and the stated rate of the purchase contract adjustment payments of 1.07%. Interest on the senior unsecured notes began to accrue on November 16, 2001, and quarterly interest payments will be made each quarter beginning with the first payment, which was made on
February 15, 2002. All senior unsecured notes will be remarketed beginning on August 10, 2005, up to and including November 1, 2005, and, if necessary, on November 9, 2005, unless holders of senior notes that are not part of a Corporate PIES elect not to have their senior notes remarketed. Upon remarketing, the interest rate will be reset and the senior notes will accrue interest at the reset rate after the remarketing settlement date. Prior to the Purchase Contract Settlement Date, holders of Corporate PIES have the option to pay $50 per Corporate PIES to settle their purchase contract obligations. If the holders do not elect to make a cash payment, the proceeds from the remarketing of the senior notes will be used to satisfy their purchase contract obligations. If any senior notes remain outstanding after the Purchase Contract Settlement Date, SPR will pay interest payments on those senior notes until their maturity on November 15, 2007.
Purchase contract adjustment payments will accrue from November 16, 2001. Holders received the first quarterly purchase contract adjustment payments of $0.1323 per unit ($913,000 in aggregate) on February 15, 2002, and will receive payments of $0.1338 per unit ($923,000 in aggregate) for each subsequent quarter. Upon issuance, a liability for the present value of the purchase contract adjustment payments, approximately $13.7 million, was recorded in Other Deferred Credits, with a corresponding reduction to Other Paid-in-Capital.
NPC's, SPPC's and SPR's aggregate annual amount of maturities for long-term debt for the next five years is shown below (in thousands of dollars):
SPR Holding Co. SPR NPC SPPC and Other Subs. Consolidated ------------ ------------- --------------- ------------ 2002 $ 19,380 $ 2,630 $ 100,000 $ 122,010 2003 350,000 20,632 200,000 570,632 2004 130,000 2,621 - 132,621 2005 - 2,622 300,000 302,622 2006 - 52,629 - 52,629 ------------ ------------- -------------- ------------- Subtotal 499,380 81,134 600,000 1,180,514 Thereafter 1,127,967 844,566 345,068 2,317,601 ------------ ------------- -------------- ------------- Total $ 1,627,347 $ 925,700 $ 945,068 $ 3,498,115 ============ ============= ============== ============= |
NOTE 10. TAXES
Nevada Power Company
The following reflects the composition of taxes on income (in thousands of dollars):
2001 2000 1999 ---------- ----------- ---------- As Reflected in Statement of Income: Federal income taxes $ 18,715 $ (12,162) $ 19,943 State income taxes (940) - - ----------- ----------- ---------- Operating Income 17,775 (12,162) 19,943 Other income - net 15,008 2,776 1,270 ----------- ----------- ---------- Total $ 32,783 $ (9,386) $ 21,213 =========== =========== ========== |
The total income tax provisions differ from amounts computed by applying the federal statutory tax rate to income before income taxes for the following reasons (in thousands of dollars):
2001 2000 1999 ------------ ----------- ----------- Income before preferred dividend requirements $ 63,405 $ (7,928) $ 38,787 Total income tax expense 32,783 (9,386) 21,213 ------------ ----------- ----------- 96,188 (17,314) 60,000 Statutory tax rate 35% 35% 35% ------------ ----------- ----------- Expected income tax expense 33,666 (6,060) 21,000 Depreciation related to difference in costs basis for tax purposes 1,431 1,431 1,431 Allowance for funds used during construction - equity 383 300 300 Tax benefit from the disposition of assets - - - State taxes (net of federal benefit) (611) - - ITC amortization (1,630) (1,460) (1,460) Other - net (456) (3,597) (58) ------------ ----------- ----------- $ 32,783 $ (9,386) $ 21,213 ============ =========== =========== Effective tax rate 34.1% 54.2% 35.5% ============ =========== =========== |
The net accumulated deferred federal income tax liability consists of accumulated deferred federal income tax liabilities less related accumulated deferred federal income tax assets, as shown (in thousands of dollars):
2001 2000 ----------- ----------- Deferred Federal Income Tax Liabilities: Allowance for funds used during construction - debt $ 7,659 $ 6,067 Bond redemptions 5,460 5,683 Excess of tax depreciation over book depreciation 212,969 197,248 Severance programs 1,982 1,982 Tax benefits flowed through to customer 113,647 114,097 Deferred energy 343,023 - Other - net 1,943 (1,016) ----------- ----------- 686,683 324,061 ----------- ----------- Deferred Federal Income Tax Assets: Avoided interest capitalized 11,217 9,584 Employee benefit plans 8,555 3,536 Reserve for bad debt 10,801 4,062 Contributions in aid of construction and customer advances 69,232 63,953 Gross-ups received on contributions in aid of construction and customer advances 6,514 4,108 Excess deferred income taxes 5,859 6,358 Unamortized investment tax credit 13,255 13,550 Other - net (5,414) 2,157 ----------- ----------- 120,019 107,308 ----------- ----------- Total $ 566,664 $ 216,753 =========== =========== |
NPC's balance sheets contain a net regulatory asset of $94.4 million at year-end 2001 and $94 million at year-end 2000. The net regulatory asset consists of future revenue to be received from customers (a regulatory asset) of $113.6 million at year-end 2001 and $114 million at year-end 2000, due to flow-through of the tax benefits of temporary differences. Offset against this amount are future revenues to be refunded to customers (a regulatory liability), consisting of $5.9 million at year-end 2001 and $6.4 million at year-end 2000 due to temporary differences for liberalized depreciation at rates in excess of current tax rates, and $13.3 million at year-end 2001 and $13.6 million at year-end 2000 due to unamortized investment tax credits. The regulatory liability for temporary differences related to liberalized depreciation will continue to be amortized using the average rate assumption method required by the Tax Reform Act of 1986. The regulatory liability for temporary differences caused by the investment tax credit will be amortized ratably in the same fashion as the accumulated deferred investment credit. In addition, certain items of deferred taxes represent positive cash flows to NPC. These items reduce rate base and, therefore, are benefits passed through to customers. However, because NPC had a net operating loss for tax purposes in 2001, some of this benefit could not be utilized (i.e., deferred energy).
Sierra Pacific Power Company
The following reflects the composition of taxes on income (in thousands of dollars):
2001 2000 1999 ----------- ----------- ----------- As Reflected in Statement of Income Federal income taxes $ 10,731 $ (1,118) $ 32,982 State income taxes (2,224) 446 888 ----------- ----------- ----------- Operating Income 8,507 (672) 33,870 Other income - net 1,753 (586) (324) ----------- ----------- ---------- Total $ 10,260 $ (1,258) $ 33,546 =========== =========== ========== |
The total income tax provisions differ from amounts computed by applying the federal statutory tax rate to income before income taxes for the following reasons (in thousands of dollars):
2001 2000 1999 ----------- ---------- ----------- Income before preferred dividend requirements $ 22,743 $ (4,077) $ 64,615 Total income tax expense 10,260 (1,258) 33,546 ----------- ---------- ---------- 33,003 (5,335) 98,161 Statutory tax rate 35% 35% 35% ----------- ---------- ---------- Expected income tax expense 11,551 (1,867) 34,356 Depreciation related to difference in costs basis for tax purposes 1,513 1,531 1,408 Allowance for funds used during construction - equity (298) (149) 386 Tax benefit from the disposition of assets (111) (175) (442) ITC amortization (1,824) (1,824) (1,981) State taxes (net of federal benefit) (1,446) 290 577 Other - net 875 936 (758) ----------- ---------- ----------- $ 10,260 $ (1,258) $ 33,546 =========== ========== =========== Effective tax rate 31.1% 23.6% 34.2% =========== =========== =========== |
The net accumulated deferred federal income tax liability consists of accumulated deferred federal income tax liabilities less related accumulated deferred federal income tax assets, as shown (in thousands of dollars):
2001 2000 ----------- ----------- Deferred Federal Income Tax Liabilities: Allowance for funds used during construction - debt $ 4,837 $ 7,399 Bond redemptions 6,048 5,732 Excess of tax depreciation over book depreciation 188,389 176,125 Severance programs 3,317 3,465 Tax benefits flowed through to customer 63,410 65,471 Deferred energy 87,790 5,729 Other 4,132 6,366 ----------- ----------- 357,923 270,287 ----------- ----------- Deferred Federal Income Tax Assets: Avoided interest capitalized 12,444 11,313 Employee benefit plans 3,451 3,789 Reserve for bad debt 2,960 388 Contributions in aid of construction and customer advances 35,163 33,979 Gross-ups received on contributions in aid of construction and customer advances 5,462 5,059 Excess deferred income taxes 12,797 14,494 Unamortized investment tax credit 17,452 18,434 Other 1,871 3,725 ----------- ----------- 91,600 91,181 ----------- ----------- Accumulated Deferred Federal Income Taxes $ 266,323 $ 179,106 =========== =========== |
SPPC's balance sheets contain a net regulatory asset of $33.1 million at year-end 2001 and $32.6 million at year-end 2000. The net regulatory asset consists of future revenue to be received from customers (a regulatory asset) of $63.4 million at year-end 2001 and $65.5 million at year-end 2000, due to flow-through of the tax benefits of temporary differences. Offset against this amount are future revenues to be refunded to customers (a regulatory liability), consisting of $12.8 million at year-end 2001 and $14.5 million at year-end 2000, due to temporary differences for liberalized depreciation at rates in excess of current tax rates, and $17.5 million at year-end 2001 and $18.4 million at year-end 2000 due to unamortized investment tax credits. The regulatory liability for temporary differences related to liberalized depreciation will continue to be amortized using the average rate assumption method required by the Tax Reform Act of 1986. The regulatory liability for temporary differences caused by the investment tax credit will be amortized ratably in the same fashion as the accumulated deferred investment credit. In addition, certain items of deferred taxes represent positive cash flows to SPPC. These items reduce rate base and, therefore, are benefits passed through to customers. However, because SPPC had a net operating loss for tax purposes in 2001, some of this benefit could not be utilized (i.e., deferred energy).
Sierra Pacific Resources
The following reflects the composition of taxes on income (in thousands of dollars):
2001 2000 1999 ------------ ------------ ----------- As Reflected in Statement of Income: Federal income taxes $ 1,934 $ (31,468) $ 24,410 State income taxes (3,164) 446 888 ------------ ------------ ----------- Operating Income (1,230) (31,022) 25,298 Other income - net 16,761 2,190 946 ------------ ------------ ----------- Total $ 15,531 $ (28,832) $ 26,244 ============ ============ =========== |
The total income tax provisions differ from amounts computed by applying the federal statutory tax rate to income before income taxes for the following reasons (in thousands of dollars):
2001 2000 1999 ------------ ---------- ---------- Income before preferred dividend requirements $ 33,566 $ (45,915) $ 50,410 Total income tax expense (benefit) 15,531 (28,832) 26,244 ------------ ---------- --------- 49,097 (74,747) 76,654 Statutory tax rate 35% 35% 35% ------------ ---------- --------- Expected income tax expense (benefit) 17,184 (26,161) 26,829 Depreciation related to difference in costs basis for tax purposes 2,944 2,962 2,839 Allowance for funds used during construction - equity 85 151 686 Tax benefit from the disposition of assets (111) (175) (442) ITC amortization (3,454) (1,824) (1,981) State taxes (net of federal benefit) (2,057) (1,170) (883) Other - net 940 (2,615) (804) ------------ ---------- --------- $ 15,531 $ (28,832) $ 26,244 ============ ========== ========= Effective tax rate 31.6% 38.6% 34.2% =========== ========= ========= |
The net accumulated deferred federal income tax liability consists of accumulated deferred federal income tax liabilities less related accumulated deferred federal income tax assets, as shown (in thousands of dollars):
2001 2000 ------------ ---------- Deferred Federal Income Tax Liabilities: Allowance for funds used during construction - debt $ 12,496 $ 13,466 Bond redemptions 11,508 11,415 Excess of tax depreciation over book depreciation 401,358 373,373 Severance programs 5,299 5,447 Tax benefits flowed through to customer 177,057 179,568 Deferred energy 430,813 5,729 Other 16,558 5,350 ------------ ----------- 1,055,089 594,348 ------------ ----------- Deferred Federal Income Tax Assets: Avoided interest capitalized 23,661 20,897 Employee benefit plans 12,006 7,325 Reserve for bad debt 13,761 4,450 Contributions in aid of construction and customer advances 104,395 97,932 Gross-ups received on contribution in aid of construction and customer advances 11,976 9,167 Excess deferred income taxes 18,656 20,852 Unamortized investment tax credit 30,707 31,984 Other (3,543) (4,569) ------------ ----------- 211,619 188,038 ------------ ----------- Total $ 843,470 $ 406,310 ============ =========== |
SPR's balance sheets contain a net regulatory asset of $127.7 million at year-end 2001 and $126.7 million at year-end 2000. The net regulatory asset consists of future revenue to be received from customers (a regulatory asset) of $177.1 million at year-end 2001 and $179.6 million at year-end 2000, due to flow-through of the tax benefits of temporary differences. Offset against these amounts are future revenues to be refunded to customers (a regulatory liability), consisting of $18.7 million at year-end 2001 and $20.9 million at
year-end 2000, due to temporary differences for liberalized depreciation at rates in excess of current tax rates, and $30.7 million at year-end 2001 and $32 million at year-end 2000 due to unamortized investment tax credits. The regulatory liability for temporary differences related to liberalized depreciation will continue to be amortized using the average rate assumption method required by the Tax Reform Act of 1986. The regulatory liability for temporary differences caused by the investment tax credit will be amortized ratably in the same fashion as the accumulated deferred investment credit. In addition, certain items of deferred taxes represent positive cash flows to SPR. These items reduce rate base and, therefore, are benefits passed through to customers. However, because SPR had a net operating loss for tax purposes in 2001, some of this benefit could not be utilized (i.e., deferred energy).
NOTE 11. FAIR VALUE OF FINANCIAL INSTRUMENTS
The December 31, 2001, carrying amount for cash and cash equivalents, current assets, accounts receivable, accounts payable and current liabilities approximates fair value due to the short-term nature of these instruments.
The total fair value of NPC's consolidated long-term debt at December 31, 2001, is estimated to be 1.56 billion (excluding current portion) based on quoted market prices for the same or similar issues or on the current rates offered to NPC for debt of the same remaining maturities. The total fair value (excluding current portion) was estimated to be $851.2 million at December 31, 2000. The estimated fair value of NPC's preferred trust securities is $181.5 million at December 31, 2001. The fair value of NPC's preferred securities was estimated to be $186.3 million at December 31, 2000.
The total fair value of SPPC's consolidated long-term debt at December 31, 2001, is estimated to be $946.5 million (excluding current portion) based on quoted market prices for the same or similar issues or on the current rates offered to SPPC for debt of the same remaining maturities. The total fair value (excluding current portion) was estimated to be $587.4 million as of December 31, 2000. SPPC's preferred trust securities were redeemed on November 29, 2001. The fair value of SPPC's preferred trust securities was estimated to be $48.5 million at December 31, 2000.
The total fair value of SPR's consolidated long-term debt at December 31, 2001, is estimated to be $3.386 billion (excluding current portion) based on quoted market prices for the same or similar issues or on the current rates offered to SPR for debt of the same remaining maturities. The total fair value (excluding current portion) was estimated to be $2.052 billion as of December 31, 2000. The estimated fair value of SPR's consolidated preferred trust securities is $181.5 million at December 31, 2001. The fair value of SPR's consolidated preferred trust securities was estimated to be $234.8 million at December 31, 2000.
NOTE 12. SHORT-TERM BORROWINGS
SPR
On January 16, 2001, SPR paid off its commercial paper balance of $4 million. SPR cancelled its commercial paper program as of June 12, 2001.
On November 29, 2001, SPR put into place a $75 million unsecured revolving credit facility that may be used for working capital and general corporate purposes. This facility will expire on November 28, 2002. As of December 31, 2001 SPR had not drawn on this facility and had no outstanding balance.
NPC
On November 29, 2001, NPC put into place a $200 million unsecured revolving credit facility that may be used for working capital and general corporate purposes, including commercial paper backup. This new credit facility requires NPC to issue General and Refunding Mortgage Bonds to secure this credit facility in the event of a decline in NPC's senior unsecured debt rating. This facility will expire on November 28, 2002.
On December 17, 2001, $100 million of NPC's floating rate notes matured and were paid in full.
On December 31, 2001, NPC had a commercial paper balance outstanding of $130.5 million with a weighted average interest rate of 2.85%, and remaining capacity to issue an additional $69.5 million under its commercial paper program. NPC sustained its A2/P2 ratings by Standard and Poor's and Moody's, respectively.
SPPC
On November 29, 2001, SPPC put into place a $150 million unsecured revolving credit facility that may be used for working capital and general corporate purposes, including commercial paper backup. This new credit facility requires SPPC to issue General and Refunding Mortgage Bonds to secure this credit facility in the event of a decline in SPPC's senior unsecured debt rating. This facility will expire on November 28, 2002.
On December 31, 2001, SPPC had a commercial paper balance outstanding of $46.5 million with a weighted average interest rate of 2.77%, and remaining capacity to issue an additional $103.5 million under its commercial paper program. SPPC sustained its A2/P2 ratings by Standard and Poor's and Moody's, respectively.
NOTE 13. DIVIDEND RESTRICTIONS
SPR's primary source of funds for the payment of dividends to its stockholders is dividends paid by the Utilities on their common stock, all of which is owned by SPR. Accordingly, SPR's ability to pay dividends is dependent upon the ability of the Utilities to pay dividends on their common stock. The Restated Articles of Incorporation of the Utilities, the indentures relating to the various series of their First Mortgage Bonds, and the bank credit agreements of SPR and the Utilities contain restrictions as to the payment of dividends on their common stock and as to the purchase, redemption or retirement of their capital stock.
NOTE 14. RETIREMENT PLAN AND POST-RETIREMENT BENEFITS
Pension and other postretirement benefit plans: SPR has pension plans covering substantially all employees. Benefits are based on years of service and the employee's highest compensation for a period prior to retirement. SPR also has other postretirement plans which provide medical and life insurance benefits for certain retired employees. The following table provides a reconciliation of benefit obligations, plan assets and the funded status of the plans. This reconciliation is based on a September 30 measurement date and reflects the acquisition of SPPC by NPC during 1999 under purchase accounting:
Other Postretirement Pension Benefits Benefits ------------------------------- ---------------------------- 2001 2000 2001 2000 ------------------------------ ---------------------------- Change in benefit obligations Benefit obligation, beginning of year $ 348,135 $ 348,470 $ 77,790 $ 77,987 Service cost 13,494 11,907 1,922 1,775 Interest cost 27,742 26,469 6,358 5,829 Participant contributions - - 466 300 Plan amendment and special termination 476 498 - - Actuarial loss (gain) 6,864 (8,922) (5,201) (4,101) Special Termination Benefits 394 - - - Acquisitions and divestiture - - (1,231) - Benefits paid (36,428) (30,287) (4,661) (4,000) ------------- ------------- ------------ ------------ Benefit obligation, end of year $ 360,677 $ 348,135 $ 75,443 $ 77,790 ============= ============= ============ ============ Change in plan assets Fair value of plan assets, beginning of year $ 349,153 $ 326,708 $ 81,900 $ 66,688 Actual return on plan assets (39,320) 51,136 (15,797) 17,377 Company contributions 1,900 1,596 730 1,535 Participant contributions - - 466 300 Acquistion and divestiture - - (1,231) - Benefits paid (36,428) (30,287) (4,661) (4,000) ------------- ------------- ------------ ------------ Fair value of plan assets, end of year $ 275,305 $ 349,153 $ 61,407 $ 81,900 ============= ============= ============ ============ Funded Status, end of year $ (85,373) $ 1,018 $ (14,036) $ 4,110 Unrecognized net actuarial (gains) losses 61,750 (13,526) (5,365) (22,696) Unrecognized prior service cost 10,366 11,561 - - Unrecognized net transition obligation - - 10,280 11,248 Contributions made in 4th quarter 11,917 270 - - ------------- ------------- ------------ ------------ Accrued pension and postretirement benefit obligations $ (1,340) $ (677) $ (9,121) $ (7,338) ============= ============= ============ ============ |
Amounts for pension and postretirement benefits recognized in the consolidated balance sheets consist of the following:
Pension Benefits Benefits ------------------------- ------------------------- 2001 2000 2001 2000 ------------------------- ------------------------- Prepaid pension asset $ 14,051 $ 13,939 N/A N/A Accrued benefit liability (15,391) (14,616) $ (9,121) $ (7,338) Intangible asset - - N/A N/A Accumulated other comprehensive income 1,395 1,395 N/A N/A Additional minimum liability (1,395) (1,395) N/A N/A ----------- ----------- ----------- ----------- Net amount recognized $ (1,340) $ (677) $ (9,121) $ (7,338) =========== =========== =========== =========== |
The weighted-average actuarial assumptions as of the measurement date were as follows:
Other Postretirement Pension Benefits Benefits ---------------------------- ------------------------------ 2001 2000 1999 2001 2000 1999 ---------------------------- ------------------------------ Discount rate 7.50% 8.00% 7.50% 7.50% 8.00% 7.50% Expected return on plan assets 8.50% 8.50% 8.50% 8.50% 8.50% 8.50% Rate of compensation increase 4.50% 4.50% 4.50% N/A N/A N/A |
SPR has assumed a health care cost trend rate of 6% for 2001 and all future years.
Net periodic pension and other postretirement benefit costs include the following components:
Pension Benefits -------------------------------------- 2001 2000 1999 -------------------------------------- Service cost $ 13,494 $ 11,907 $ 8,481 Interest cost 27,742 26,469 12,823 Expected return on assets (28,806) (27,186) (11,712) Amortization of: Transition asset - - - Prior service costs 1,195 1,201 841 Actuarial losses 200 159 976 ----------- ----------- ------------ Net periodic benefit cost 13,825 12,550 11,409 Additional charges (credits): Special termination charges 394 - 5,865 Curtailment credits - - (3,920) ----------- ----------- ------------ Total net benefit cost $ 14,219 $ 12,550 $ 13,354 =========== =========== ============ Other Postretirement Benefits -------------------------------------- 2001 2000 1999 -------------------------------------- Service cost $ 1,922 $ 1,775 $ 996 Interest cost 6,358 5,829 1,982 Expected return on assets (6,774) (5,327) (1,741) Amortization of: Prior service costs - - - Transition obligation 969 968 1,344 Actuarial gains - (598) (596) ----------- ----------- ------------ Net periodic benefit cost 2,475 2,647 1,985 Additional charges (credits): Special termination charges - - 1,312 Curtailment loss - - 1,283 ----------- ----------- ------------ Total net benefit cost $ 2,475 $ 2,647 $ 4,580 =========== =========== ============ |
The assumed health care cost trend rate has a significant effect on the amounts reported. A one percentage point change in the assumed health care cost trend rate would have had the following effects on 2001 service and interest costs and the accumulated postretirement benefit obligation at year end:
One percentage point change Increase Decrease --------------------------- -------- -------- Effect on service and interest components of net periodic cost $ 708 $ (583) Effect on accumulated postretirement benefit obligation $ 6,961 $(5,839) |
NOTE 15. STOCK COMPENSATION PLANS
At December 31, 2001, Sierra Pacific Resources had several stock-based compensation plans which are described below. SPR applies Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees, in accounting for its stock option plans. Accordingly, no compensation cost has been recognized for nonqualified stock options and the employee stock purchase plan. The total compensation cost (benefit) that has been charged against income for the performance shares, dividend equivalents, restricted stock grants, and the non-employee director stock plans was $0.5 million for 2001, ($0.2 million) for 2000, and $0.2 million for 1999. SPR has adopted the disclosure-only provisions of SFAS No. 123, Accounting for Stock Based Compensation. Had compensation cost for SPR's nonqualified stock options and the employee stock purchase plan been determined based on the fair value at the grant dates for awards under those plans consistent with the provisions of SFAS No. 123, SPR's income applicable to common stock would have been decreased to the pro forma amounts indicated below:
2001 2000 1999 -------------------------------- Net Income (Loss) As Reported $ 56,733 $ (39,780) $ 51,750 Pro Forma $ 55,524 $ (40,475) $ 50,908 Basic Earnings (Loss) Per Share As Reported $ 0.65 $ (0.51) $ 0.83 Pro Forma $ 0.63 $ (0.52) $ 0.81 Diluted Earnings (Loss) Per Share As Reported $ 0.65 $ (0.51) $ 0.83 Pro Forma $ 0.63 $ (0.52) $ 0.81 |
SPR's executive long-term incentive plan for key management employees, which was approved by shareholders on May 16, 1994, provides for the issuance of up to 750,000 of SPR's common shares to key employees through December 31, 2003. On June 19, 2000, shareholders approved an increase of 1,000,000 shares for the executive long-term incentive plan. The plan permits the following types of grants, separately or in combination: nonqualified and qualified stock options, stock appreciation rights, restricted stock, performance units, performance shares, and bonus stock. During 2001, SPR issued nonqualified stock options, performance shares, and restricted stock under the long-term incentive plan.
Non-Qualified Stock Options
Nonqualified stock options granted during 2001 were issued at an option price not less than market value at the date of the grants: January 1, May 15, May 22, July 19, and November 15. The January 1 grant vests to the participants 33% per year over a 3 year period from the grant date, and the remaining grants vest to the participants 25% per year over a four year period from the grant date. All grants may be exercised for a
period not exceeding ten years from the grant date. The options may be exercised using either cash or previously acquired shares, valued at the current market price, or a combination of both.
A summary of the status of SPR's nonqualified stock option plan as of December 31, 2001, 2000, and 1999, and changes during the year is presented below:
----------------------------------------------------------------------------------------------------------------------------- 2001 2000 1999 ------------------------------------------------------------------------------------- Weighted- Weighted- Weighted- Average Exercise Average Exercise Average Nonqualified Stock Options Shares Price Shares Price Shares Exercise Price ----------------------------------------------------------------------------------------------------------------------------- Outstanding at beginning of year 799,428 $ 19.94 839,442 $ 24.33 289,126 $ 21.98 Granted/1/ 414,530 $ 15.08 400,000 $ 16.00 586,280 $ 25.35 Exercised - - 14,107 $ 14.28 1,286 $ 14.39 Forfeited - - 425,907 $ 25.07 34,678 $ 22.48 Outstanding at end of year 1,213,958 $ 18.28 799,428 $ 19.94 839,442 $ 24.33 Options exercisable at year-end 262,533 $ 23.03 202,394 $ 22.66 128,975 $ 20.53 Weighted-average grant date fair value of options granted/2/: November 15, 2001 $ 3.28 July 19, 2001 $ 4.62 May 22, 2001 $ 3.90 May 15, 2001 $ 4.05 January 1, 2001 $ 3.32 August 4, 2000 $ 4.10 August 1, 1999 $ 5.11 January 1, 1999 $ 4.05 ----------------------------------------------------------------------------------------------------------------------------- |
1. The number of nonqualified stock options granted during the year was 414,530
shares.
2. The fair value of each nonqualified option has been estimated on the date
of grant using the Black-Scholes option pricing model with the following
assumptions used for grants issued in 2001, 2000 and 1999:
------------------------------------------------------------------------------- Dividend Expected Risk-Free Rate of Option Grant Date Yield Volatility Return Expected Life ------------------------------------------------------------------------------- November 15, 2001 5.04% 32.37% 4.63% 10 years July 19, 2001 4.47% 32.02% 5.66% 10 years May 22, 2001 4.98% 32.48% 5.55% 10 years May 15, 2001 4.98% 32.48% 5.55% 10 years January 1, 2001 5.48% 32.22% 5.22% 10 years August 4, 2000 4.81% 30.49% 6.14% 9.6 years August 1, 1999 4.25% 17.41% 6.31% 10 years January 1, 1999 4.40% 18.60% 5.08% 10 years ------------------------------------------------------------------------------- |
The following table summarizes information about nonqualified stock options outstanding at December 31, 2001:
------------------------------------------------------------------------------------- Options Outstanding Options Exercisable ------------------------------------------------------- Number Remaining Number Exercise Outstanding Contractual Exercise Exercisable Grant Date Price at 12/31/01 Life Price at 12/31/01 ------------------------------------------------------------------------------------- 1/1/1994 $14.24 8,003 2 years $14.24 8,003 1/1/1995 $13.02 9,750 3 years $13.02 9,750 1/1/1996 $16.23 8,674 4 years $16.23 8,674 1/1/1997 $19.97 45,501 5 years $19.97 45,501 1/1/1998 $24.93 69,120 6 years $24.93 69,120 1/1/1999 $24.22 106,080 7 years $24.22 70,724 8/1/1999 $26.00 152,300 7.6 years $26.00 50,762 8/4/2000 $16.00 400,000 8 years $16.00 - 1/1/2001 $14.80 310,530 9 years $14.80 - 5/15/2001 $16.09 27,000 9.5 years $16.09 - 5/22/2001 $15.52 40,000 9.5 years $15.52 - 7/19/2001 $16.95 27,000 9.6 years $16.95 - 11/15/2001 $14.12 10,000 9.9 years $14.12 - Weighted Average Remaining 7.9 years Contractual Life ------------------------------------------------------------------------------------ |
Each participant was granted dividend equivalents for all 1996 and prior nonqualified option grants. Each dividend equivalent entitles the participant to receive a contingent right to be paid an amount equal to dividends declared on shares originally granted from the date of grant through the exercise date. Dividend equivalents will be forfeited if options expire unexercised.
Performance Shares
In 2001, 2000 and 1999, SPR granted performance shares in the following numbers and initial values:
1/1/2001 8/4/2000 1/1/2000 1/1/1999 ----------------------------------------------- Shares Granted 135,906 4,798 31,707 28,944 Value per Share $ 14.80 $16.00 $ 26.00 $ 24.22 |
The actual number of shares earned by each participant is dependent upon SPR achieving certain financial goals over three-year performance periods. However, 66,100 shares included in the number granted on 1/1/2001 have a one-year performance period, from January 1 through December 31, 2001. The value of all performance share grants, if earned, will be equal to the market value of SPR's common shares as of the end of the performance periods. Sierra Pacific Resources, at its sole discretion, may pay earned performance shares in the form of cash or in shares, or a combination thereof. The grant of 66,100 shares on 1/1/2001 will be paid in SPR stock only.
Simultaneous with the grant of the performance shares above, each participant was granted dividend equivalents. Each dividend equivalent entitles the participant to receive a contingent right to be paid an amount equal to dividends declared on shares originally granted throughout the performance period. Additionally, in order for dividend equivalents to be paid on the performance shares, certain financial targets must be met. Dividend equivalents will be forfeited if options expire unexercised.
Restricted Stock Shares
In 2001, SPR granted 13,200 restricted stock shares, detailed as follows:
Grant Date 11/15/2001 7/19/2001 5/22/2001 5/15/2001 -------------------------------------------------- Shares Granted 2,400 2,500 4,000 4,300 Grant Price per Share $14.12 $16.95 $15.52 $16.09 |
Vesting Schedule for all: 4 years, 25% per year
In 2000, SPR granted 16,000 restricted stock shares at a grant price of $16.00 per share. The grant vests over 4 years with 4,000 shares becoming available in 2002, 4,000 shares in 2003, and 8,000 shares in 2004. No restricted stock grants were issued in 1999. There are no performance criteria associated with the restricted stock grants, and all grants were issued with an entitlement to dividend equivalents.
Employee Stock Purchase Plan
Upon the inception of SPR's employee stock purchase plan, SPR was authorized to issue up to 400,162 shares of common stock to all of its employees with minimum service requirements. On June 19, 2000, shareholders approved an additional 700,000 shares for distribution under the plan. According to the terms of the plan, employees can choose twice each year to have up to 15% of their base earnings withheld to purchase SPR's common stock. The purchase price of the stock is 90% of the market value on the offering commencement date. Employees can withdraw from the plan at any time prior to the exercise date. Under the plan SPR sold 33,830, 46,773 and 21,888 shares to employees in 2001, 2000 and 1999, respectively. Compensation cost has been estimated for the employees' purchase rights on the date of grant using the Black-Scholes option-pricing model with the following assumptions used for 2001, 2000 and 1999:
---------------------------------------------------------------- Average Average Average Weighted Dividend Expected Risk-Free Average Fair Year Yield Volatility Rate of Return Value ---------------------------------------------------------------- 2001 5.01% 32.43% 2.82% $2.72 2000 4.72% 30.97% 5.86% $3.03 1999 4.31% 18.85% 5.08% $2.85 |
Non-Employee Director Stock Plan
SPR's non-employee director stock plan provides that a portion of the outside directors' annual retainer be paid in SPR stock. Under the current plan, the annual retainer for non-employee directors is $30,000, and the minimum amount to be paid in SPR stock is $20,000 per director. During 2001, 2000 and 1999, SPR granted the following total shares and related compensation to directors in SPR stock, respectively: 14,573, 16,915 and 4,741 shares, and $210,000, $250,000 and $150,000. SPR did not pay out any phantom stock shares in 2001.
NOTE 16. POSTEMPLOYMENT BENEFITS
During 1999, SPR offered a severance program to non-bargaining-unit employees, which provides for severance pay and medical benefits continuation totaling $14.3 million and $0.8 million respectively. As approved by the PUCN in 1999, this cost is being deferred as a regulatory asset as of December 31, 2001. The order approving the merger by the PUCN, directed the Utilities to defer merger costs (including severance and related benefits) for a three-year period. The deferral of these costs is intended to allow adequate time for the anticipated savings from the merger to develop. At the end of the three-year period, the order instructed the Utilities to propose an amortization period for these costs, and allows SPPC and NPC to recover the costs to the extent that they are offset by merger savings. The Utilities have filed a case with the PUCN for recovery of these amounts and other merger costs. NPC and SPPC have proposed recovery over a 10-year period, and expect a decision on their filings by April 1, 2002 and June 1, 2002, respectively. At December 31, 2001, the remaining liability for unpaid severance was $0.4 million.
NOTE 17. DISCONTINUED OPERATIONS (SALE OF WATER BUSINESS)
On September 7, 2000, SPR and SPPC adopted a plan to sell SPPC's water utility business, and on June 11, 2001, SPPC closed the sale of its water business to the Truckee Meadows Water Authority (TMWA) for $341 million. SPPC recorded a $25.8 million gain on the sale, net of the refund described below and net of income taxes of $18.2 million. Included in the sale were facilities for water storage, supply, transmission, treatment and distribution, as well as accounts receivable and regulatory assets. Accounts receivable consisted of amounts due from developers for distribution facilities. Regulatory assets consisted primarily of costs incurred in connection with the Truckee River negotiated water settlement. Transfer of hydroelectric facilities included in the contract of sale for an additional $8 million will require action by the California Public Utilities Commission (CPUC). The sale agreement contemplates a second closing for the hydroelectric facilities to accommodate the CPUC's review of the transaction.
Pursuant to a stipulation entered into in connection with the sale and approved by the Public Utilities Commission of Nevada ("PUCN"), SPPC is required to hold in trust for refund to customers $21.5 million of the proceeds from the sale. The refund is being credited on the electric bills of SPPC's former water customers over a period not to exceed fifteen months from June 11, 2001. Under a service contract with TMWA, SPPC will provide, on an interim basis, customer service, billing, and meter reading services to TMWA.
Revenues from operations of the water business for the years ended December 31, 2001, 2000, and 1999 were $23 million, $57 million, and $54 million, respectively. The net income from operations of the water business, as shown in the Consolidated Statements of Income of SPR, includes (in thousands) preferred dividends of $200, $401, and $196 for the years ended December 31, 2001, 2000, and 1999, respectively. The income from operations of the water business, as shown in the Consolidated Statements of Income of SPPC, includes (in thousands) preferred dividends of $200, $401, and $528 for the years ended December 31, 2001, 2000, and 1999, respectively. These amounts are not included in the revenues and income (loss) from continuing operations shown in the accompanying income statements.
NOTE 18. COMMITMENTS AND CONTINGENCIES
The Utilities' combined estimated cash construction expenditures for the year 2002 and the five-year period 2002-2006 are $470 million and $1.7 billion, respectively.
NPC has three long-term contracts for the purchase of electric energy. One of these contracts commences in 2004 and expires in 2012. NPC's other contracts expire in 2016 and 2017. SPPC has one such contract that expires in 2009. Estimated future commitments under non-cancelable agreements with initial terms of one year or more at December 31, 2001, were as follows (dollars in thousands):
2002 $ 46,440 2003 152,852 2004 151,627 2005 136,680 2006 137,446 2007 to 2017 777,064 |
According to the regulations of the Public Utility Regulator Policies Act, the Utilities are obligated, under certain conditions, to purchase the generation produced by small power producers and cogeneration facilities at costs determined by the appropriate state utility commission. Generation facilities that meet the specifications of the regulations are known as qualifying facilities (QFs). As of December 31, 2001, NPC had a total of 305 MWs of contractual firm capacity under contract with four QFs. The contracts terminate between 2022 and 2024. As of December 31, 2001, SPPC had a total of 109 MWs of maximum contractual firm capacity under 15 contracts with QFs. SPPC also had contracts with three projects at variable short-term avoided cost rates. One of SPPC's long-term QF contracts terminates in 2006, one terminates in 2039, and the rest terminate between 2014 and 2022.
The Utilities have several long-term contracts for the purchase and transportation of coal and natural gas. These contracts expire in years ranging from 2006 to 2027. Estimated future commitments under non-cancelable agreements with initial terms of one year or more at December 31, 2001 were as follows (dollars in thousands):
Coal and Gas Transportation 2002 $ 42,870 $ 78,255 2003 39,528 86,499 2004 36,451 93,031 2005 17,534 79,137 2006 18,045 76,254 2007 to 2023 0 725,651 |
In 1984, NPC sold its administrative headquarters facility, less furniture and fixtures, for $27 million and entered into a 30-year capital lease of that facility with five-year renewal options beginning in year 31. The fixed rental obligation for the first 30 years is $5.1 million per year. Future cash rental payments as of December 31, 2001, were as follows (dollars in thousands):
2002 $ 6,156 2003 6,156 2004 6,946 2005 7,736 2006 7,736 2007 to 2014 58,016 |
The amount of imputed interest necessary to reduce the future cash rental payments to present value is $44 million as of December 31, 2001. Total interest expense on the lease obligation was $5.7 million and total amortization of the leased facility was $(278,000) for the year ended December 31, 2001. The total accumulated amortization of the leased facility on December 31, 2001, was $8.6 million.
SPPC has an operating lease for its corporate headquarters building. The primary term of the lease is 25 years, ending in 2010. The current annual rental is $5.4 million, which amount remains constant until the end of the primary term. The lease has renewal options for an additional 50 years.
SPR's estimated future minimum cash payments, including SPPC's headquarters building, under non-cancelable operating leases with initial terms of one year or more at December 31, 2001, were as follows (dollars in thousands):
2002 $ 12,127 2003 9,284 2004 8,194 2005 7,289 2006 6,863 2007 to 2045 63,463 |
As a condition to its approval of the merger between SPR and NPC, the PUCN required the Utilities to file a Divestiture Plan for the sale of their electric generation assets. The PUCN approved a revised Divestiture Plan stipulation in February 2000. In May 2000 an agreement was announced for the sale of NPC's 14% undivided interest in the Mohave Generating Station ("Mohave"). In the fourth quarter of 2000 the Utilities announced agreements to sell six additional bundles of generation assets described in the approved Divestiture Plan. The sales were subject to approval and review by various regulatory agencies.
AB 369, which was signed into law on April 18, 2001, prohibits until July 2003 the sale of generation assets and directs the PUCN to vacate any of its orders that had previously approved generation divestiture transactions. In January 2001, California enacted a law that prohibits until 2006 any further divestiture of generation properties by California utilities, including SPPC, and could also affect any sale of NPC's interest in Mohave after July 2003 since the majority owner of that project is Southern California Edison. In addition, SPPC's request for an exemption from the requirements of a separate California law requiring approval of the CPUC to divest its plants was denied, subject to future refiling.
The sales agreements for the six bundles provide that they terminate eighteen months after their execution unless the parties agree to an earlier termination. The parties may extend the termination another six months to obtain additional regulatory approvals. As a result of the legislative and regulatory developments which have rendered the contracts impossible to perform, the Utilities are engaged in discussions with the buyers of the generation assets regarding the formal termination of the sales agreements and the related energy buyback contracts and interconnection agreements. As of December 31, 2001, NPC and SPPC had incurred costs of approximately $12.3 million and $15.5 million, respectively, in order to prepare for the sale of generation assets. The Utilities have requested recovery of these costs in each Utility's respective general rate case filing with the PUCN, discussed in Note 3, Regulatory Actions.
Nevada Power Company
The Grand Canyon Trust and Sierra Club filed a lawsuit in the U.S. District Court, District of Nevada, in February 1998, against the owners (including NPC) of the Mohave Generation Station ("Mohave"), alleging violations of the Clean Air Act regarding emissions of sulfur dioxide and particulates. An additional plaintiff, National Parks and Conservation Association, later joined the suit. The plant owners and plaintiffs have had numerous settlement discussions and filed a proposed settlement with the court in October 1999. The consent decree, approved by the court in November 1999, established emission limits for sulfur dioxide and opacity and required installation of air pollution controls for sulfur dioxide, nitrogen oxides and particulate matter. The new emission limits must be met by January 1, 2006 and April 1, 2006 for the first and second units respectively. However, if the owners sell their entire ownership interest with a closing date prior to December 30, 2002, the new emission limits become effective 36 months and 39 months from the date of last closing for the two respective units. The estimated cost of new controls is $395 million. As a 14% owner in the Mohave Station, NPC's cost could be $55 million.
Also, the United States Congress authorized the EPA to study the potential impact Mohave may have on visibility in the Grand Canyon area. A final report of the study results was released in March 1999. The study acknowledges that sulfur dioxide emissions from Mohave are transported to the Grand Canyon. The EPA has solicited information to determine whether visibility impairment in the Grand Canyon can be reasonably attributed to Mohave. The EPA determined that significant visibility impairment to the Grand Canyon cannot be reasonably attributable to the station provided controls are installed as agreed to in the consent order. Therefore, the EPA will not require a Best Available Retrofit Technology Review. Provisions that were agreed to in the settlement will be reflected in the state Implementation Plan for Nevada.
In May 1997, NDEP ordered NPC to submit a plan to eliminate the discharge of Reid Gardner Station wastewater to groundwater. The NDEP order also required a hydrological assessment of groundwater impacts in the area. In June 1999, NDEP determined that wastewater ponds had degraded groundwater quality. In August 1999, NDEP issued a discharge permit to Reid Gardner Station and an order that requires all wastewater ponds to be closed or lined with impermeable liners over the next 10 years. This order also required NPC to submit a Site Characterization Plan to NDEP to ascertain impacts. This plan is under review by NDEP. After approval, an estimate of remediation costs will be determined by NPC. New pond construction and lining costs are estimated at $15 million.
Also, at the Reid Gardner Station, the NDEP has determined that there is additional groundwater contamination that resulted from oil spills at the facility. NDEP has required submitting a corrective action plan. The extent of contamination has been determined and remediation is occurring at a modest rate. An engineering evaluation of the current remediation technology will occur in 2002 to verify efficiency and to expedite remediation. Remediation modifications are not expected to materially affect the financial position of SPR or NPC.
In May 1999, NDEP issued an order to eliminate the discharge of NPC's Clark Station wastewater to groundwater. The order also required a hydrological assessment of groundwater impacts in the area. This assessment, submitted to NDEP in February 2001, warranted a Corrective Action Plan which was submitted to NDEP in November and is pending review. Remediation costs are expected to be in the $500,000 - $750,000 range. In addition to remediation, NPC will spend $789,000 to line existing ponds. After review and approval of the Corrective Action Plan by NDEP, NPC will implement remediation.
In July 2000, NPC received a request from the EPA for information to determine the compliance of certain generation facilities at the Clark Station with the applicable State Implementation Plan. In November 2000, NPC and the Clark County Health District entered into a Corrective Action Order requiring, among other steps, capital expenditures at the Clark Station totaling approximately $3 million. In March 2001, the EPA issued an additional request for information that could result in remediation beyond that specified in the November 2000 Corrective Action Order. If the EPA prevails, capital expenditures and temporary outages of four of Clark Station's generation units could be required. Additionally, depending on the time of year that the compliance activity and corresponding generation outage would occur, the incremental cost to purchase replacement energy could be substantial.
Sierra Pacific Power Company
In September 1994, Region VII of EPA notified SPPC that it was being named as a potentially responsible party (PRP) regarding the past improper handling of Polychlorinated Biphenyls (PCBs) by PCB Treatment, Inc., located in Kansas City, Kansas, and Kansas City, Missouri (the Sites). The EPA is requesting that SPPC voluntarily pay an undefined, pro rata share of the ultimate clean-up costs at the Sites. A number of the largest PRP's formed a steering committee, which is chaired by SPPC. The responsibility of the Committee is to direct clean-up activities, determine appropriate cost allocation, and pursue actions against recalcitrant parties, if necessary. The EPA issued an administrative order on consent requiring signatories to perform certain investigative work at the Sites. The steering committee retained a consultant to prepare an analysis regarding the Sites. The Site evaluations have been completed. EPA is developing an allocation formula to allocate the remediation costs. SPPC has recorded a preliminary liability for the Sites of $650,000 of which approximately $136,000 has been spent through December 31, 2001. Once evaluations are completed, SPPC will be in a better position to estimate and record the ultimate liabilities for the Sites.
Other Subsidiaries of SPR
LOS, a wholly owned subsidiary of SPR, owns property in North Lake Tahoe, California, which is leased to independent condominium owners. The property has both soil and groundwater petroleum contaminate resulting from an underground fuel tank that has been removed from the property. Additional contaminate from a third party fuel tank on the property has also been identified and is undergoing remediation. Estimated future remediation costs are not expected to be significant.
NEICO, a wholly owned subsidiary of SPR, owns property in Wellington, Utah, which was the site of a coal washing and load out facility. The site now has a reclamation estimate supported by a bond of $4 million with the Utah Division of Oil and Gas Mining. The property was under contract for sale and the contract required the purchaser to provide $1.3 million in escrow towards reclamation. However, the sales contract was terminated and NEICO took title to the escrow funds. In September 2000, NEICO leased the property together with an option to purchase. It is NEICO's intention to either lease or sell the property.
SPR is a limited partner in an energy technology venture capital partnership formed to gain access to new technologies that could affect SPR and its subsidiaries. This partnership invests in energy companies offering technologies of strategic advantage to its partners. The initial term of this partnership expires in 2006, with two extensions of up to two years each. SPR's investment in the partnership was $4.7 million as of December 31, 2001, of which $325,000 was made in 2001. The remaining $300,000 balance of SPR's commitment is expected to be drawn, as funds are needed by the partnership during 2002. Gains and losses will be allocated 80% to the limited partners based on their contributions, and 20% to the general partner. SPR, as a limited partner, is entitled to 7.89%.
Certain of the Utilities' substations and portions of its generating stations, transmission, distribution, and communication systems are located on lands owned by units or agencies of federal, state and local governments under licenses, permits, easements (collectively, "rights"). Except for those granted in perpetuity, these rights may be canceled, with notice, at the will of the grantor. Certain rights may impose restrictions and obligations on the Utilities, including, but not limited to, care of property, limits on use, and the right of inspection. Certain of the rights obligate the Utilities to make periodic payments and may also allow the grantor to periodically reappraise the lands on which the Utilities' property is located. Such reappraisals, which may result in a change to the required periodic payments, may occur from annually to every five years. In connection with these rights, the Utilities incurred expenses of $1.41 million, $1.11 million and $1.38 million in 2001, 2000, and 1999, respectively.
Sierra Touch America LLC (STA), a partnership between SPC and Touch America, a subsidiary of Montana Power Company, is constructing a fiber optic line between Salt Lake City, Utah and Sacramento, CA. The conduits included in the line are under contract to be sold to AT&T, PF Net corporations, and STA. SPC is responsible for 50% of the partnership's operating expenses and shares in the construction cost of the fiber network. Construction activity between Sacramento and Reno commenced in July 2000, and the estimated completion date has been moved to early 2003. Williams Communications, LLC ("Williams") has filed a complaint in United States District Court alleging that STA has failed to make timely payment on invoices in connection with a construction agreement between Williams and STA. TI Energy Services ("TI") has filed a complaint in the District Court of Harris County, Texas, alleging that STA has failed to make timely payment on invoices in connection with a services agreement between TI and STA, whereby TI is to provide services for certain segments of the fiber optic line. Although SPC's ultimate liability, if any, cannot be estimated, Management believes the final outcome of the litigation is not likely to have a material adverse effect on SPR's financial position or results of operations.
SPPC owns a 345 kV transmission line that connects SPPC to the facilities of the Bonneville Power Administration ("BPA") near Alturas, California. The Transmission Agency of Northern California ("TANC") initiated proceedings in the United States District Court for the Eastern District of California and the United States Court of Appeals for the Ninth Circuit, in each case alleging that BPA's construction of a small portion of the Alturas Intertie violated the Northwest Power Preference Act and requesting an injunction prohibiting operation of the Alturas Intertie. The case before the Eastern District was dismissed for lack of jurisdiction. The case before the Ninth Circuit was dismissed for TANC's failure to prosecute. In December 1999, TANC filed suit in the Superior Court of the State of California, Sacramento County, seeking an injunction against operation of the Alturas Intertie based on numerous allegations under state law, including inverse condemnation, trespass, private nuisance, and conversion. That case was removed to Federal Court and dismissed by the trial court, and is now on appeal in the Ninth Circuit. Although SPPC's ultimate liability, if any, cannot be estimated at this time, Management believes the final outcome of the appeal and any subsequent litigation is not likely to have a material adverse effect on SPR's financial position or results of operation.
SPR and its subsidiaries, through the course of their normal business operations, are currently involved in a number of other legal actions, none of which has had or, in the opinion of management, is expected to have, a significant impact on its financial position or results of operations.
See Notes 3, 5, 6, 7, 8, 9, 12, 14, and, 16 of SPR's consolidated financial statements for additional commitments and contingencies.
NOTE 19. SEGMENT INFORMATION
SPR operates three business segments (as defined by FASB statement No. 131, Disclosure about Segments of an Enterprise and Related Information) providing regulated electric, natural gas and water service. Electric service is provided to Las Vegas and surrounding Clark County, northern Nevada and the Lake Tahoe
area of California. Natural gas and water services are provided in the Reno-Sparks area of Nevada. Other segment information includes segments below the quantitative threshold for separate disclosure.
On September 7, 2000, SPR and SPPC adopted a plan to sell SPPC's water utility business. Accordingly, the water business is reported as a discontinued operation and the consolidated financial statements have been reclassified to report separately the net assets and operating results of the water business. Therefore the water business is not reflected in the segment information below.
Operational information of the different business segments is set forth below based on the nature of products and services offered. SPR evaluates performance based on several factors, of which the primary financial measure is business segment operating income. The accounting policies of the business segments are the same as those described in Note 1, Summary of Significant Accounting Policies. Intersegment revenues are not material.
In accordance with the requirements of purchase accounting and based on a merger date of August 1, 1999, the segmented financial information for the period ended December 31, 1999, includes five months of operating activity for SPR's subsidiaries other than NPC.
Reconciling December 31, 2001 NPC Electric SPPC Electric Total Electric Gas All Other Eliminations Consolidated ----------------- ------------------------------------------- --------- --------- ------------ ------------ Operating revenues $ 3,025,103 $ 1,399,134 $ 4,424,237 $ 145,652 $ 18,841 $ 4,588,730 Operating income 144,364 71,219 215,583 7,749 (463) - 222,869 Operating income taxes 17,775 5,534 23,309 2,973 (27,512) (1,230) Depreciation 93,101 64,648 157,749 5,710 1,181 164,640 Interest expense on long term debt 81,599 50,071 131,670 5,128 51,572 188,370 Assets 5,225,369 2,336,479 7,561,848 264,108 270,038 85,320 8,181,314 Capital expenditures 200,852 117,563 318,415 16,041 - 334,456 Reconciling December 31, 2000 NPC Electric SPPC Electric Total Electric Gas All Other Eliminations Consolidated ----------------- ------------------------------------------- --------- --------- ------------ ------------ Operating revenues $ 1,325,470 $ 893,782 $ 2,219,252 $ 100,803 $ 14,199 $ 2,334,254 Operating income 73,460 33,715 107,175 13,420 6,794 127,389 Operating income taxes (12,162) (3,944) (16,106) 3,272 (18,188) (31,022) Depreciation 85,989 64,375 150,364 4,975 696 156,035 Interest expense on long term debt 64,513 32,547 97,060 4,318 33,218 134,596 Assets 3,407,751 1,722,725 5,130,476 151,905 61,768 333,759 5,677,908 Capital expenditures 204,505 117,429 321,934 14,490 23,350 359,774 Reconciling December 31, 1999 NPC Electric SPPC Electric Total Electric Gas All Other Eliminations Consolidated ----------------- ------------------------------------------- --------- --------- ------------ ------------ Operating revenues $ 977,262 $ 259,440 $ 1,236,702 $ 38,958 $ 9,132 $ 1,284,792 Operating income 116,983 40,047 157,030 3,175 2,656 162,861 Operating income taxes 19,943 10,177 30,120 425 (5,247) 25,298 Depreciation 80,644 27,060 107,704 2,128 243 110,075 Interest expense on long term debt 64,454 11,415 75,869 1,326 299 77,494 Assets 2,748,329 1,607,312 4,355,641 153,347 426,881 300,048 5,235,917 Capital expenditures 223,963 51,798 275,761 7,051 16,252 299,064 |
The reconciliation of Capital expenditures for 2000 and 1999 represents capital expenditures of the discontinued water business. The reconciliation of segment assets at December 31, 2001, 2000, and 1999 to the consolidated total includes the following unallocated amounts:
2001 2000 1999 -------- ---------- ---------- Other property $ - $ 1,998 $ 2,661 Cash 11,772 5,348 3,011 Current assets- other 50,862 29,852 3,103 Other regulatory assets 22,626 33,315 34,571 Net assets - discontinued operations - 261,479 256,365 Deferred charges- other 60 1,767 337 -------- ---------- ---------- $ 85,320 $ 333,759 $ 300,048 ======== ========== ========== |
Note 20. Subsequent Events
On February 6, 2002, a dividend of $975,000 ($0.4875 per share) was declared on SPPC's preferred stock. The dividend is payable on March 1, 2002, to holders of record as of February 8, 2002.
On February 6, 2002, SPR's Board of Directors declared a dividend on common stock of 20 cents per share, payable March 15, 2002, to shareholders of record at the close of business on February 22, 2002.
On February 6, 2002, NPC's Board of Directors declared a $10 million dividend on NPC's common stock, all of which is held by SPR. On February 6, 2002, SPPC's Board of Directors declared a $10 million dividend on SPPC's common stock, all of which is held by SPR. Both dividends were paid on March 15, 2002.
NOTE 21. QUARTERLY FINANCIAL DATA (UNAUDITED)
The following figures are unaudited and include all adjustments necessary in the opinion of management for a fair presentation of the results of interim periods. Dollars are presented in thousands except per share amounts.
Quarter Ended March 31, 2001 June 30, 2001 September 30, 2001 December 31, 2001 Operating Revenues $ 737,926 $ 1,155,462 $ 1,971,900 $ 723,442 ============== ============= ================== ================= Operating Income $ (30,487) $ 78,294 $ 122,190 $ 52,872 ============== ============= ================== ================= Income (loss) from continuing operations $ (83,860) $ 27,549 $ 80,409 $ 5,768 Income from discontinued operations 381 641 - - Gain on disposal of water business - 25,845 - - -------------- ------------- ------------------ ----------------- Net income (loss) $ (83,479) $ 54,035 $ 80,409 $ 5,768 ============== ============= ================== ================= Income (loss) per share-Basic: Income (loss) from continuing perations $ (1.07) $ 0.35 $ 0.89 $ 0.06 Income from discontinued operations 0.01 0.01 - - Gain on disposal of water business - 0.33 - - -------------- ------------- ------------------ ----------------- Net income (loss) $ (1.06) $ 0.69 $ 0.89 $ 0.06 ============== ============= ================== ================= Income (loss) per share-Diluted: Income (loss) from continuing operations $ (1.07) $ 0.35 $ 0.89 $ 0.06 Income from discontinued operations 0.01 0.01 - - Gain on disposal of water business - 0.33 - - -------------- ------------- ------------------ ----------------- Net income (loss) $ (1.06) $ 0.69 $ 0.89 $ 0.06 ============== ============= ================== ================= Quarter Ended March 31, 2000 June 30, 2000 September 30, 2000 December 31, 2000 Operating Revenues $ 392,649 $ 474,312 $ 868,174 $ 599,119 ============== ============= ================== ================= Operating Income $ 57,193 $ 15,144 $ 19,074 $ 35,978 ============== ============= ================== ================= Income (loss) from continuing operations $ 17,251 $ (24,021) $ (23,742) $ (18,902) Income from discontinued operations 927 3,830 4,194 683 -------------- ------------- ------------------ ----------------- Net income (loss) $ 18,178 $ (20,191) $ (19,548) $ (18,219) ============== ============= ================== ================= Income (loss) per share-Basic: Income (loss) from continuing operations $ 0.22 $ (0.31) $ (0.30) $ (0.24) Income from discontinued operations 0.01 0.05 0.05 0.01 -------------- ------------- ------------------ ----------------- Net income (loss) $ 0.23 $ (0.26) $ (0.25) $ (0.23) ============== ============= ================== ================= Income (loss) per share-Diluted: Income (loss) from continuing operations $ 0.22 $ (0.31) $ (0.30) $ 0.24) Income from discontinued operations 0.01 0.05 0.05 0.01 -------------- ------------- ------------------ ----------------- Net income (loss) $ 0.23 $ (0.26) $ (0.25) $ (0.23) ============== ============= ================== ================= |
NOTE 22. DERIVATIVES AND HEDGING ACTIVITIES (SPR, NPC, SPPC)
Effective January 1, 2001, SPR, SPPC, and NPC adopted Statement of Financial Accounting Standards (SFAS) No. 133, "Accounting for Derivative Instruments and Hedging Activities," as amended by SFAS No. 138, both issued by the Financial Accounting Standards Board. As amended, SFAS No. 133 requires that an entity recognize all derivatives as either assets or liabilities in the statement of financial position, measure those instruments at fair value, and recognize changes in the fair value of the derivative instruments in earnings in the period of change unless the derivative qualifies as an effective hedge.
The adoption of this standard did not have a material impact on the earnings of SPR or the Utilities. SPR and the Utilities did, however, recognize all derivatives as assets or liabilities in the condensed consolidated balance sheets upon adoption and measured those instruments at fair value. This resulted in SPR, NPC, and SPPC recording $981 million, $678 million, and $303 million of risk management assets, respectively, and $822 million, $722 million, and $97 million of risk management liabilities, respectively, at January 1, 2001.
On April 18, 2001, AB 369 was signed into law in Nevada. AB 369 reinstated
deferred energy accounting by the Utilities effective March 1, 2001. (See Note 3
- Regulatory Actions, above.) As a result, fuel and purchased power expenses,
including gains and losses on derivative instruments, are recoverable or payable
through future rates. In accordance with SFAS No. 71, "Accounting for the
Effects of Certain Types of Regulation," regulatory assets and liabilities are
established to the extent that such derivative gains and losses are recoverable
or payable through future rates. Because of this accounting treatment, the
Utilities will not apply hedge accounting to their electricity and natural gas
derivatives. However, SPR and the Utilities have adopted cash flow hedge
accounting for other derivative instruments not subject to regulatory treatment.
The transition adjustments resulting from adoption of SFAS No. 133 related to
the other derivative instruments not subject to regulatory treatment was
reported as the cumulative effect of a change in accounting principle in Other
Comprehensive Income of SPR and the Utilities.
SPR's and the Utilities' objective in using derivatives is to reduce exposure to energy price risk and interest rate risk. Energy price risks result from activities that include the generation, procurement and marketing of power and the procurement and marketing of natural gas. Derivative instruments used to manage energy price risk include forwards, options, and swaps. These contracts allow the Utilities to reduce the risks associated with volatile electricity and natural gas markets.
Derivatives used to manage interest rate risk include interest rate swaps designed to moderate exposure to interest-rate changes and lower the overall cost of borrowing. At December 31, 2001, SPR had one interest rate swap related to $200 million of SPR floating rate notes maturing April 20, 2003. This interest rate swap is considered a completely effective cash flow hedge.
At December 31, 2001, the fair value of the derivatives resulted in the recording of $347 million, $250 million and $97 million in risk management assets and $1.019 billion, $601 million and $410 million in risk management liabilities in the Consolidated Balance Sheets of SPR, NPC and SPPC, respectively. The fair values of the forward contracts and swaps are determined based on quotes obtained from independent brokers and exchanges. The fair values of options are determined using a pricing model which incorporates assumptions such as the underlying commodity's forward price curve, time to expiration, strike price, interest rates, and volatility. The use of different assumptions and variables in the model could have a significant impact on the valuation of the instruments.
Due to the regulatory environment in which the Utilities operate, regulatory assets and liabilities are established to the extent that electricity and natural gas derivative gains and losses are recoverable or payable through future rates. Accordingly, at December 31, 2001, $664 million, $351 million and $313 million in net
risk management regulatory assets were recorded in the Consolidated Balance Sheets of SPR, NPC, and SPPC, respectively. In addition, for the twelve months ended December 31, 2001, the unrealized gains and losses resulting from the change in the fair value of derivatives designated and qualifying as cash flow hedges for SPR, NPC, and SPPC were recorded in Other Comprehensive Income. Such amounts will be reclassified into earnings when the related transactions are settled or terminate. No amounts were reclassified into earnings during the twelve months ended December 31, 2001.
Management has evaluated the impact of Derivatives Implementation Group Issues C10 and C15 with respect to option contracts and optionality features. In Management's opinion, the implementation of these interpretations will not result in any changes to the initial application of SFAS No. 133 nor have a significant impact on the financial position or results of operations of SPR or the Utilities.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
PART III
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
(a) Directors
The following is a listing of all the current directors of SPR, NPC and SPPC, and their ages as of December 31, 2001. There are no family relationships among them. Directors serve three-year terms with three (or four) terms of office expiring at each Annual Meeting, or until their successors have been elected and qualified.
Directors whose terms expire in 2002:
Krestine M. Corbin, 64
President and Chief Executive Officer of Sierra Machinery, Incorporated since 1984 and a director of that company since 1980. She also serves on the Federal Reserve Board of San Francisco Board of Directors. Ms. Corbin has served as a Director of SPR since 1989, of SPPC since 1992, and was elected a Director of NPC in July 1999.
Fred D. Gibson, Jr., 73
Retired Chairman, President and Chief Executive Officer, but remains as a director, of American Pacific Corporation, a manufacturer of chemicals and pollution abatement equipment and a real estate developer. Mr. Gibson has been affiliated with American Pacific Corporation and its predecessor, Pacific Engineering & Production Co., since 1956. He is also a director of Cashman Equipment Company. Mr. Gibson has served as a Director of NPC since 1978, and was elected a Director of SPR and SPPC in July 1999.
James L. Murphy, 71
Certified Public Accountant and retired partner of and consultant to Grant Thornton L.L.P., an international accounting and management consulting firm. Mr. Murphy is the owner, independent trustee, and general partner of several real estate development projects and numerous rental properties. He is also a retired colonel in the United States Air Force Reserve. Mr. Murphy has served as a Director of SPPC since 1990, of SPR since 1992, and was elected a Director of NPC in July 1999.
Clyde T. Turner, 64
Chairman and CEO of Turner Investments, Ltd., a general-purpose investment company, and several special-purpose real estate development companies known as Spectrum Companies in Las Vegas, Nevada. He is also a director of St. Rose Dominican Hospital and CapCure, and a member of the Environmental Advisory Committee to the Board of County Commissions, Clark County, Nevada. Mr. Turner is the retired Chairman and Chief Executive Officer of Mandalay Bay. He was elected a Director of SPR in November 2001.
Dennis E. Wheeler, 59
Chairman, President and Chief Executive Officer of Coeur d'Alene Mines Corporation since 1986. Mr. Wheeler has served as a Director of SPR since 1990, of SPPC since 1992, and was elected a Director of NPC in July 1999.
Directors whose terms expire in 2003:
Edward P. Bliss, 69
Consultant to Zurich Scudder Investments Co; retired partner, Loomis, Sayles & Company, Inc., an investment counsel firm in Boston, Massachusetts. He is also a Director of Seaboard Petroleum, Midland, Texas. Mr. Bliss has served as a Director of SPR since 1991, of SPPC since 1992, and was elected a Director of NPC in July 1999.
Mary Lee Coleman, 64
President of Coleman Enterprises, a developer of shopping centers and industrial parks. She is also a director of First Dental Health. Ms. Coleman has served as a Director of NPC since 1980, and was elected a Director of SPR and SPPC in July 1999.
Theodore J. Day, 52
Senior Partner, Hale, Day, Gallagher Company, a real estate brokerage and investment firm. Mr. Day has served as a Director of SPPC since 1986, of SPR since 1987, and was elected a Director of NPC in July 1999. He is also a Director of the W.M. Keck Foundation.
Jerry E. Herbst, 63
Chief Executive Officer of Terrible Herbst, Inc., a gas station, car wash, convenience store chain; and Herbst Supply Co., Inc., a wholesale fuel distributor; family-owned businesses for which he has worked since 1959. He is also a partner of the Coast Resorts (hotel and casino industry). Mr. Herbst has served as a Director of NPC since 1990, and was elected a Director of SPR and SPPC in July 1999.
Directors whose terms expire in 2004:
James R. Donnelley, 66
Partner, Stet & Query, Ltd., since June 2000. Retired, R.R. Donnelly & Sons Company since June 2000, Vice Chairman of the Board, R.R. Donnelley & Sons Company from July 1990 to June 2000, and a Director of that company since 1976. Mr. Donnelley was R.R. Donnelley and Sons' Group President, Corporate Development from June 1987 to July 1990, and Group President, Financial Printing Services Group from January 1985 to January 1988. He is also a Director of Pacific Magazines & Printing Limited, and Chairman of National Merit Scholarship Corporation. Mr. Donnelley has served as a Director of SPR since 1987, of SPPC since 1992, and was elected a Director of NPC in July 1999.
Walter M. Higgins, 57
Chairman, President and Chief Executive Officer of SPR since August 8, 2000. Chairman, President and Chief Executive Officer of AGL Resources, Inc., from February 1998 to August 2000. Chairman, President and Chief Executive Officer of SPR from January 4, 1994 to January 14, 1998. President and
Chief Operating Officer of Louisville Gas and Electric Company from 1991 to November 1993. He is also a director of Aegis Insurance Services, Inc. NEETF, American Gas Association, and Infrastrux.
John F. O'Reilly, 56
Chairman and Chief Executive Officer of the law firm of Mangels, Butler, Marmaro & O'Reilly. He was formerly with the law firm of Keefer, O'Reilly, and Ferrario. Mr. O'Reilly is also Chairman and Chief Executive Officer of the O'Reilly Gaming Group and is on the Board of Trustees of Loyola Marymount University. Mr. O'Reilly has served as a Director of NPC since 1995, and was elected a Director of SPR and SPPC in July 1999.
Messrs. Higgins and Murphy are Directors of Lands of Sierra, Inc.; Messrs. Day and Higgins are Directors of Tuscarora Gas Pipeline Company; Mr. Higgins is a Director of Sierra Pacific Communications, Sierra Water Development Company, Sierra Gas Holdings Company, Pinon Pine Corporation, Pinon Pine Investment Company, and GPSF-B. The Directors of e.three are Walter M. Higgins and Richard J. Coyle. All of the above listed companies are subsidiaries of Sierra Pacific Resources, with the exception of Pinon Pine Corporation, Pinon Pine Investment Company, and GPSF-B, which are subsidiaries of Sierra Pacific Power Company.
(b) Executive Officers
The following are current executive officers of the companies indicated and their ages as of December 31, 2001. There are no family relationships among them. Officers serve a term which extends to and expires at the annual meeting of the Board of Directors or until a successor has been elected and qualified:
Walter M. Higgins, 57, Chairman, President and Chief Executive Officer, Sierra Pacific Resources
See above description under Item 10(a), "Directors."
William E. Peterson, 54, Senior Vice President, General Counsel and Corporate Secretary, Sierra Pacific Resources
Mr. Peterson was elected to his present position in January 1994, and holds the same positions with SPPC and NPC. He was previously Senior Vice President, Corporate Counsel for SPPC from July 1993 to January 1994. Prior to joining SPR in 1993, he served as General Counsel and Resident Agent for SPR since 1992, while a partner in the Woodburn and Wedge law firm. He was a partner in the Woodburn and Wedge law firm since 1982.
Mark A. Ruelle, 40, President, Nevada Power Company
Mr. Ruelle was elected to his present position in May 2001. He was formerly Senior Vice President and Chief Financial Officer for SPR since December 2000, and held the same positions with SPPC and NPC. Prior to joining SPR, Mr. Ruelle was President of Westar Energy, a subsidiary of Western Resources in 1996, and before that, served as Vice President, Corporate Development for Western Resources in 1995. Mr. Ruelle was with Western Resources since 1987 and served in numerous positions in regulatory affairs, treasury, finance, corporate development, and strategy planning.
Jeffrey L. Ceccarelli, 46, President, Sierra Pacific Power Company
Mr. Ceccarelli was elected to his present position in June 2000. He previously held the position of Vice President, Distribution Services, New Business, in July 1999 for SPPC and NPC. He was elected Vice President, Distribution Services for SPPC in February 1998. Prior to this, he served as Executive Director, Distribution Services. From January 1996 through January 1998, Mr. Ceccarelli was Director, Customer Operations. A civil engineer, Mr. Ceccarelli has been with SPPC since 1972.
Dennis D. Schiffel, 58, Senior Vice President and Chief Financial Officer, Sierra Pacific Resources
Mr. Schiffel was elected to his current position in July 2001. Previously, he was vice President, Corporate Planning, for ARCO. He held various positions there, including investor relations, finance, planning and treasury at ARCO's parent company or operating units overseas.
Matt H. Davis, 45, Vice President, Transmission Services, Nevada Power Company
Mr. Davis was elected to his present position in November 2001. He was formerly Vice President, Distribution Services for NPC. In the spring of 2000, he held a similar position forth both NPC and SPPC since July 1999. Previously he was Director, System Planning, and Division Director, System Planning and Operations for NPC. Mr. Davis has been with NPC since 1978.
Steven C. Oldham, 51, Senior Vice President, Energy Supply, Sierra Pacific Power Company and Nevada Power Company
Mr. Oldham was elected to his current position in August 2001. Previously, he was Senior Vice President, Corporate Development and Strategic Planning. Previous to that, he was Vice President, Transmission Business Group and Strategic Development; Vice President, Information Resources, Corporate Redesign and Merger Transaction; Vice President, Regulation and Treasurer; and Treasurer and Director of Finance. Mr. Oldham has been with SPPC since 1976.
Victor H. Pena, 53, Senior Vice President and Chief Administrative Officer, Sierra Pacific Power Company and Nevada Power Company
Mr. Pena was elected to his current position in May 2001. From 1998 to his appointment at SPPC and NPC, he held various executive positions at AGL Resources, Inc., in Atlanta, Georgia, including Vice President, Business Development, and Vice President, Financial Systems and Controller.
Mary O. Simmons, 46, Vice President, Rates and Regulatory Affairs, Sierra Pacific Power Company and Nevada Power Company
Ms. Simmons was elected to her current position in May 2001. Previously she held the position of Controller for SPR since July 1999, and held the same position with SPPC and NPC. Her previous positions include: Director, Water Policy and Planning; Director, Budgets and Financial Services; and Assistant Treasurer, Shareholder Relations for SPR. Ms. Simmons is a certified public accountant and has been with SPR since 1985.
Douglas R. Ponn, 54, Vice President, Public Policy, Sierra Pacific Power Company and Nevada Power Company
Mr. Ponn was elected to his present position in May 2001. Formerly he held the position of Vice President, Governmental and Regulatory Affairs, since July 1999 for both SPPC and NPC. Previously
he was Executive Director, Governmental and Regulatory Affairs. Mr. Ponn has been with SPR since 1986.
Mary Jane Reed, 55, Vice President, Human Resources, Sierra Pacific Power Company and Nevada Power Company
Ms. Reed was elected Vice President, Human Resources of SPPC in January 1997, and was named to the same position with NPC in July 1999. She was previously Vice President, Human Resources, Network Group for Bell Atlantic Corporation. Ms. Reed was with Bell Atlantic from 1968 - 1996 and, in addition to the Vice President's position, served as Director of Human Resources, Assistant to the President for Consumer Affairs, and several other managerial positions.
Richard K. Atkinson, 50, Treasurer and Investor Relations Officer, Sierra Pacific Resources
Mr. Atkinson was elected to his current position in May 2001 and holds the same position with SPPC and NPC. He was formerly Treasurer of SPR, SPPC, and NPC in December 2000. Previously he held the positions of Assistant Treasurer, Executive Director, Finance, and other positions in the Finance Department. Mr. Atkinson has been with SPPC since 1980.
Michael R. Smart, 45, Vice President, Resource Management, Sierra Pacific Power Company and Nevada Power Company
Mr. Smart was appointed to his present position in May 2001. He was formerly Acting Vice President, Resource Management, since October 2000. Previously he was Executive Director, Resource Management for SPPC and NPC effective August 1999. Prior to this, from February 1998, he served as Director, Electric Operations for SPPC. From August 1996 to February 1998, he was Director of Energy Sales. A registered electrical engineer in Nevada and California, Mr. Smart has been with SPPC since 1979 and has held numerous management positions in operations, engineering, and planning.
Paul Heagen, 49, Vice President, Marketing and Corporate Communications, Sierra Pacific Power Company and Nevada Power Company
Mr. Heagen was appointed to his present position in 2001. He has held various positions at GTE Corporation in all areas of utility communications, marketing, public policy, crisis management, corporate branding, and communications strategy.
Carol Marin, 50, Vice President, Customer Service, Sierra Pacific Power Company and Nevada Power Company
Ms. Marin was elected to her present position in May 2001. Previously she held the position of Director, Customer Information Systems Project for both companies from August 1999-May 2001. From 1977 until 1999, Ms. Marin served in a variety of management positions for SPPC in customer service, major accounts, and operations analysis. Ms. Marin has been with SPPC for 25 years.
Susan Brennan, 42, Vice President, Information Services, Sierra Pacific Power Company and Nevada Power Company.
Ms. Brennan was elected to her present position in May 2001. Previously she held the position of Executive Director, Customer Service, from august 1999 to May 2001. From 1992 to 1999, Ms. Brennan served in various financial and industry restructuring positions. Ms. Brennan has been with NPC 10 years.
John Brown, 51, Controller, Sierra Pacific Resources
Mr. Brown was elected to his present position in May 2001 and holds the same position at SPPC and NPC. Previously he held the position of Director, Corporate and Tax Accounting. Mr. Brown has held a variety of positions in SPR, including Compliance Officer, Director, Shareholder Relations, and Director, Internal Audit. Mr. Brown has been with SPR 21 years.
Although all outstanding shares of SPPC's common stock are held by SPR and it is SPR's common stock which is traded on the New York Stock Exchange, SPPC has one series of non-voting preferred stock outstanding and registered under the Securities Exchange Act of 1934 ("the Act"). As a technical matter, SPPC is thus deemed an "issuer" for purposes of the Act whose officers are required to make filings with respect to beneficial ownership, if any, of those non-voting preferred securities. SPPC's officers, all of whom are currently reporting pursuant to Section 16(a) of the Act with respect to SPR's common stock, have filed reports with respect to SPPC's preferred stock, which reports show no past or current beneficial ownership of such preferred stock.
ITEM 11. EXECUTIVE COMPENSATION
SUMMARY COMPENSATION TABLE
The following table sets forth information about the compensation of the Chief Executive Officer that served in that position during 2001, and each of the four most highly compensated officers for services in all capacities to SPR and its subsidiaries. Also included is an individual who, although not an officer at the end of 2001, warranted inclusion due to compensation levels.
------------------------------------------------------------------------------------------------------------------------------------ Annual Compensation Long-Term Compensations --------------------------------------------------------------------------------------------------- Awards Payout ---------------------------------------------------------- Securities Underlying All Other Name and Principal Other Annual Restricted Stock Options/SARs LTIP Payouts Compensations Position Year Salary ($) Bonus ($) Compensation ($) Awards ($) (#) ($) ($) (a) (b) (c) (d)(2) (e)(3) (f)(4) (g)(5) (h)(6) (i)(7) ------------------------------------------------------------------------------------------------------- ---------------------------- Walter M Higgings 2001 $ 590,000 $ - $ 70,970 $ - 110,130 $ - $ 614,129 Chairman of the Board, 2000 $ 215,151 $ - $ 33,690 $ 256,000 400,000 $ - $ 411,758 President, and Chief Executive Officer Mark A. Ruelle 2001 $ 280,962 $ - $ 28,108 $ 62,080 66,520 $ - $ 109,437 President Nevada Power 2000 $ 250,255 $ - $ 15,967 $ - - $ 59,357 $ 19,160 Company 1999 $ 196,654 $ 86,658 $ 7,389 $ - 61,292 $ - $ 8,565 Steven W. Rigazio/1/ 2001 $ 255,000 $ - $ 843 $ - 26,520 $ - $ 573,177 President, Nevada Power 2000 $ 255,003 $ - $ 15,477 $ - - $ 26,713 $ 201,227 Company 1999 $ 262,075 $ 81,700 $ 60,654 $ - 36,260 $ 27,712 $ 6,811 William E. Peterson 2001 $ 231,538 $ - $ 31,606 $ - 22,880 $ - $ 20,456 Senior Vice President 2000 $ 216,203 $ - $ 25,943 $ - - $ 59,357 $ 20,926 General Counsel and 1999 $ 200,000 $ 83,053 $ 20,727 $ - 80,168 $ - $ 11,974 Corporate Secretary Jeffrey L. Cecarelli 2001 $ 221,539 $ - $ 13,712 $ - 22,510 $ - $ 19,429 President, Sierra Pacific 2000 $ 191,539 $ - $ 19,320 $ - - $ 36,527 $ 16,781 Power Company 1999 $ 148,077 $ 26,840 $ 8,321 $ - 26,140 $ - $ 1,484 Steven C. Oldham 2001 $ 219,039 $ - $ - $ - 20,800 $ - $ 19,775 Senior Vice President, 2000 $ 186,584 $ - $ 13,750 $ - - $ 36,527 $ 19,678 Energy Supply 1999 $ 151,058 $ 26,840 $ 8,859 $ - 41,286 $ - $ 7,970 ------------------------------------------------------------------------------------------------------------------------------------ |
1. Mr. Rigazio was President of Nevada Power Company until the appointment of
Mr. Ruelle to that position in May 2001.
2. The amounts presented for 1999 represent incentive pay received pursuant to
SPR's "pay for performance" team incentive plan approved by stockholders in
May, 1994. All of the amounts are reported in the year they were earned,
although payment may have occurred in a subsequent reporting period. The
Board of Directors elected not to grant payment of the 2000 and 2001
incentive pay to the executives.
3. For all of the executives listed these amounts represent Personal Time Off
payouts.
4. As the result of a promotion, Mr. Ruelle was awarded a restricted stock
grant of 4,000 shares with dividend equivalents. At December 31, 2001, the
value of the grant was $60,200 at $15.05 per share. The grant will vest
over a four year period at 25% per year.
In 2000, Mr. Higgins was awarded a restricted stock grant of 16,000 shares
with dividend equivalents. At December 31, 2001, the value of the grant was
$240,800 at $15.05 per share. The grant will vest over a four year period
in the following manner:
September 2002 4,000 shares September 2003 4,000 shares September 2004 8,000 shares |
5. As a result of the August 1, 1999 merger with Nevada Power Company, all SPR nonqualifying stock options outstanding as of that date were converted at a ratio of 1.44:1. For the pre-merger SPR executives, the 1999 option amounts include the number of new shares issued during the year, as well as the total number of shares that were converted for that employee. The 2000 Non-Qualified Stock Options were granted in August of 1999 and are therefore included in the 1999 amounts.
6. The Long-term incentive payouts for the SPR executives, for the three-year periods ended December 31, 1999 and December 31, 2001, were not approved for payment by the SPR Board of Directors; therefore, for these payouts, zero amounts are shown in 1999 for the pre-merger SPR executives, and in 2001 for all executives. In 1999, Nevada Power executives received a lump sum payout of all their performance shares as a result of the August 1, 1999 merger.
7. Amounts for All Other Compensation include the following for 2001:
------------------------------------------------------------------------------------------------------------------- Walter M. Mark A. Steven W. William E. Jeffrey L. Steven C. Description Higgins Ruelle Rigazio Peterson Ceccarelli Oldham ------------------------------------------------------------------------------------------------------------------- Company contributions to the 401k $ 10,200 $ 9,600 $ 10,200 $ 8,400 $ 10,200 $ 10,200 deferred compensation plan Company paid portion of $ 7,752 $ 7,180 $ 7,752 $ 7,752 $ 7,752 $ 7,752 Medical/Dental/Vision Benefits Company contributions to the $ 646 $ 1,935 nonqualified deferred compensation plan Imputed income on group term life $ 3,612 $ 400 $ 600 $ 773 $ 477 $ 690 insurance premiums paid by SPR Insurance premiums paid for executive $ 7,746 $ 563 $ 1,596 $ 1,000 $ 1,133 term life policies Moving Expense Reimbursement (includes $ 418,211 $ 91,048 closing costs on sale of home) Additional Compensation upon Rehire $ 72,865 Taxable Interest on Refund of $ 24,935 Non-Qualified Pension Contribution Housing Allowance $ 64,122 Spouse Travel Expense Reimbursement $ 4,686 Severance/Stay Agreement payments $ 554,625 Total $ 614,129 $ 109,437 $ 573,177 $ 20,456 $ 19,429 $ 19,775 ------------------------------------------------------------------------------------------------------------------- |
Options/SAR Grants in Last Fiscal Year
The following table shows all grants of options to the named executive officers of SPR in 2001. Pursuant to Securities and Exchange Commission (SEC) rules, the table also shows the present value of the grant at the date of grant.
-------------------------------------------------------------------------------------------------------------- Number of Percent of Total Securities Options/SAR's Underlying Granted to Exercise of Options/SAR's Employees in Base Price Grant Date Name Granted Fiscal Year ($/share) Expiration Date Present Value (a) (b) (1) (c) (2) (d) (e) (f)(3) -------------------------------------------------------------------------------------------------------------- Walter M. Higgins 01/01/2001 Grant date 110,130 26.57% $14.80 01/01/2011 $365,632 Mark A. Ruelle 01/01/2001 Grant date 26,520 6.40% $14.80 01/01/2011 $ 88,046 05/22/2001 Grant date 40,000 9.65% $15.52 05/22/2011 $156,000 Steven W. Rigazio 01/01/2001 Grant date 26,520 6.40% $14.80 01/01/2011 $ 88,046 William E. Peterson 01/01/2001 Grant date 22,880 5.52% $14.80 01/01/2011 $ 75,962 Jeffrey L. Ceccarelli 01/01/2001 Grant date 22,510 5.43% $14.80 01/01/2011 $ 74,733 Steven C. Oldham 01/01/2001 Grant date 20,800 5.02% $14.80 01/01/2011 $ 69,056 -------------------------------------------------------------------------------------------------------------- |
1. Under the SPR executive long-term incentive plan, the 2001 grants of nonqualifying stock options were made on January 1, 2001. One-third of these grants vest annually commencing one year after the date of the grant. An additional grant of 40,000 shares of nonqualifying stock options was made to Mr. Ruelle as the result of a promotion. This grant vests at a rate of one-quarter per year for four years beginning one year after the grant date of May 22, 2001.
2. The total number of nonqualifying stock options granted to all employees in 2001 was 414,530.
3. The hypothetical grant-date present values are calculated under the Black-Scholes Model. The Black-Scholes Model is a mathematical formula used to value options traded on stock exchanges. The assumptions used in determining the option grant date present values listed above include the stock's average expected volatility (32.31%), average risk free rate of return (5.32%), average projected dividend yield (4.99%), the stock option term (10 years), and an adjustment for risk of forfeiture during the vesting period (4 years at 3%). No adjustment was made for non-transferability.
Aggregated Option/SAR Exercises in Last Fiscal Year and Fiscal Year-End Option/SAR Values
The following table provides information as to the value of the options held by the named executive officers at year end measured in terms of the closing price of Sierra Pacific Resources common stock on December 31, 2001.
------------------------------------------------------------------------------------------------------------------- Shares Number of Securities Underlying Value of Unexercised in-the- Acquired on Value Unexercised Options/SARs at money Options/SARs at Name Exercise Realized Fiscal Year-End Fiscal Year-End (a) (b) (c) (d) (e) --------------------------------------------------------------- Exercisable Unexercisable Exercisable Unexercisable ------------------------------------------------------------------------------------------------------------------- Walter M. Higgins - - - 510,130 $ - $ 27,533 Mark A. Ruelle - - 41,439 86,374 $ - $ 6,630 Steven W. Rigazio - - 16,406 46,374 $ - $ 6,630 William E. Peterson - - 60,317 42,734 $ 16,768 $ 5,720 Jeffrey L. Ceccarelli - - 16,633 32,017 $ - $ 5,628 Steven C. Oldham - - 31,780 30,307 $ 8,028 $ 5,200 ------------------------------------------------------------------------------------------------------------------- |
(e) Pre-tax gain. Value of in-the-money options based on December 31, 2001 closing trading price of $15.05 less the option exercise price.
Long-Term Incentive Plans-Awards in Last Five Years
The executive long-term incentive plan (LTIP) provides for the granting of stock options (both nonqualified and qualified), stock appreciation rights (SARs), restricted stock performance units, performance shares and bonus stock to participating employees as an incentive for outstanding performance. Incentive compensation is based on the achievement of pre-established financial goals for SPR. Goals are established for total shareholder return (TSR) compared against the Dow Jones Utility Index and annual growth in earnings per share (EPS).
The following table provides information as to the performance shares granted to the named executive officers of Sierra Pacific Resources in 2001. Nonqualifying stock options granted to the named executives as part of the LTIP are shown in the table "Option/SAR Grants in Last Fiscal Year."
--------------------------------------------------------------------------------------------------------- Performance or Estimated Future Payouts Under Non-Stock Number of Other Period Price-Based Plans ------------------------------------------------ Shares, Units Until or Other Maturation or Name Rights Payout Threshold ($) Target ($) Maximum ($) (a) (b) (c) (d)(1) (e)(2) (f)(3) --------------------------------------------------------------------------------------------------------- Walter M. Higgins 20,650 3 years $ 152,810 $ 305,620 $ 534,835 Mark A. Ruelle 4,970 3 years $ 36,778 $ 73,556 $ 128,723 Steven W. Rigazio 4,970 3 years $ 36,778 $ 73,556 $ 128,723 William E. Peterson 4,290 3 years $ 31,746 $ 63,492 $ 111,111 Jeffrey L. Ceccarelli 4,220 3 years $ 31,228 $ 62,456 $ 109,298 Steven C. Oldham 3,900 3 years $ 28,860 $ 57,720 $ 101,010 --------------------------------------------------------------------------------------------------------- |
1. The threshold represents the level of TSR and EPS achieved during the cycle
which represents minimum acceptable performance and which, if attained, results
in payment of 50% of the target award. Performance below the minimum acceptable
level results in no award earned.
2. The target represents the level of TSR and EPS achieved during the cycle
which indicates outstanding performance and which, if attained, results in
payment of 100% of the target award.
3. The maximum represents the maximum payout possible under the plan and a level
of TSR and EPS indicative of exceptional performance which, if attained, results
in a payment of 175% of the target award.
All levels of awards are made with reference to the price of each performance share at the time of the grant.
Pension Plans
The following table shows annual benefits payable on retirement at normal retirement age 65 to elected officers under SPR's qualified and non-qualified defined benefit plans based on various levels of remuneration and years of service which may exist at the time of retirement. The amounts below are based upon a maximum benefit of 60% of final average earnings used under the Supplemental Executive Retirement Plan. This maximum is reduced to 50% for any Officer who became a participant after November 1, 1999.
--------------------------------------------------------------------------------------- Annual Benefits for Years of Service Indicated --------------------------------------------------------------------- Highest Average Five-Years 15 Years 20 Years 25 Years 30 Years 35 Years Remuneration --------------------------------------------------------------------------------------- $ 60,000 $ 27,000 $ 31,500 $ 36,000 $ 36,000 $ 36,000 $120,000 $ 54,000 $ 63,000 $ 72,000 $ 72,000 $ 72,000 $180,000 $ 81,000 $ 94,500 $108,000 $108,000 $108,000 $240,000 $108,000 $126,000 $144,000 $144,000 $144,000 $300,000 $135,000 $157,500 $180,000 $180,000 $180,000 $360,000 $162,000 $189,000 $216,000 $216,000 $216,000 $420,000 $189,000 $220,500 $252,000 $252,000 $252,000 $480,000 $216,000 $252,000 $288,000 $288,000 $288,000 $540,000 $243,000 $283,500 $324,000 $324,000 $324,000 $600,000 $270,000 $315,000 $360,000 $360,000 $360,000 $660,000 $297,000 $346,500 $396,000 $396,000 $396,000 $720,000 $324,000 $378,000 $432,000 $432,000 $432,000 --------------------------------------------------------------------------------------- |
SPR's noncontributory qualified retirement plan provides retirement benefits to eligible employees upon retirement at a specified age. Annual benefits payable are determined by a formula based on years of service and final average earnings consisting of base salary and incentive compensation. Remuneration for the named executives is the amount shown in columns (c) and (d) of the Summary Compensation Table. Pension costs of the retirement plan, to which SPR contributes 100% of the funding, are not and cannot be readily allocated to individual employees and are not subject to Social Security or other offsets.
The years of credited service under the qualified retirement plan for the named executives are as follows: Mr. Higgins 5.5, Mr. Ruelle 4.7, Mr. Rigazio 17.4, Mr. Peterson 8.4, Mr. Ceccarelli 27.3, and Mr. Oldham 25.2.
A supplemental executive retirement plan (SERP) and a restoration plan are also offered to the named executive officers. The SERP is intended to ensure the payment of a competitive level of retirement income to attract, retain and motivate selected executives. The Restoration Plan is intended to provide benefits to executive officers whose benefits cannot be paid under the qualified plan because of salary deferrals to the Non-Qualified Deferred Compensation Plan, IRS limitations on compensation that can be recognized by a qualified plan, and IRS limitations on benefits payable from a qualified plan.
The years of credited service under the non-qualified SERP are as follows: Mr. Higgins 8.1, Mr. Ruelle 4.7, Mr. Rigazio 17.4, Mr. Peterson 16.4, Mr. Ceccarelli 27.3, and Mr. Oldham 25.2.
Severance Arrangements
Individual severance allowance plans exist for the named executive officers which provide for severance pay, payable in a lump sum or by purchase of an annuity, if within three years after a change in control of SPR, there is a termination of employment by SPR related to such change in control, or a termination of employment by the employee for good reason, in each case as described in the plans. In these circumstances, officers are entitled to a severance allowance not to exceed an amount equal to 36 months of the officer's base salary and any bonus and the continuation for up to 36 months of participation in SPR's group medical and life insurance plans. Change in control is defined in the plans as, among other things, a dissolution or liquidation, a reorganization, merger or consolidation in which SPR is not the surviving corporation, the sale of all or substantially all the assets of SPR (not the sale of a work unit) or the acquisition by any person or entity of 30% or more of the voting power of SPR.
In addition, several merger-related and merger-conditioned severance arrangements have been entered into between SPR and several executives, which are described in Item 13 - Certain Relationships and Related Transactions.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Voting Stock of SPR
The following table indicates the shares owned by Franklin Advisors, and Putnam Investments, the only investors known to Sierra Pacific Resources to be owners of more than 5 percent of any class of its voting stock as of March 11, 2002.
Name and Address of Shares Beneficially Title of Class Beneficial Owner Owned Percent of Class -------------- ---------------- ----- ---------------- Common Stock Franklin Advisors 9,978,000 10.8% 777 Mariners Island Blvd. San Mateo, Ca. 94404 Common Stock Putnam Investors 5,400,000 5.3% One Post Office Square Boston, Ma. 02109 |
The table below sets forth the shares of SPR Common Stock beneficially owned by each director, nominee for director, the Chief Executive Officer, and the four other most highly compensated executive officers. No director, nominee for director or executive officer owns, nor do the directors and executive officers as a group own, in excess of one percent of the outstanding Common Stock of SPR. Unless otherwise indicated, all persons named in the table have sole voting and investment power with respect to the shares shown.
Common Shares Beneficially Percent of Total Common Name of Director Owned as of Shares Outstanding as of or Nominee March 11, 2002 March 11, 2002 ------------------------ ---------------- ------------------------------ Edward P. Bliss 29,450 Mary L. Coleman 150,634 Krestine M. Corbin 22,271 Theodore J. Day 36,130 No director or nominee James R. Donnelley 37,429 for director owns in excess Fred D. Gibson Jr. 24,095 of one percent. Jerry E. Herbst 15,479 Walter M. Higgins 49,868 James L. Murphy 34,268 John F. O'Reilly 14,985 Clyde T. Turner 0 Dennis E. Wheeler 19,994 -------------- 434,603 ============== |
Common Shares Beneficially Percent of Total Common Owned as of Shares Outstanding as of Executive Officers March 11, 2002 March 11, 2002 -------------------------------- ------------------ ---------------------------- Walter M. Higgins 49,868 Steven W. Rigazio (1) 16,406 No executive officer owns Mark A. Ruelle 47,244 In excess of one percent William E. Peterson 88,294 Jeffrey L. Ceccarelli 44,422 Steven C. Oldham 55,891 ------ 302,125 ======= All directors and executive officers as a group (a)(b)(c) 862,753 ======= |
(1) Mr. Rigazio was President of Nevada Power Company until the appointment of
Mr. Ruelle to that position in May 2001.
(a) Includes shares/units acquired through participation in the Employee Stock
Purchase Plan and/or the 401(k) plan.
(b) The number of shares beneficially owned includes: shares the Executive
Officers currently have the right to acquire pursuant to stock options
granted, and performance shares earned under the Executive Long-Term
Incentive Plan. Shares beneficially owned pursuant to stock options granted
to Messrs. Higgins, Rigazio, Peterson, Ruelle, Ceccarelli, Oldham, and
directors and executive officers as a group are 0, 16,406, 80,029, 62,366,
30,210, 44,787, and 338,409 shares, respectively.
(c) Included in the shares beneficially owned by the Directors are 100,172
shares of "phantom stock" representing the actuarial value of the
Director's vested benefits in the terminated Retirement Plan for Outside
Directors. The "phantom stock" is held in an account to be paid at the time
of the Director's departure from the Board.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Mr. Peterson, formerly a partner with the law firm of Woodburn and Wedge, became Senior Vice President and General Counsel for Sierra Pacific Resources in 1993. Woodburn and Wedge, which has performed legal services for SPPC since 1920 and for Sierra Pacific Resources and all of its subsidiaries from their inception, continues to perform legal work for SPR. Mr. Peterson's spouse, an equity partner in the firm since 1982, has performed work for SPR since 1976 and continues to do so from time to time.
Susan Oldham, a former employee of SPPC specializing in water resources law, planning and policy, accepted SPPC's voluntary severance offering in December 1995. Ms. Oldham is the spouse of Steven C. Oldham, Senior Vice President, Energy Supply, for NPC and SPPC. Ms. Oldham, a licensed attorney in Nevada and California, performed specialized legal services in the water resources area for SPR on a contract basis through June 2001.
SPR has entered into change in control severance agreements with Walter M. Higgins, Jeffrey L. Ceccarelli, Steven C. Oldham, William E. Peterson, Mark A. Ruelle, Victor H. Pena, Dennis D. Schiffel, Mary
O. Simmons, Susan Brennan, Carol Marin, Paul Heagen, Richard K. Atkinson, John Brown, Douglas R. Ponn, Michael R. Smart, Matt H. Davis, and Mary Jane Reed. These agreements provide that, upon termination of the executive's employment within 24 or 36 months following a change in control of SPR (as defined in the agreement either (a) by SPR for reasons other than cause (as defined in the agreements), (b) death or disability, or (c) by the executive for good reason as defined in the agreement, including a diminution of responsibilities, compensation, or benefits (unless, with respect to reduction in salary or benefits, such reduction is applicable to all senior executives of SPR and the acquirer)), the executive will receive certain payments and benefits. These severance payments and benefits include (i) a lump sum payment equal to two or three times the sum of the executive's base salary and target bonus, (ii) a lump sum payment equal to the present value of the benefits the executive would have received had he continued to participate in SPR's retirement plans for an additional two or three years (or, in the case of SPR's Supplemental Executive Retirement Plan only, the greater of three years or the period from the date of termination until the executive's early retirement date, as defined in such plan), and (iii) continuation of life, disability, accident and health insurance benefits for a period of 24 or 36 months immediately following termination of employment. The agreements also provide that if any compensation paid, or benefit provided, to the executive, whether or pursuant to the change in control agreements, would be subject to the federal excise tax on "excess parachute payments," payments and benefits provided pursuant to the agreement will be cut back to the largest amount that would not be subject to such excise tax, if such cutback results in a higher after-tax payment to the executive. The Board of Directors entered into these agreements in order to attract and retain excellent management and to encourage and reinforce continued attention to the executives' assigned duties without distraction under circumstances arising from the possibility of a change in control of SPR. In entering into these agreements, the Board was advised by Towers Perrin, the national compensation and benefits consulting firm described above, and Skadden, Arps, Slate, Meagher & Flom, an independent outside law firm, to insure that the agreements entered into were in line with existing industry standards, and provided benefits to management consistent with those standards. The new contracts expire on December 31, 2003, unless renewed or replaced before that time.
Walter M. Higgins
On August 4, 2000, SPR elected Walter M. Higgins as President, Chief Executive Officer and Chairman of the Board under terms and conditions of an employment offer. The terms and conditions of that agreement essentially replicate Mr. Higgins' compensation and benefits package provided by his previous employer, AGL Resources, and make him whole for benefits and compensation lost, forgone, or otherwise forfeited as a result of his accepting employment with SPR.
SPR engaged Towers Perrin to evaluate Mr. Higgins' offer prior to consummating it in order to assure that it was consistent with SPR policy to compensate its senior executives, including the Chief Executive Officer, at or near the midpoint of the competitive market for base salary and incentive compensation opportunities for executives of comparably sized companies in general industry.
The employment agreement with Mr. Higgins provides for an annual base salary of $590,000, participation in SPR's short-term incentive program, at 65% of base pay, and participation in SPR's long-term incentive program approved by shareholders at 140% of base salary. Payments are based on corporate and personal performance targets established under terms and conditions of the plan. The agreement also provides that Mr. Higgins will be paid long-term incentives in accordance with the terms of the plan approved by shareholders in 1994, which contemplates a performance share grant of 13,200 shares effective January 2001, to be earned over a three-year period under performance measurements relating to financial performance and total shareholder return. Effective January 1, 2001, he also received 104,000 non-qualified stock options, which will vest at one-third per year. As with the officer group as a whole, the strike price will be fixed at the average daily closing price of the stock on the New York Stock Exchange for the 30-day period January 1-31. In
addition, Mr. Higgins will be eligible to receive on a pro-rata basis (28 of 36 months) the 2000-2002 performance share grants, which are also earned based on targets relating to financial performance and total shareholder return. Mr. Higgins also received a one-time restricted stock grant of 16,000 shares with dividend equivalents, grossed-up for taxes, which will vest over a four-year period. Mr. Higgins is required to accumulate and maintain, over five years, two times annual compensation in SPR stock, and was also granted 400,000 non-qualified stock options at a strike price based on the closing stock price on the day he accepted employment with SPR, which will vest 25% per year or sooner if certain price threshold levels are met. Mr. Higgins is also eligible to participate in SPR's Supplemental Executive Retirement Plan and was provided credit for all previous years of service with SPR, plus all years served at AGL Resources or Louisville Gas & Electric, with benefits reduced by any qualified benefits received from that prior employment. Mr. Higgins was also provided $2,000,000 of life insurance coverage at SPR expense and is otherwise eligible to participate in all employer-sponsored health, pension, benefit, and welfare plans. In the event Mr. Higgins is terminated by SPR for any reason other than cause (as defined in the agreement), he will receive one year's base salary and annual incentive payment, subject to execution of an appropriate release and non-compete covenants. In the event of a termination resulting from a change in control, within 24 months following a change in control of SPR (as defined in the agreement either (a) by SPR for reasons other than cause (as defined in the agreement), (b) death or disability, or (c) by Mr. Higgins for good reason as defined in the agreement, including a diminution of responsibilities, compensation, or benefits (unless, with respect to reduction in salary or benefits, such reduction is applicable to all senior executives of SPR and the acquirer)), he will receive certain payments and benefits. This severance payment and benefit include (i) a lump sum payment equal to three times the sum of his base salary and target bonus, (ii) a lump sum payment equal to the present value of the benefits he would have received had he continued to participate in SPR's retirement plans for an additional three years (or, in the case of SPR's Supplemental Executive Retirement Plan only, the greater of three years or the period from the date of termination until the executive's early retirement date, as defined in such plan), and (iii) continuation of life, disability, accident and health insurance benefits for a period of 36 months immediately following termination of employment.
Under the employment agreement, SPR will pay any additional amounts sufficient to hold Mr. Higgins harmless for any excise tax that might be imposed as a result of being subject to the federal excise tax on "excess parachute payments" or similar taxes imposed by state or local law in connection with receiving any compensation or benefits that are considered contingent on a change in control.
A change in control for purposes of the Employment Agreement occurs (i) if SPR merges or consolidates, or sells all or substantially all of its assets, and less than 65% of the voting power of the surviving corporation is owned by those stockholders who were stockholders of SPR immediately prior to such merger or sale; (ii) any person acquires 20% or more of SPR's voting stock; (iii) SPR enters into an agreement or SPR or any person announces an intent to take action, the consummation of which would otherwise result in a change in control, or the Board of Directors of SPR adopts a resolution to the effect that a change in control has occurred; (iv) within a two-year period, a majority of the directors of SPR at the beginning of such period cease to be directors; or (v) the stockholders of SPR approve a complete liquidation or dissolution of SPR.
Steven W. Rigazio
On August 31, 2000, SPR entered into an employment agreement with Steven W. Rigazio, President of Nevada Power. Under the terms of the agreement, Mr. Rigazio will be paid $255,000 in annual base salary, subject to adjustment if the Board determines that an adjustment is appropriate. In addition, Mr. Rigazio is entitled to receive annual incentive and long-term compensation in accordance with the terms and conditions of existing plans as apply to the officer group as a whole. If Mr. Rigazio becomes disabled during the course of his employment, he will be entitled to receive 100% of base salary for six months, and any annual incentive pay for which he would otherwise be eligible during the year he first went on disability. At the expiration of any short-term disability, Mr. Rigazio would be eligible for long-term disability under SPR's long-term disability
plan and will continue to be covered by SPR's medical, vision and dental plans during all of such time and will continue to earn years of service under the Retirement Plan until age 65 at which time he will be required to retire. During such time, he will also receive life insurance benefits substantially similar to those he was entitled to receive before going on short-term disability or long-term disability. If Mr. Rigazio dies before age 55 (the Retirement Plan's earliest retirement date), his surviving spouse will be eligible to receive the Retirement Plan's pre-retirement death benefit at the time Mr. Rigazio would have become 55. If Mr. Rigazio dies while on short-term disability or long-term disability, his surviving spouse will be eligible for SERP benefits as if Mr. Rigazio were 62 and will be paid an annuity on the date of death, or when Mr. Rigazio would have reached age 55, whichever occurs later. In addition, SPR will continue to provide the Employee's spouse and eligible dependents all medical coverage so long as they are not covered by other plans. Mr. Rigazio died on December 27, 2001, and the payments described above were made.
David G. Barneby
On June 19, 1999, Nevada Power, a wholly owned subsidiary of SPR, entered into a retention agreement effective on the date of the merger with David G. Barneby, Vice President, Generation, which provides him with benefits which he would have been entitled to receive had he voluntarily terminated his original May 13, 1998, employment agreement with SPR. The agreement provides, in addition to base pay and any incentive pay or long-term pay accrued during the period of his employment, an additional $600,890 in cash, payable in substantially equal quarterly installments commencing on October 1, 1999, and ending on July 31, 2002. If employment is terminated during the term or if the employee dies during the term, any remaining and unpaid installments shall be paid to the employee or to his heirs. If the employee is terminated or retires, then the employee shall, in addition, receive the economic equivalent to an enhancement of his retirement allowing for payment in cash of the present value of the average early retirement benefit calculated on the basis of the greater of actual age or age 55, and an additional five years of age or years of service or a combination thereof to maximize retiree medical benefits. The employee is also entitled to 24 months of employee health and life benefits in amounts substantially equivalent to those in effect immediately prior to termination. Mr. Barneby retired on January 1, 2002.
In the event any payments or benefits or distributions thereof under the contract or any other agreements, policies, or plans of SPR would be subject to the excise tax imposed by Section 4999 of the Internal Revenue Code by reason of being considered contingent on a change of control, then the employee is entitled to receive an additional payment equal to such excise tax.
PART IV
Item 14. Exhibits, Financial Statement Schedules and Reports on Form 8-K
(a) Financial Statements, Financial Statement Schedules and Exhibits
Page ---- 1. Financial Statements: Independent Auditors' Reports.............................................. 83-84 Consolidated Balance Sheets as of December 31, 2001 and 2000 .............. 85 Consolidated Statements of Income for the Years Ended December 31, 2001, 2000 and 1999 ..................................................... 86 Consolidated Statements of Comprehensive Income for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 87 Consolidated Statements of Common Shareholders' Equity for the Years Ended December 31, 2001, 2000 and 1999 .................................. 87 Consolidated Statements of Cash Flows for the Years Ended December 31, 2001, 2000 and 1999 ................................................. 88 Consolidated Statements of Capitalization as of December 31, 2001 and 2000 ................................................................ 89-90 Balance Sheets for Nevada Power Company as of December 31, 2001 and 2000 .................................................................... 91 Statements of Income for Nevada Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 92 Statements of Cash Flows for Nevada Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................ 93 Statements of Capitalization for Nevada Power Company as of December 31, 2001 and 2000 ....................................................... 94 Consolidated Balance Sheets for Sierra Pacific Power Company as of December 31, 2001 and 2000 .............................................. 95 Consolidated Statements of Income for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 .................... 96 Consolidated Statements of Comprehensive Income for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ............ 97 Consolidated Statements of Common Shareholders' Equity for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ........................................................... 97 Consolidated Statements of Cash Flows for Sierra Pacific Power Company for the Years Ended December 31, 2001, 2000 and 1999 ............ 98 Consolidated Statements of Capitalization for Sierra Pacific Power Company as of December 31, 2001 and 2000 .......................... 99 Notes to Financial Statements ............................................. 100 2. Financial Statement Schedules: Schedule II - Consolidated Valuation and Qualifying Accounts ....... 169-170 |
All other schedules have been omitted because they are not required or are not applicable, or the required information is shown in the financial statements or notes thereto. Columns omitted from schedules have been omitted because the information is not applicable.
3. Exhibits:
Exhibits are listed in the Exhibit Index on pages 171-189.
(b) Reports on Form 8-K
Form 8-K dated November 16, 2001, filed by SPR - Item 5, Other Events
Disclosed that on November 16, 2001, SPR completed a public offering of $300,000,000 principal amount of its Premium Income Equity Securities at a price of $50 per unit with quarterly payments of an initial annual combined rate of 9%.
SIGNATURES
Pursuant to the requirements of Section 13 and 15(d) of the Securities Exchange Act of 1934, Sierra Pacific Resources, Nevada Power Company and Sierra Pacific Power Company have each duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized. The signatures for each undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.
SIERRA PACIFIC RESOURCES
NEVADA POWER COMPANY
SIERRA PACIFIC POWER COMPANY
By /S/ Walter M. Higgins -------------------------------- Walter M. Higgins Chairman, Chief Executive Officer and Director March 20, 2002 |
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of Sierra Pacific Resources, Nevada Power Company and Sierra Pacific Power Company and in the capacities indicated on the 20th day of March, 2002.
/S/ Dennis Schiffel /S/ John Brown ------------------------------------------ ------------------------------------------ Dennis Schiffel John Brown Senior Vice President, Controller Chief Financial Officer (Principal Accounting Officer) (Principal Financial Officer) /S/ Edward P. Bliss /S/ Jerry E. Herbst ------------------------------------------ ------------------------------------------ Edward P. Bliss Jerry E. Herbst Director Director /S/ Mary Lee Coleman /S/ James L. Murphy ------------------------------------------ ------------------------------------------ Mary Lee Coleman James L. Murphy Director Director /S/ Krestine M. Corbin /S/ John F. O'Reilly ------------------------------------------ ------------------------------------------ Krestine M. Corbin John F. O'Reilly Director Director /S/ Theodore J. Day /S/ Clyde T. Turner ------------------------------------------ ------------------------------------------ Theodore J. Day Clyde T. Turner Director Director /S/ James R. Donnelley /S/ Dennis E. Wheeler ------------------------------------------ ------------------------------------------ James R. Donnelley Dennis E. Wheeler Director Director /S/ Fred D. Gibson, Jr. ------------------------------------------ Fred D. Gibson, Jr. Director |
Sierra Pacific Resources Schedule II - Consolidated Valuation and Qualifying Accounts For The Years Ended December 31, 2001, 2000 and 1999
(Dollars in Thousands)
Provision for Uncollectible Accounts --------------- Balance at January 1, 1999 $ 5,890 Provision charged to income 7,882 Amounts written off, less recoveries (7,297) -------------- Balance at December 31, 1999 6,475 Balance at January 1, 2000 6,475 Provision charged to income (1) 14,879 Amounts written off, less recoveries (8,160) -------------- Balance at December 31, 2000 13,194 ============== Balance at January 1, 2001 13,194 Provision charged to income (2) 42,767 Amounts written off, less recoveries (16,626) -------------- Balance at December 31, 2001 $ 39,335 ============== |
Nevada Power Company Schedule II - Consolidated Valuation and Qualifying Accounts For The Years Ended December 31, 2001, 2000 and 1999
(Dollars in Thousands)
Provision for Uncollectible Accounts --------------- Balance at January 1, 1999 $ 2,429 Provision charged to income 5,877 Amounts written off, less recoveries (5,480) -------------- Balance at December 31, 1999 2,826 Balance at January 1, 2000 2,826 Provision charged to income (1) 13,090 Amounts written off, less recoveries (4,311) -------------- Balance at December 31, 2000 11,605 Balance at January 1, 2001 11,605 Provision charged to income (2) 32,137 Amounts written off, less recoveries (12,881) -------------- Balance at December 31, 2001 $ 30,861 ============== |
Sierra Pacific Power Company Schedule II - Consolidated Valuation and Qualifying Accounts For The Years Ended December 31, 2001, 2000 and 1999
(Dollars in Thousands)
Provision for Uncollectible Accounts ----------------- Balance at January 1, 1999 $ 3,461 Provision charged to income 2,005 Amounts written off, less recoveries (1,817) ---------- Balance at December 31, 1999 3,649 Balance at January 1, 2000 3,649 Provision charged to income (1) 1,789 Amounts written off, less recoveries (3,849) ---------- Balance at December 31, 2000 1,589 Balance at January 1, 2001 1,589 Provision charged to income (2) 10,630 Amounts written off, less recoveries (3,745) ---------- Balance at December 31, 2001 $ 8,474 ========== |
(1) Included in the provision charged to income in 2000 was $7.3 million and
$0.3 million, respectively, for NPC and SPPC as reserves against
receivables from California's Power Exchange and Independent System
Operator.
(2) In 2001, the provision charge to income included $12.6 million and $1.2
million respectively, for NPC and SPPC as reserves against receivables
from California's Power Exchange and Independent System Operator. The
provision charge also included $.1 million and $.4 million respectively,
for NPC and SPPC as reserves against receivables from Enron.
2001 FORM 10-K EXHIBIT INDEX
(a) Exhibits Index
Certain of the following exhibits with respect to SPR and its subsidiaries, Nevada Power Company, Sierra Pacific Power Company, Lands of Sierra, Inc., Sierra Energy Company, Tuscarora Gas Pipeline Company and Sierra Water Development Company, are filed herewith. Certain other of such exhibits have heretofore been filed with the Commission and are incorporated herein by reference.
(* filed herewith)
(3) Sierra Pacific Resources
. Restated Articles of Incorporation of Sierra Pacific Resources dated July 28, 1999 (filed as Exhibit 3(A) to Form 10-K for year ended December 31, 1999).
. By-laws of Sierra Pacific Resources as amended through February 25, 2000 (filed as Exhibit 3(A) to Form 10-K for year ended December 31, 2000).
Nevada Power Company
. Restated Articles of Incorporation of Nevada Power Company, dated July 28, 1999 (filed as Exhibit 3(B) to Form 10-K for year ended December 31, 1999).
. Amended and Restated By-Laws of Nevada Power Company dated July 28, 1999 (filed as Exhibit 3(C) to Form 10-K for year ended December 31, 1999).
Sierra Pacific Power Company
. Restated Articles of Incorporation of Sierra Pacific Power Company dated May 19, 1987 (filed as Exhibit (3)(A) to Form 10-K for the year ended December 31, 1993).
. Certificate of Amendments dated August 26, 1992 to Restated Articles of Incorporation of Sierra Pacific Power Company dated May 19, 1987, in connection with Sierra Pacific Power Company's preferred stock (filed as Exhibit 3.1 to Form 8-K dated August 26, 1992).
. Certificate of Designation, Preferences and Rights dated August 31, 1992 to Restated Articles of Incorporation of Sierra Pacific Power Company dated May 19, 1987, in connection with Sierra Pacific Power Company's Class A Series 1 Preferred Stock (filed as Exhibit 4.3 to Form 8-K dated August 26, 1992).
. By-laws of Sierra Pacific Power Company, as amended through November 13, 1996 (filed as Exhibit (3)(A) to Form 10-K for the year ended December 31, 1996).
. Articles of Incorporation of Pinon Pine Corp., dated December 11, 1995 (filed as Exhibit (3)(A) to Form 10-K for the year ended December 31, 1995).
. Articles of Incorporation of Pinon Pine Investment Co., dated December 11, 1995 (filed as Exhibit (3)(B) to Form 10-K for the year ended December 31, 1995).
. Agreement of Limited Liability Company of Pinon Pine Company, L.L.C., dated December 15, 1995, between Pinon Pine Corp., Pinon Pine Investment Co. and GPSF-B INC 1995 (filed as Exhibit (3)(C) to Form 10-K for the year ended December 31, 1995).
. Amended and Restated Limited Liability Company Agreement of SPPC
Funding LLC dated as of April 9, 1999, in connection with the
issuance of California rate reduction bonds (filed as Exhibit
(3)(A) to Form 10-K for the year ended December 31, 1999).
(4) Sierra Pacific Resources
. Amended and Restated Rights Agreement dated as of February 28, 2001 between Sierra Pacific Resources and Wells Fargo Bank Minnesota, N.A. as successor Rights Agent (filed as Exhibit 4.1 to Registration Statement on Form S-3 filed July 2, 2001, File No. 333-64438).
. Purchase and Contract Agreement dated November 16, 2001, between Sierra Pacific Resources and The Bank of New York, relating to the Company's Premium Income Equity Securities (PIES) (filed as Exhibit 4.3 to Form 8-K dated November 16, 2001).
. Corporate PIES Certificate (filed as Exhibit 4.4 to Form 8-K dated November 16, 2001).
. Treasury PIES Certificate (filed as Exhibit 4.5 to Form 8-K dated November 16, 2001).
. Pledge Agreement dated November 16, 2001, among Sierra Pacific Resources, Wells Fargo Bank Minnesota, N.A. and The Bank of New York (filed as Exhibit 4.6 to Form 8-K dated November 16, 2001).
. Remarketing Agreement dated November 16, 2001, between Sierra Pacific Resources and Lehman Brothers, Inc. (filed as Exhibit 4.7 to Form 8-K dated November 16, 2001).
. Indenture between Sierra Pacific Resources and The Bank of New York, dated as of May 1, 2000 for the issuance of debt securities (filed as Exhibit 4.1 to Form 8-K dated May 22, 2000).
. Global 8-3/4% Note due 2005 (filed as Exhibit 4.2 to Form 8-K dated May 22, 2000).
. Officers' Certificate establishing the terms of the 8-3/4% Notes due 2005 (filed as Exhibit 4.3 to Form 8-K dated May 22, 2000).
. 7.93% Senior Note due 2007 issued in connection with Sierra Pacific Resources PIES (filed as Exhibit 4.2 to Form 8-K dated November 16, 2001).
. Officers' Certificate establishing the terms of the 7.93% Senior Notes due 2007 (filed as Exhibit 4.3 to Form 8-K dated November 16, 2001).
. Fiscal and Paying Agency Agreement dated as of April 17, 2000 between Sierra Pacific Resources and Bankers Trust Company, relating to the Company's money market note program (filed as Exhibit 4(A) to Form 10-K for the year ended December 31, 2000).
. Form of Global Floating Rate Note due April 20, 2002 in connection with the Company's money market note program (filed as Exhibit 4(B) to Form 10-K for year ended December 31, 2000).
. Form of Global Floating Rate Note due April 20, 2003 in connection with the Company's money market note program (filed as Exhibit 4(C) to Form 10-K for year ended December 31, 2000).
Nevada Power Company
. General and Refunding Mortgage Indenture, dated as of May 1, 2001, between Nevada Power Company and The Bank of New York, as Trustee (filed as Exhibit 4.1(a) to Form 10-Q for the quarter ended June 30, 2001).
. First Supplemental Indenture, dated as of May 1, 2001, establishing Nevada Power Company's 8.25% General and Refunding Mortgage Bonds, Series A, due June 1, 2011 (filed as Exhibit 4.1(b) to Form 10-Q for the quarter ended June 30, 2001).
. Officer's Certificate establishing the terms of Nevada Power Company's 8.25% General and Refunding Mortgage Bonds, Series A, due June 1, 2011 (filed as Exhibit 4.1(c) to Form 10-Q for the quarter ended June 30, 2001).
. Form of Nevada Power Company's 8.25% General and Refunding Mortgage Bonds, Series A, due June 1, 2011 (filed as Exhibit 4.1(d) to Form 10-Q for the quarter ended June 30, 2001).
. *(A) Second Supplemental Indenture, dated as of October 1, 2001, establishing Nevada Power Company's General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003.
. *(B) Officer's Certificate establishing the terms of Nevada Power Company's General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003.
. *(C) Form of Nevada Power Company's General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003.
. Fiscal and Paying Agency Agreement, dated as of September 19, 2001, between Nevada Power Company and Bankers Trust Company, relating to the issuance and sale of Nevada Power Company's 6% Notes due 2003 (filed as Exhibit 4.1 to Form 10-Q for the quarter ended September 30, 2001).
. Form of Global Note due September 15, 2003, in connection with the issuance and sale of Nevada Power Company's 6% Notes due 2003 (filed as Exhibit 4.2 to Form 10-Q for the quarter ended September 30, 2001).
. Junior Subordinated Indenture between Nevada Power and IBJ Schroder Bank & Trust Company, as Debenture Trustee dated March 1, 1997 (filed as Exhibit 4.01 to Form S-3, File No. 333-21091).
. Trust Agreement of NVP Capital I dated March 1, 1997 (filed as Exhibit 4.03 to Form S-3, File No. 333-21091).
. Form of Amended and Restated Trust Agreement dated March 1, 1997 (filed as Exhibit 4.10 to Form S-3, File No. 333-21091).
. Form of Agreement as to Expenses and Liabilities between Nevada Power and NVP Capital I dated March 1, 1997 (filed as Exhibit 4.14 to Form S-3, File No. 333-21091).
. Form of Preferred Security Certificate for NVP Capital I and NVP Capital II dated March 1, 1997 (filed as Exhibit 4.11 to Form S-3, FileNo. 333-21091).
. Form of Guarantee Agreement dated March 1, 1997 (filed as Exhibit 4.12 to Form S-3, File No. 333-21091).
. Form of Supplemental Indenture between Nevada Power and IBJ Schroder Bank & Trust Company, as Debenture Trustee dated March 1, 1997 (filed as Exhibit 4.13 to Form S-3, File No. 333-21091).
. Supplemental Indenture No. 2 and Assumption Agreement, dated as of June 1, 1999, between Nevada Power Company and IBJ Whitehall Bank & Trust Company, supplementing and assuming the Junior Subordinated Indenture dated as of March 1, 1997 between Nevada Power Company and IBJ Whitehall Bank & Trust Company (filed as Exhibit 4(D) to Form 10-K for year ended December 31, 1999).
. Form of Indenture between Nevada Power and IBJ Schroder Bank & Trust Company, as Trustee dated October 1, 1998 (filed as Exhibit 4.1 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Certificate of Trust of NVP Capital III dated October 1, 1998 (filed as Exhibit 4.2 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Trust Agreement for NVP Capital III dated October 1, 1998 (filed as Exhibit 4.3 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Form of Amended and Restated Declaration of Trust dated October 1, 1998 (filed as Exhibit 4.4 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Form of Preferred Security Certificate for NVP Capital III dated October 1, 1998 (filed as Exhibit 4.5 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Form of Preferred Securities Guarantee Agreement dated October 1, 1998 (filed as Exhibit 4.7 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Form of Junior Subordinated Deferrable Interest Debenture dated October 1, 1998 (filed as Exhibit 4.9 to Form S-3, File Nos. 333-63613 and 333-63613-01).
. Supplemental Indenture No. 1 and Assumption Agreement, dated as of June 1, 1999, between Nevada Power Company and IBJ Whitehall Bank & Trust Company, supplementing and assuming the Indenture dated as of October 1, 1998 between Nevada Power Company and IBJ Whitehall Bank & Trust Company (filed as Exhibit 4(E) to Form 10-K for year ended December 31, 1999).
. Form of Senior Unsecured Note Indenture between Nevada Power Company and IBJ Whitehall Bank & Trust Company dated as of March 1, 1999 (filed as Exhibit 4.1 to Form S-4, File No. 333-77325).
. Supplemental Indenture No. 1 between Nevada Power Company and IBJ Whitehall Bank & Trust Company dated as of March 1, 1999 (including form of 6.20% Senior Unsecured Note, Series A due April 15, 2004) (filed as Exhibit 4.2 to Form S-4, File No. 333-77325).
. Supplemental Indenture No. 2 between Nevada Power Company and IBJ Whitehall Bank & Trust Company dated as of April 1, 1999 (including form of 6.20% Senior Unsecured Note, Series B due April 15, 2004) (filed as Exhibit 4.3 to Form S-4, File No. 333-77325).
. Supplemental Indenture No. 3 and Assumption Agreement, dated as of July 1, 1999, between Nevada Power Company and IBJ Whitehall Bank & Trust Company, supplementing and assuming the Senior Unsecured Note Indenture dated as of March 1, 1999 between Nevada Power Company and IBJ Whitehall Bank & Trust Company (filed as Exhibit 4(F) to Form 10-K for year ended December 31, 1999).
. Indenture of Mortgage and Deed of Trust providing for Nevada Power Company's First Mortgage Bonds, dated as of October 1, 1953 and Twenty-Eight Supplemental Indentures as follows:
. First Supplemental Indenture, dated as of August 1, 1954 (filed as Exhibit 4.2 to Form S-1, File No. 2-11440).
. Instrument of Further Assurance dated April 1, 1956 to Indenture of Mortgage and Deed of Trust dated October 1, 1953 (filed as Exhibit 4.8 to Form S-1, File No. 2-12666).
. Second Supplemental Indenture, dated as of September 1, 1956 (filed as Exhibit 4.9 to Form S-1, File No. 2-12566).
. Third Supplemental Indenture, dated as of May 1, 1959 (filed as Exhibit 4.13 to Form S-1, File No. 2-14949).
. Fourth Supplemental Indenture, dated as of October 1, 1960 (filed as Exhibit 4.5 to S-1, File No. 2-16968).
. Fifth Supplemental Indenture, dated as of December 1, 1961 (filed as Exhibit 4.6 to Form S-16, File No. 2-74929).
. Sixth Supplemental Indenture, dated as of October 1, 1963 (filed as Exhibit 4.6A to Form S-1, File No. 2-21689).
. Seventh Supplemental Indenture, dated as of August 1, 1964 (filed as Exhibit 4.6B to Form S-1, File No. 2-22560).
. Eighth Supplemental Indenture, dated as of April 1, 1968 (filed as Exhibit 4.6C to Form S-9, File No. 2-28348.
. Ninth Supplemental Indenture, dated as of October 1, 1969 (filed as Exhibit 4.6D to Form S-1, File No. 2-34588).
. Tenth Supplemental Indenture, dated as of October 1, 1970 (filed as Exhibit 4.6E to Form S-7, File No. 2-38314).
. Eleventh Supplemental Indenture, dated as of November 1, 1972 (filed as Exhibit 2.12 to Form S-7, File No. 2-45728).
. Twelfth Supplemental Indenture, dated as of December 1, 1974 (filed as Exhibit 2.13 to Form S-7, File No. 2-52350).
. Thirteenth Supplemental Indenture, dated as of October 1, 1976 (filed as Exhibit 4.14 to Form S-16, File No. 2-74929).
. Fourteenth Supplemental Indenture, dated as of May 1, 1977 (filed as Exhibit 4.15 to Form S-16, File No. 2-74929).
. Fifteenth Supplemental Indenture, dated as of September 1, 1978 (filed as Exhibit 4.16 to Form S-16, File No. 2-74929).
. Sixteenth Supplemental Indenture, dated as of December 1, 1981 (filed as Exhibit 4.17 to Form S-16, File No. 2-74929).
. Seventeenth Supplemental Indenture, dated as of August 1, 1982 (filed as Exhibit 4.2 to Form 10-K, File No. 1-4698, Year 1982).
. Eighteenth Supplemental Indenture, dated as of November 1, 1986 (filed as Exhibit 4.6 to Form S-3, File No. 33-9537).
. Nineteenth Supplemental Indenture, dated as of October 1, 1989 (filed as Exhibit 4.2 to Form 10-K, File No. 1-4698, Year 1989).
. Twentieth Supplemental Indenture, dated as of May 1, 1992 (filed as Exhibit 4.21 to Form S-3, File No. 33-53034).
. Twenty-First Supplemental Indenture, dated as of June 1, 1992 (filed as Exhibit 4.22 to Form S-3, File No. 33-53034).
. Twenty-Second Supplemental Indenture, dated as of June 1, 1992 (filed as Exhibit 4.23 to Form S-3, Filed No. 33-53034).
. Twenty-Third Supplemental Indenture, dated as of October 1, 1992 (filed as Exhibit 4.23 to Form S-3, File No. 33-53034).
. Twenty-Fourth Supplemental Indenture, dated as of October 1, 1992 (filed as Exhibit 4.23 to Form S-3, File No. 33-53034).
. Twenty-Fifth Supplemental Indenture, dated as of January 1, 1993 (filed as Exhibit 4.23 to Form S-3, File No. 33-53034).
. Twenty-Sixth Supplemental Indenture, dated as of May 1, 1995 (filed as Exhibit 4.2 to Form 10-K, File No. 1-4698, Year 1995).
. Twenty-Seventh Supplemental Indenture dated as of as of July 1, 1999 (filed as Exhibit 4(C) to Form 10-K for year ended December 31, 1999).
. *(D) Twenty-Eighth Supplemental Indenture dated as of July 1, 2001.
Sierra Pacific Power Company
. Indenture of Mortgage providing for Sierra Pacific Power Company's First Mortgage Bonds, dated as of December 1, 1940 (filed as Exhibit 7-A to Registration No. 2-7475).
. Ninth Supplemental Indenture, dated as of June 1, 1964 (filed as Exhibit 2-M to Registration No. 2-59509).
. Tenth Supplemental Indenture, dated as of March 31, 1965 (filed as Exhibit 4-K to Registration No. 2-23932).
. Eleventh Supplemental Indenture, dated as of October 1, 1965 (filed as Exhibit 4-L to Registration No. 2-26552).
. Twelfth Supplemental Indenture, dated as of July 1, 1967 (filed as Exhibit 4-L to Registration No. 2-36982).
. Sixteenth Supplemental Indenture, dated as of October 1, 1975 (filed as Exhibit 2-Y to Registration No. 2-53404).
. Nineteenth Supplemental Indenture, dated as of April 1, 1978 (filed as Exhibit (4)(A) to the 1991 Form 10-K).
. Twentieth Supplemental Indenture, dated as of October 1, 1978 (filed as Exhibit (4)(B) to the 1991 Form 10-K).
. Twenty-Seventh Supplemental Indenture, dated as of August 1, 1989 (filed as Exhibit (4)(A) to the 1989 Form 10-K).
. Twenty-Eighth Supplemental Indenture, dated as of May 1, 1992 (filed as Exhibit (4)(A) to the 1992 Form 10-K).
. Twenty-Ninth Supplemental Indenture, dated as of June 1, 1992 (filed as Exhibit D to Form 8-K dated July 15, 1992).
. Thirtieth Supplemental Indenture, dated as of July 1, 1992 (filed as Exhibit (4)(B) to the 1992 Form 10-K).
. Thirty-First Supplemental Indenture, dated as of November 1, 1992 (filed as Exhibit (4)(C) to the 1992 Form 10-K).
. Thirty-Second Supplemental Indenture, dated as of June 1, 1993 (filed as Exhibit 4.6 to Registration No. 33-69550).
. Thirty-Third Supplemental Indenture, dated as of October 1, 1993 (filed as Exhibit C to Form 8-K dated October 20, 1993).
. Thirty-Fourth Supplemental Indenture, dated as of February 1, 1996 (filed as Exhibit C to Form 8-K dated March 11, 1996).
. Thirty-Fifth Supplemental Indenture, dated as of February 1, 1997 (filed as Exhibit C to Form 8-K dated March 10, 1997).
. Indenture dated as of April 9, 1999 between SPPC Funding LLC and Bankers Trust Company of California, N.A. in connection with the issuance of California rate reduction bonds (filed as Exhibit 4(C) to Form 10-K for year ended December 31, 1999).
. First Series Supplement dated as of April 9, 1999 to Indenture between SPPC Funding LLC and Bankers Trust Company of California, N.A. in connection with the issuance of California rate reduction bonds (filed as Exhibit 4(D) to Form 10-K for year ended December 31, 1999).
. Form of SPPC Funding LLC Notes, Series 1999-1, in connection with the issuance of California rate reduction bonds (filed as Exhibit 4(E) to Form 10-K for year ended December 31, 1999).
. Collateral Trust Indenture dated June 1, 1992 between Sierra Pacific Power Company and Bankers Trust Company, as Trustee, relating to Sierra Pacific Power Company's medium-term note program (filed as Exhibit B to Form 8-K dated July 15, 1992).
. First Supplemental Indenture dated June 1, 1992 (filed as Exhibit C to Form 8-K dated July 15, 1992).
. Second Supplemental Indenture dated October 1, 1993 (filed as Exhibit B to Form 8-K dated October 20, 1993).
. Third Supplemental Indenture dated as of February 1, 1996 (filed as Exhibit B to Form 8-K dated March 11, 1996).
. Fourth Supplemental Indenture dated as of February 1, 1997 (filed as Exhibit B to Form 8-K dated March 10, 1997).
. Form of Medium-Term Global Fixed Rate Note, Series A in connection with Sierra Pacific Power Company's medium-term note program (filed as Exhibit E to Form 8-K dated July 15, 1992 ).
. Form of Medium-Term Global Fixed Rate Note, Series B in connection with Sierra Pacific Power Company's medium-term note program (filed as Exhibit D to Form 8-K dated October 25, 1993).
. Form of Medium-Term Global Fixed-Rate Note, Series C in connection with Sierra Pacific Power Company's medium-term note program (filed as Exhibit D to Form 8-K dated March 11, 1996).
. Form of Medium-Term Global Fixed-Rate Note, Series D in connection with Sierra Pacific Power Company's medium-term note program (filed as Exhibit D to Form 8-K dated March 10, 1997).
(10) Sierra Pacific Resources, Nevada Power Company, and Sierra Pacific Power Company
Sierra Pacific Resources
. *(A) Credit Agreement dated as of November 30, 2001, among Sierra Pacific Resources, Union Bank of California, N.A., as Sole Bookrunner and Administrative Agent, Wells Fargo Bank, N4.A., as Syndication Agent, Bank One, NA, BNP Paribas and Mellon Bank, N.A., as Co-Documentation Agents, the Lenders party hereto from time to time, and Union Bank of California, N.A. and Wells Fargo Bank, N.A., as Co-Lead Arrangers relating to $75,000,000 credit facility.
. *(B) Change in Control Agreement dated May 21, 2001, by and between Sierra Pacific Resources and Walter M. Higgins.
. Walter M. Higgins Employment Letter dated August 4, 2000 (filed as Exhibit 10(B) to Form 10-K for the year ended December 31, 2000).
. *(C) Change in Control Agreement dated May 21, 2001, by and among Sierra Pacific Resources and the following officers (individually): Jeffrey L. Ceccarelli, Steven C. Oldham, Victor H. Pena, William E. Peterson and Mark A. Ruelle in substantially the same form as the Change in Control Agreement dated May 21, 2001 by and between Sierra Pacific Resources and Dennis D. Schiffel.
. *(D) Change in Control Agreement dated May 21, 2001, by and among Sierra Pacific Resources and the following officers (individually): Richard K. Atkinson, Susan Brennan, Matt H. Davis, Carol Elmore, Paul Heagen, Douglas R. Ponn, Mary O. Simmons and Mike Smart, in substantially the same form as the Change in Control Agreement dated May 21, 2001 by and between Sierra Pacific Resources and John E. Brown.
. Sierra Pacific Resources' Executive Long-Term Incentive Plan (filed as Exhibit 99.1 to Form S-8 dated December 13, 1999).
. Sierra Pacific Resources' Non-Employee Director Stock Plan (filed as Exhibit 99.2 to Form S-8 dated December 13, 1999).
. Sierra Pacific Resources' Employee Stock Purchase Plan (filed as Exhibit 99.3 to Form S-8 dated December 13, 1999).
Nevada Power Company
. Asset Sale Agreement between Nevada Power Company and The AES Corporation dated as of May 10, 2000 for the Mohave Asset Bundle (filed as Exhibit (10)(C) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Nevada Power Company and AES Mohave, LLC dated as of May 10, 2000 (filed as Exhibit (10)(D) to Form 10-K for the year ended December 31, 2000).
. Asset Sale Agreement between Nevada Power Company, NRG Energy, Inc. and Dynegy Holdings Inc. for the Clark Asset Bundle dated as of November 16, 2000 (filed as Exhibit (10)(E) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Nevada Power Company and Clark Power LLC dated as of November 16, 2000 (filed as Exhibit (10)(F) to Form 10-K for the year ended December 31, 2000).
. Asset Sale Agreement between Nevada Power Company, NRG Energy, Inc. and Dynegy Holdings Inc. for the Reid Gardner Asset Bundle dated as of November 16, 2000 (filed as Exhibit (10)(G) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Nevada Power Company and Reid Gardner Power LLC dated as of November 16, 2000 (filed as Exhibit (10)(H) to Form 10-K for the year ended December 31, 2000).
. Asset Sale Agreement between Nevada Power Company and Pinnacle West Energy Corporation for the Harry Allen Asset Bundle, dated as of December 1, 2000 (filed as Exhibit (10)(I) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Nevada Power Company and Pinnacle West Energy Corporation dated as of December 1, 2000 (filed as Exhibit (10)(J) to Form 10-K for the year ended December 31, 2000).
. Asset Sale Agreement between Nevada Power Company and Reliant Energy Sunrise, LLC for the Sunrise/Sun-Peak Asset Bundle dated as of December 9, 2000 (filed as Exhibit (10)(K) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Nevada Power Company and Reliant Energy Sunrise, LLC dated as of December 9, 2000 (filed as Exhibit (10)(L) to Form 10-K for the year ended December 31, 2000).
. *(E) Credit Agreement, dated as of November 1, 2001, among Nevada Power Company, Union Bank of California, N.A., as Sole Bookrunner and Administrative Agent, Wells Fargo Bank, N.A., as Syndication Agent, Bank One, NA, BNP Paribas and Mellon Bank, N.A., as Co-Documentation Agents, the Lenders party hereto from time to time, and Union Bank of California, N.A. and Wells Fargo Bank, N.A., as Co-Lead Arrangers relating to $200,000,000 credit facility.
. Letter of Credit and Reimbursement Agreement dated as of October 1, 1995 among Nevada Power Company, The Banks named therein, and Societe Generale, Los Angeles Branch (relating to the Clark County, Nevada $85,000,000 Industrial Development Refunding Revenue Bonds, Series 1995B; Clark County, Nevada $20,300,000 Pollution Control Refunding Revenue Bonds Series, 1995D; and Coconino County, Arizona Pollution Control Corporation $13,000,000 Pollution Control Refunding Revenue Bonds, Series 1995E) (filed as Exhibit 10.80 to Form 10-K, File No. 1-4698, Year 1995).
. Letter of Credit and Reimbursement Agreement dated as of October 1, 1995 among Nevada Power Company, The Banks named therein, and Barclays Bank PLC, New York Branch (relating to Clark County, Nevada $44,000,000 Industrial Development Refunding Revenue Bonds, Series 1995C) (filed as Exhibit 10.81 to Form 10-K, File No. 1-4698, Year 1995).
. Letter of Credit and Reimbursement Agreement dated as of April 12, 1994 between Nevada Power Company and Societe Generale, Los Angeles Branch and Amendment No. 1 thereto dated as of May 3, 1994 (relating to $60,000,000 Clark County, Nevada Floating Rate Weekly
Demand Industrial Development Revenue Bonds, Series 1989A) (filed as Exhibit 10.72 to Form 10-K, File No. 1-4698, Year 1994).
. Reimbursement Agreement dated as of November 1, 1988 between the Fuji Bank, Limited and Nevada Power Company (relating to $25,000,000 Clark County, Nevada Floating Rate Weekly Demand Industrial Development Revenue Bonds, Series 1998) (filed as Exhibit 10.43 to Form 10-K, File No. 1-4698, Year 1988).
. Reimbursement Agreement dated as of December 1, 1985 between The Fuji Bank, Limited and Nevada Power Company (relating to Clark County, Nevada $44,000,000 Floating Rate Weekly Demand Industrial Development Revenue Bonds, Series 1985) (filed as Exhibit 10.38 to Form 10-K, File No. 1-4698, Year 1986).
. Guaranty Agreement dated as of March 1, 1974 between Nevada Power Company and Commerce Union Bank as Trustee (filed as Exhibit 5.39 to Form 8-K, File No. 1-4698, April 1974).
. Financing Agreement No. 1 between Clark County, Nevada and Nevada Power Company dated as of June 1, 2000 (Series 2000A) (filed as Exhibit 10(O) to Form 10-K for the year ended December 31, 2000).
. Financing Agreement No. 2 between Clark County, Nevada and Nevada Power Company dated as of June 1, 2000 (Series 2000B) (filed as Exhibit 10(P) to Form 10-K for the year ended December 31, 2000).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated November 1, 1997 (relating to Clark County, Nevada $52,285,000 Industrial Development Revenue Bonds, Series 1997A) (filed as Exhibit 10.83 to Form 10-K, File No. 1-4698, Year 1997).
. Financing Agreement between Coconino County, Arizona Pollution Control Corporation and Nevada Power Company dated November 1, 1997 (relating to Coconino County, Arizona $20,000,000 Pollution Control Corporation Pollution Control Revenue Bonds, Series 1997B) (filed as Exhibit 10.84 to Form 10-K, File No. 1-4698, Year 1997).
. Financing Agreement between Coconino County, Arizona Pollution Control Corporation and Nevada Power Company dated October 1, 1996 (relating to Coconino County, Arizona Pollution Control Corporation $20,000,000 Pollution Control Revenue Bonds, Series 1996) (filed as Exhibit 10.82 to Form 10-K, File 1-4698, Year 1996).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated October 1, 1995 (relating to Clark County, Nevada $76,750,000 Industrial Development Revenue Bonds, Series 1995A) (filed as Exhibit 10.75 to Form 10-K, File No. 1-4698, Year 1995).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated October 1, 1995 (relating to Clark County, Nevada $85,000,000 Industrial Development Refunding Revenue Bonds, Series 1995B) (filed as Exhibit 10.76 to Form 10-K, File No. 1-4698, Year 1995).
. Financing Agreement between Clark County, Nevada and Nevada Power
Company dated October 1, 1995 (relating to Clark County, Nevada
$76,750,000 Industrial Development Revenue Bonds, Series 1995A and
$44,000,000 Industrial Development Refunding Revenue Bonds, Series
x 1995C) (filed as Exhibit 10.77 to Form 10-K, File No. 1-4698,
Year 1995).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated October 1, 1995 (relating to Clark County, Nevada $20,300,000 Pollution Control Refunding Revenue Bonds, Series 1995D) (filed as Exhibit 10.78 to Form 10-K, File No. 1-4698, Year 1995).
. Financing Agreement between Coconino County, Arizona Pollution\ Control Corporation and Nevada Power Company dated October 1, 1995 (relating to Coconino County, Arizona Pollution Control Corporation $13,000,000 Pollution Control Refunding Revenue Bonds, Series 1995E) (filed as Exhibit 10.79 to Form 10-K, File No. 1-4698, Year 1995).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated October 1, 1992 (Relating to Industrial Development Refunding Revenue Bonds, Series 1992C) (filed as Exhibit 10.67 to Form 10-K, File No. 1-4698, Year 1992).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated June 1, 1992 (Relating to Clark County, Nevada $105,000,000 Industrial Development Revenue Bonds, Series 1992A) (filed as Exhibit 10.65 to Form 10-K, File No. 1-4698, Year 1992).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated June 1, 1992 (Relating to Pollution Control Refunding Revenue Bonds, Series 1992B) (filed as Exhibit 10.66 to Form 10-K, File No. 1-4698, Year 1992).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated as of November 1, 1988 (relating to Clark County, Nevada $25,000,000 Floating Rate Weekly Demand Industrial Development Revenue Bonds, Series 1988) (filed as Exhibit 10.42 to Form 10-K, File No. 1-4698, Year 1988).
. Financing Agreement between Clark County, Nevada and Nevada Power Company dated as of December 1, 1985 (relating to Clark County, Nevada $44,000,000 Floating Rate Weekly Demand Industrial Development Revenue Bonds, Series 1985) (filed as Exhibit 10.37 to Form 10-K, File No. 1-4698, Year 1985).
. Financing Agreement dated as of February 1, 1983 between Clark County, Nevada and Nevada Power Company (relating to Clark ounty, Nevada $78,000,000 Industrial Development Revenue Bonds, Series 1983) (filed as Exhibit 10.36 to Form 10-K, File No. 1-4698, Year 1985).
. Plant Collective Bargaining Agreement dated February 1, 1998, effective through February 1, 2002 between Nevada Power Company and the International Brotherhood of Electrical Workers Local No. 396 (filed as Exhibit 10(Q) to Form 10-K for the year ended December 31, 2000).
. Clerical Collective Bargaining Agreement dated February 1, 1998, effective through February 1, 2002 between Nevada Power Company and the International Brotherhood of Electrical Workers Local No. 396 (filed as Exhibit 10(R) to Form 10-K for the year ended December 31, 2000).
. Generation Agreement dated as of June 25, 1999 between Nevada Power Company and the International Brotherhood of Electrical Workers Local No. 396 (filed as Exhibit 10(S) to Form 10-K for the year ended December 31, 2000).
. Contract for Long-Term Power Purchases from Qualifying Facilities dated May 27, 1992 between Las Vegas Co-generation, Inc. and Nevada Power Company (filed as Exhibit 10.70 to Form 10-K, File No. 1-4698, Year 1993).
. *(F) Western Systems Power Pool ("WSPP") Agreement effective March 1, 2002 between Nevada Power Company as a member of WSPP and the other members of the WSPP.
. Contract A for Long-Term Power Purchases from Qualifying Facilities dated May 2, 1989 between Nevada Cogenerational Associates #1 (assigned from Bonneville Nevada Corporation) and Nevada Power Company (filed as Exhibit 10.47 to Form 10-K, File No. 1-4698, Year 1989).
. Contract B for Long-Term Power Purchases from a Qualifying Facility dated May 24, 1990 between Nevada Cogenerational Associates (assigned from Bonneville Nevada Corporation) and Nevada Power Company (filed as Exhibit 10.56 to Form 10-K, File No. 1-4698, Year 1990).
. Contract for Long-Term Power Purchases from Qualifying Facilities dated April 10, 1989 between Saguaro Power Company (assigned from Magna Energy Systems and Eastern Sierra Energy Company) and Nevada Power Company (filed as Exhibit 10.48 to Form 10-K, File No. 1-4698, Year 1989).
. Agreement for Transmission Service dated March 29, 1989 between Overton Power District No. 5, Lincoln County Power District No. 1 and Nevada Power Company (filed as Exhibit 10.51 to Form 10-K, File No. 1-4698, Year 1989).
. Contract for Operation, Maintenance, Replacement, Ownership, and Interconnection of Facilities dated June 30, 1988 between United States Department of Energy Western Area Power Administration and Nevada Power Company (filed as Exhibit 10.52 to Form 10-K, File No. 1-4698, Year 1989).
. Transmission Facilities Agreement between Utah Power & Light Company and Nevada Power Company, dated August 17, 1987 (filed as Exhibit 10.41 to Form 10-K, File No. 1-4698, Year 1987).
. Contract for Sale of Electrical Energy between the State of Nevada and Nevada Power Company, dated July 8, 1987 (filed as Exhibit 10.39 to Form 10-K, File No. 1-4698, Year 1987).
. Participation Agreement Reid Gardner Unit No. 4 dated July 11, 1979 between Nevada Power Company and California Department of Water Resources (filed as Exhibit 5.34 to Form S-7, File No. 2-65097).
. Amended Mohave Project Coal Slurry Pipeline Agreement dated May 26, 1976 between Peabody Coal Company and Black Mesa Pipeline, Inc. (Exhibit B to Exhibit 10.18) (filed as Exhibit 5.36 to Form S-7, File No. 2-56356).
. Amended Mohave Project Coal Supply Agreement dated May 26, 1976 between Nevada Power Company and Southern California Edison Company, Department of Water and Power of the City
of Los Angeles, Salt River Project Agricultural Improvement and Power District and the Peabody Coal Company (filed as Exhibit 5.35 to Form S-7, File No. 2-56356).
. Navajo Project Co-Tenancy Agreement dated March 23, 1976 between Nevada Power Company, Arizona Public Service Company, Department of Water and Power of the City of Los Angeles, Salt River Project Agricultural Improvement and Power District, Tucson Gas & Electric Company and the United States of America (filed as Exhibit 5.31 to Form 8-K, File No. 1-4696, April 1974).
. Mohave Operating Agreement dated July 6, 1970 between Nevada Power Company, Salt River Project Agricultural Improvement and Power District, Southern California Edison Company and Department of Water and Power of the City of Los Angeles (filed as Exhibit 13.26F to Form S-1, File No. 2-38314).
. Navajo Project Coal Supply Agreement dated June 1, 1970 between Nevada Power Company, the United States of America, Arizona Public Service Company, Department of Water and Power of the City of Los Angeles, Salt River Project Agricultural District, Tucson Gas & Electric Company and the Peabody Coal Company (filed as Exhibit 13.27B to Form S-1, File No. 2-38314).
. Eldorado System Conveyance and Co-Tenancy Agreement dated December 20, 1967 between Nevada Power Company and Salt River Project Agricultural Improvement and Power District and Southern California Edison Company (filed as Exhibit 13.30 to Form S-9, File No. 2-28348).
. Mohave Project Plant Site Conveyance and Co-Tenancy Agreement dated May 29, 1967 between Nevada Power Company and Salt River Project Agricultural Improvement and Power District and Southern California Edison Company (filed as Exhibit 13.27 to Form S-9, File No. 2-28348).
. Reliability Management System Agreement dated June 18, 1999 by and between Western Systems Coordinating Council and Nevada Power Company (filed as Exhibit 10(U) to Form 10-K for the year ended December 31, 2000).
. *(G) Service Agreement No. 90 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission July 20, 2001 between Nevada Power Company and Reliant Energy Services, Inc.
. *(H) Service Agreement Nos. 95 and 96 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 1, 2001 between Nevada Power Company and Calpine Corporation.
. *(I) Service Agreement No. 97 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 1, 2001 between Nevada Power Company and Duke Energy Trading and Marketing.
. *(J) Service Agreement Nos. 98 and 99 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 1, 2001 between Nevada Power Company and Mirant Americas Development, Inc.
. *(K) Service Agreement No. 100 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 1, 2001 between Nevada Power Company and Pinnacle West Energy Company.
. *(L) Service Agreement No. 101 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 1, 2001 between Nevada Power Company and Reliant Energy Services, Inc.
. *(M) Service Agreement No. 102 for Long-Term Firm Point-To-Point Transmission Service filed with the Federal Energy Regulatory Commission August 3, 2001 between Nevada Power Company and Las Vegas Cogeneration II, LLC.
. Sublease Agreement between Powveg Leasing Corp., as Lessor and Nevada Power Company as Lessee, dated January 1, 1984 for lease of administrative headquarters (the primary term of the sublease ends in 2014 and the lessee has the option to extend the term up to 25 additional years) (filed as Exhibit 10.31 to Form 10-K, File No. 1-4698, Year 1983).
Sierra Pacific Power Company
. Asset Sale Agreement between Sierra Pacific Power Company and NRG Energy, Inc. dated as of October 16, 2000 for the North Valmy Asset Bundle (filed as Exhibit (10)(V) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Sierra Pacific Power Company and Valmy Power LLC dated as of October 16, 2000 (filed as Exhibit (10)(W) to Form 10-K for the year ended December 31, 2000).
. Asset Sale Agreement between Sierra Pacific Power Company and WPS Northern Nevada, LLC for the Tracy/Pinon Asset Bundle dated as of October 25, 2000 (filed as Exhibit (10)(X) to Form 10-K for the year ended December 31, 2000).
. Transitional Power Purchase Agreement by and between Sierra Pacific Power Company and WPS Northern Nevada, LLC dated as of October 25, 2000 (filed as Exhibit (10)(Y) to Form 10-K for the year ended December 31, 2000).
. Asset Purchase Agreement between Sierra Pacific Power Company and Truckee Meadows Water Authority dated as of January 15, 2001 (filed as Exhibit (10)(Z) to Form 10-K for the year ended December 31, 2000).
. *(N) Credit Agreement dated as of November 30, 2001, among Sierra Pacific Power Company, Union Bank of California, N.A., as Sole Bookrunner and Administrative Agent, Wells Fargo Bank, N.A., as Syndication Agent, Bank One, NA, BNP Paribas and Mellon Bank, N.A., as Co-Documentation Agents, the Lenders party hereto from time to time, and Union Bank of California, N.A. and Wells Fargo Bank, N.A., as Co-Lead Arrangers relating to $150,000,000 credit facility.
. Financing Agreement dated June 1, 1993 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 1993A (filed as Exhibit (10) (I) to Form 10-K for the year ended December 31, 1993).
. Financing Agreement dated June 1, 1993 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Gas and Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 1993B (filed as Exhibit (10) (J) to Form 10-K for the year ended December 31, 1993).
. *(O) Financing Agreement dated as of March 1, 2001 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 2001.
. Financing Agreement dated September 1, 1990 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Gas Facilities Revenue Bonds (Sierra Pacific Power Company Project) Series 1990 (filed as Exhibit (10)(C) to Form 10-K for the year ended December 31, 1990).
. Financing Agreement dated December 1, 1987 between Sierra Pacific
Power Company and Washoe County, Nevada relating to the Washoe
County, Nevada Variable Rate Demand Gas Facilities Revenue Bonds
(Sierra Pacific Power Company Project) Series 1987 (filed as Exhibit
(10)(H) to Form 10-K for the year ended December 31, 1993).
. Financing Agreement dated June 1, 1987 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Variable Rate Demand Water Facilities Revenue Bonds (Sierra Pacific Power Company Project) Series 1987 (filed as Exhibit (10)(G) to Form 10-K for the year ended December 31, 1993).
. Financing Agreement dated March 1, 1987 between Sierra Pacific Power
Company and Humboldt County, Nevada relating to the Humboldt County,
Nevada Variable Rate Demand Pollution Control Refunding Revenue Bonds
(Sierra Pacific Power Company Project) Series 1987 (filed as Exhibit
(10)(E) to Form 10-K for the year ended December 31, 1993).
. Financing Agreement dated March 1, 1987 between Sierra Pacific Power Company and Washoe County, Nevada relating to the Washoe County, Nevada Variable Rate Demand Gas and Water Facilities Refunding Revenue Bonds (Sierra Pacific Power Company Project) Series 1987 (filed as Exhibit (10)(F) to Form 10-K for the year ended December 31, 1993).
. Agreement dated January 1, 1998 (extended through December 31, 2002) between Sierra Pacific Power Company and the International Brotherhood of Electrical Workers Local No. 1245 (filed as Exhibit 10(B) to Form 10-K for the year ended December 31, 1997).
. Transition Property Purchase and Sale Agreement dated as of April 9, 1999 between Sierra Pacific Power Company and SPPC Funding LLC in connection with the issuance of California rate reduction bonds (filed as Exhibit 10(B) to Form 10-K for the year ended December 31, 1999).
. Transition Property Servicing Agreement dated as of April 9, 1999 between Sierra Pacific Power Company and SPPC Funding LLC in connection with the issuance of California rate reduction bonds (filed as Exhibit 10(C) to Form 10-K for the year ended December 31, 1999).
. Administrative Services Agreement dated as of April 9, 1999 between Sierra Pacific Power Company and SPPC Funding LLC in connection with the issuance of California rate reduction bonds (filed as Exhibit 10(D) to Form 10-K for the year ended December 31, 1999).
. Cooperative Agreement dated July 31, 1992 between Sierra Pacific Power Company and the United States Department of Energy in connection with the Pinon Pine Integrated Coal Gasification Combined Cycle Project (filed as Exhibit (10)(H) to Form 10-K for the year ended December 31, 1992).
. Settlement Agreement and Mutual Release dated May 8, 1992 between Sierra Pacific Power Company and Coastal States Energy Company (filed as Exhibit (10)(D) to Form 10-K for the year ended December 31, 1992; confidential portions omitted and filed separately with the Securities and Exchange Commission).
. Western Systems Power Pool ("WSPP") Agreement effective March 1, 2002 between Sierra Pacific Power Company as a member of WSPP and the other members of the WSPP (filed as Exhibit (10)(F) above).
. General Transfer Agreement dated February 25, 1988 between Sierra Pacific Power Company and the United States of America Department of Energy acting by and through the Bonneville Power Administration (filed as Exhibit (10)(E) to Form 10-K for the year ended December 31, 1988).
. *(P) Amendatory Agreement No. 1 dated April 11, 1995 to General Transfer Agreement dated February 25, 1988 between Sierra Pacific Power Company and the United States of America Department of Energy acting by and through the Bonneville Power Administration.
. *(Q) Amendatory Agreement No. 2 dated July 5, 2000 to General Transfer Agreement dated February 25, 1988 between Sierra Pacific Power Company and the United States of America Department of Energy acting by and through the Bonneville Power Administration.
. *(R) Coal Sales Agreement dated January 1, 2002 between Sierra Pacific Power Company and Arch Coal Sales Company, Inc. (5 year term ending on December 31, 2006).
. Coal Purchase Contract dated June 19, 1986 between Sierra Pacific Power Company, Black Butte Coal Company and Idaho Power Company (filed as Exhibit (10)(C) to the Form 10-K for the year ended December 31, 1992).
. Interconnection Agreement dated May 29, 1981 between Sierra Pacific Power Company and Idaho Power Company (filed as Exhibit (10)(C) to Form 10-K for the year ended December 31, 1991).
. Amendatory Agreement dated February 14, 1992 to Interconnection Agreement dated May 29, 1981 between Sierra Pacific Power Company and Idaho Power Company (filed as Exhibit (10)(D) to Form 10-K for the year ended December 31, 1991).
. Coal Sales Agreement dated May 16, 1978 between Sierra Pacific Power Company and Coastal States Energy Company (confidential portions omitted and filed separately with the Securities and Exchange Commission) (filed as Exhibit 5-GG to Registration No. 2-62476).
. Amendment No. 1 dated November 8, 1983 to Coal Sales Agreement dated May 16, 1978 between Sierra Pacific Power Company and Coastal States Energy Company (filed as Exhibit (10)(B) to Form 10-K for the year ended December 31, 1991).
. Amendment No. 2 dated February 25, 1987 to Coal Sales Agreement dated May 16, 1978 between Sierra Pacific Power Company and Coastal States Energy Company (filed as Exhibit (10)(A) to Form 10-K for the year ended December 31, 1993).
. Amendment No. 3 dated May 8, 1992 to Coal Sales Agreement dated May 16, 1978 between Sierra Pacific Power Company and Coastal States Energy Company (filed as Exhibit (10)(B) to Form 10-K for the year ended December 31, 1992; confidential portions omitted and filed separately with the Securities and Exchange Commission).
. Lease dated January 30, 1986 between Sierra Pacific Power Company and Silliman Associates Limited Partnership relating to the Company's corporate headquarters building (filed as Exhibit (10)(I) to Form 10-K for the year ended December 31, 1992).
. Letter of Amendment dated May 18, 1987 to Lease dated January 30, 1986 between Sierra Pacific Power Company and Silliman Associates Limited Partnership relating to the Company's corporate headquarters building (filed as Exhibit (10) (K) to Form 10-K for the year ended December 31, 1993).
(11) Nevada Power Company and Sierra Pacific Power Company
. Nevada Power Company and Sierra Pacific Power Company are wholly
owned subsidiaries and, in accordance with Paragraph 6 of SFAS No.
128 (Earnings Per Share), earnings per share data have been
omitted.
(12) Sierra Pacific Resources
. *(A) Statement regarding computation of Ratios of Earnings to Fixed Charges.
Nevada Power Company
. *(B) Statement regarding computation of Ratios of Earnings to Fixed Charges.
Sierra Pacific Power Company
. *(C) Statement regarding computation of Ratios of Earnings to Fixed Charges.
(21) Sierra Pacific Resources
. Nevada Power Company, a Nevada Corporation.
Sierra Pacific Power Company, a Nevada Corporation.
Great Basin Energy Company, a Nevada Corporation.
Lands of Sierra, Inc., a Nevada Corporation.
Nevada Electric Investment Company, a Nevada Corporation.
Sierra Energy Company dba e.three, a Nevada Corporation.
Sierra Gas Holdings Company, a Nevada Corporation.
Sierra Pacific Energy Company, a Nevada Corporation.
Sierra Pacific Resources Capital Trust I, a Delaware Business
Trust.
Sierra Pacific Resources Capital Trust II, a Delaware Business
Trust.
Sierra Water Development Company, a Nevada Corporation.
Tuscarora Gas Pipeline Company, a Nevada Corporation.
Tuscarora Gas Operating Company, a Nevada Corporation.
Nevada Power Company
. Commonsite, Inc., a Nevada Corporation.
NVP Capital I, a Delaware Business Trust.
NVP Capital II, a Delaware Business Trust.
Sierra Pacific Power Company
. Pinon Pine Company, a Nevada Corporation.
Pinon Pine Investment Company, a Nevada Corporation.
Pinon Pine Investment Co. LLC, a Nevada Limited Liability Company.
GPSF-B, a Delaware Corporation.
SPPC Funding LLC, a Delaware Limited Liability Company.
Sierra Pacific Power Capital Trust I, a Delaware Business Trust.
(23) Sierra Pacific Resources
. *(A) Consent of Independent Accountants in connection with the Sierra Pacific Resources' Registration Statements No. 333-77523 (Common Stock Investment Plan) on Form S-3, No. 333-92651 (Employees' Stock Ownership Plan, Executive Long-Term Incentive Plan, and Non-Employee Director Stock Plan) on Forms S-8, and No. 333-72160 (Post-Effective Amendment to Registration No. 333-80149 on Form S-3.
EXHIBIT 4(A)
Nevada Power Company
6226 W. Sahara Avenue
P.O. Box 230
Las Vegas, Nevada 89146
NEVADA POWER COMPANY
TO
THE BANK OF NEW YORK
Trustee
SECOND SUPPLEMENTAL INDENTURE
Dated as of October 1, 2001
Supplementing and Amending the General and Refunding Mortgage Indenture Dated as of May 1, 2001
THIS INSTRUMENT GRANTS A SECURITY INTEREST BY A PUBLIC UTILITY
THIS INSTRUMENT CONTAINS AFTER-ACQUIRED PROPERTY PROVISIONS
This instrument is being filed pursuant to Nevada Revised Statutes Chapter 105
SECOND SUPPLEMENTAL INDENTURE, dated as of October 1, 2001, between NEVADA POWER COMPANY, a corporation duly organized and existing under the laws of the State of Nevada (herein called the "Company"), having its principal office at 6226 W. Sahara Avenue, P.O. Box 230, Las Vegas, Nevada 89146, and THE BANK OF NEW YORK, a New York banking corporation duly organized and existing under the laws of the State of New York, as Trustee (herein called the "Trustee"), the office of the Trustee at which on the date hereof its corporate trust business is principally administered being 101 Barclay Street, New York, New York 10286.
RECITALS OF THE COMPANY
WHEREAS, the Company has heretofore executed and delivered to the Trustee a General and Refunding Mortgage Indenture dated as of May 1, 2001 (as heretofore supplemented, the "Indenture"), providing for the issuance by the Company from time to time of its bonds, notes or other evidence of indebtedness to be issued in one or more series (in the Indenture and herein called the "Securities") and to provide security for the payment of the principal of and premium, if any, and interest; if any, on the Securities; and
WHEREAS, the Company, in the exercise of the power and authority conferred upon and reserved to it under the provisions of the Indenture and pursuant to appropriate resolutions of the Board of Directors, has duly determined to make, execute and deliver to the Trustee this Second Supplemental Indenture to the Indenture as permitted by Sections 2.01, 3.01 and 14.01 of the Indenture in order to establish the form or terms of, and to provide for the creation and issuance of, a second series of Securities under the Indenture in an initial aggregate principal amount of $140,000,000 (such second series being hereinafter referred to as the "Second Series") and to correct certain defective provisions in the Indenture; and
WHEREAS, all things necessary to make the Securities of the Second Series, when executed by the Company and authenticated and delivered by the Trustee or any Authenticating Agent and issued upon the terms and subject to the conditions hereinafter and in the Indenture set forth against payment therefor the valid, binding and legal obligations of the Company and to make this Second Supplemental Indenture a valid, binding and legal agreement of the Company, have been done;
NOW, THEREFORE, THIS SECOND SUPPLEMENTAL INDENTURE WITNESSETH that, in order to establish the terms of a series of Securities, to correct certain defective provisions in the Indenture and for and in consideration of the premises and of the covenants contained in the Indenture and in this Second Supplemental Indenture and for other good and valuable consideration the receipt and sufficiency of which are hereby acknowledged, it is mutually covenanted and agreed as follows:
ARTICLE ONE
DEFINITIONS AND OTHER PROVISIONS
OF GENERAL APPLICATION
ARTICLE TWO
TITLE, FORM AND TERMS OF THE NOTES
ARTICLE THREE
AMENDMENTS TO THE GENERAL AND REFUNDING MORTGAGE INDENTURE DATED MAY 1, 2001
"(a) all Property Additions to the extent that the same shall have been designated in an Initial Expert's Certificate to be deemed to be Funded Property;"
ARTICLE FOUR
MISCELLANEOUS PROVISIONS
The Trustee makes no undertaking or representations in respect of, and shall not be responsible in any manner whatsoever for and in respect of, the validity or sufficiency of this Second Supplemental Indenture or the proper authorization or the due execution hereof by the Company or for or in respect of the recitals and statements contained herein, all of which recitals and statements are made solely by the Company.
Except as expressly amended and supplemented hereby, the Indenture shall continue in full force and effect in accordance with the provisions thereof and the Indenture is in all respects hereby ratified and confirmed. This Second Supplemental Indenture and all of its provisions shall be deemed a part of the Indenture in the manner and to the extent herein and therein provided.
This Second Supplemental Indenture shall be governed by, and construed in accordance with, the laws of the State of New York (including without limitation Section 5-1401 of the New York General Obligations Law or any successor to such statute).
This Second Supplemental Indenture may be executed in any number of counterparts, each of which so executed shall be deemed to be an original, but all such counterparts shall together constitute but one and the same instrument.
IN WITNESS WHEREOF, the parties hereto have caused this Indenture to be duly executed as of the day and year first above written.
NEVADA POWER COMPANY
By:__________________________________
Name:
Title:
[Seal]
THE BANK OF NEW YORK, as Trustee
By:__________________________________
Name:
Title:
STATE OF NEVADA ) ) COUNTY OF WASHOE ) |
This instrument was acknowledged before me on October __, 2001, by ______________________as_______________________of________________________.
(Seal, if any) ____________________________________ Notary (My commission expires:____________) |
STATE OF ILLINOIS ) ) ss.: COUNTY OF COOK ) |
On the ___ day of October in the year 2001 before me, the undersigned, personally appeared ____________________, personally known to me or proved to me on the basis of satisfactory evidence to be the individual whose name is subscribed to the within instrument and acknowledged to me that he executed the same in his capacity, and that by his signature on the instrument, the individual, or the person upon behalf of which the individual acted, executed the instrument.
Exhibit 4(B)
NEVADA POWER COMPANY
OFFICER'S CERTIFICATE
October 18, 2001
I, the undersigned officer of Nevada Power Company (the "Company"), do hereby certify that I am an Authorized Officer of the Company as such term is defined in the Indenture (as defined herein). I am delivering this certificate pursuant to the authority granted in the Board Resolutions of the Company dated August 7, 2001, and Sections 1.04, 2.01, 3.01, 4.01(a) and 4.02(b)(i) of the General and Refunding Mortgage Indenture dated as of May 1, 2001 (the "Mortgage Indenture"), as supplemented by the First Supplemental Indenture dated as of May 1, 2001, and as further supplemented and amended by the Second Supplemental Indenture dated as of October 1, 2001 (the "Supplemental Indenture"; and collectively with the Mortgage Indenture, as supplemented by said First Supplemental Indenture, the "Indenture"), between the Company and The Bank of New York, as Trustee (the "Trustee"). Terms used herein and not otherwise defined herein shall have the meanings assigned to them in the Indenture unless the context clearly requires otherwise. Based upon the foregoing, I hereby certify on behalf of the Company as follows:
1. The terms and conditions of the Securities described in this Officer's Certificate are as follows (the lettered subdivisions set forth in this Paragraph 1 corresponding to the lettered subdivisions of Section 3.01 of the Mortgage Indenture):
(a) The Securities of the second series to be issued under the Indenture shall be designated "General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003" (the "Series B Notes").
(b) There shall be no limit upon the aggregate principal amount of the Series B Notes that may be authenticated and delivered under the Indenture. The Series B Notes shall be initially authenticated and delivered in the aggregate principal amount of $140,000,000.
(d) The Series B Notes shall mature and the principal thereof shall be due and payable together with all accrued and unpaid interest thereon on October 15, 2003.
(f) The Corporate Trust Office of The Bank of New York in New York, New York shall be the place at which (i) the principal of, premium and interest on, the Series B Notes shall be payable, (ii) registration of transfer of the Series B Notes may be effected, (iii) exchanges of the Series B Notes may be effected and (iv) notices and demands to or
The Calculation Agent for the Series B Notes shall be The Bank of New York, or its successor as Calculation Agent. At any time, the Company may designate a successor Calculation Agent, who may be any person or entity who is eligible to be a successor Trustee or co-trustee under the Indenture or who (a) is in fact independent, (b) does not have any direct material financial interest in the Company or in any affiliate of the Company, (c) is not connected with the Company as an officer, employee, promoter, underwriter, partner, director or person performing similar functions, (d) is selected by an Authorized Officer and (e) is approved by the Trustee in the exercise of reasonable care.
(g) Not applicable.
(h) Not applicable.
(i) The Series B Notes are issuable only in denominations of $100,000 and integral multiples of $1,000 in excess thereof.
(j) Not applicable.
(k) Not applicable.
(l) Not applicable.
(m) See subsection (e) above.
(n) Not applicable.
(o) Not applicable.
(p) Not applicable.
(i) the Global Certificate may be transferred in whole, and appropriate registration of transfer effected, if such transfer is by such nominee to the Depositary, or by the Depositary to another nominee thereof, or by any nominee of the Depositary to any other nominee thereof, or by the Depositary or any nominee thereof to any successor securities depositary or any nominee thereof; and
(ii) the Global Certificate may be exchanged for Series B Notes in the form of definitive certificates, registered in the respective names of the beneficial owners thereof, and thereafter shall be transferable without restriction, if:
(B) the Company shall have delivered to the Trustee a Company Order to the effect that the Company has elected to terminate the book-entry system; or
(C) an Event of Default shall have occurred and be continuing.
Unless and until definitive, fully registered certificates
shall have been issued to beneficial owners as provided in subclause
(ii) of this clause (g) of Paragraph 1 hereof:
(a) the provisions of this clause (q) shall be in full force and effect;
(b) the Company and the Trustee and any agent of either shall be entitled to deal with the Depositary for all purposes of the Indenture and such Series B Notes (including payment of principal of, and premium and interest thereon, the giving of notice and receiving approvals, votes or consents thereunder) as the Holder of such Securities and the sole holder of the Global Certificate and shall have no obligation to the beneficial owners of such Securities;
(c) to the extent that the provisions of clause
(q) of paragraph 1 conflicts with any other provisions of the
Indenture or the Series B Notes, the provisions of this
clause (q) of Paragraph 1 shall control; and
(d) the rights of such beneficial owners shall be exercised only through the Depositary and shall be limited to those established by law and agreements between such beneficial owners or of any agent member of, or direct or indirect participants in, the Depositary and the Depositary or the depositary participants.
The Depositary will make book-entry transfers among depositary participants and receive and transmit payments of principal, premium and interest, if any, to such depositary participants.
Notwithstanding the foregoing, with respect to any Global Certificate, nothing contained herein or in the Indenture shall prevent the Company, the Trustee or any agent of the Company or the Trustee, from giving effect to any written certification, proxy or other authorization furnished by the Depositary (or its nominee), as a Holder, with respect to such Global Certificate or impair, as between such Depositary and the related beneficial owner, the operation of customary practices governing the exercise of rights of the Depositary (or its nominee) as Holder of such global certificate. Except for the Global Certificate, any and all of the Series B Notes shall be in the form of a non-global, definitive physical certificate.
"IN CONNECTION WITH ANY TRANSFER, THE HOLDER WILL DELIVER TO THE COMPANY AND THE SECURITIES REGISTRAR AND/OR TRANSFER AGENT SUCH CERTIFICATES AND OTHER INFORMATION AS THE COMPANY AND SUCH SECURITIES REGISTRAR AND/OR TRANSFER AGENT MAY REASONABLY REQUIRE TO CONFIRM THAT THE TRANSFER COMPLIES WITH THE FOREGOING RESTRICTIONS."
(r) Not applicable.
(s) The Series B Notes have not been registered under the Securities Act and may not be offered, sold or otherwise transferred in the absence of such registration or an applicable exemption therefrom. No service charge shall be made for the registration of transfer or exchange of the Series B Notes, or any Tranche thereof; provided, however,
that the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection with the exchange or transfer.
(t) For purposes of the Series B Notes, "Business Day" shall mean any day, other than Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York.
(u) Notwithstanding the provisions of Section 9.01 of the Indenture, no Series B Note shall be deemed to have been paid, and the indebtedness of the Company in respect thereof deemed to have been satisfied and discharged as contemplated therein, unless the Company shall have delivered to the Trustee either:
(i) an opinion of counsel in the United States reasonably acceptable to the Trustee confirming that (A) the Company has received from, or there has been published by, the Internal Revenue Service a ruling or (B) since the date of the Indenture, there has been a change in the applicable federal income tax law, in either case to the effect that, and based thereon such opinion of counsel shall confirm that, the Holders of the outstanding Bonds will not recognize income, gain or loss for federal income tax purposes as a result of such defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such defeasance had not occurred; or
(ii) (A) an instrument wherein the Company, notwithstanding the satisfaction and discharge of its Indebtedness in respect of the Bonds, shall assume the obligation (which shall be absolute and unconditional) to irrevocably deposit with the Trustee such additional sums of money, if any, or additional Government Obligations, if any, or any combination thereof, at such time or times, as shall be necessary, together with the money and/or Government Obligations theretofore so deposited, to pay when due the principal of and premium, if any, and interest due and to become due on such bonds or portions thereof; provided, however, that such instrument may state that the obligation of the Company to make additional deposits as aforesaid shall be subject to the delivery to the Company by the Trustee of a notice asserting the deficiency accompanied by an opinion of an independent public accountant of nationally recognized standing showing the calculation thereof; and (B) an opinion of tax counsel in the United States reasonably acceptable to the Trustee to the effect that the Holders of the outstanding Bonds will not recognize income, gain or loss for federal income tax purposes as a result of such defeasance and will be subject to federal income tax on the same amounts, in the same manner and at the same times as would have been the case if such defeasance had not occurred.
2. The undersigned has read all of the covenants and conditions contained in the Indenture, and the definitions in the Indenture relating thereto, relating to the issuance of the Series B Notes and in respect of compliance with which this certificate is made.
The statements contained in this certificate are based upon the familiarity of the undersigned with the Indenture, the documents accompanying this certificate, and upon discussions by the undersigned with officers and employees of the Company familiar with the matters set forth herein.
In the opinion of the undersigned, he has made such examination or investigation as is necessary to enable him to express an informed opinion as to whether or not such covenants and conditions have been complied with.
In the opinion of the undersigned, such conditions and covenants have been complied with.
IN WITNESS WHEREOF, the undersigned has executed this Officer's Certificate as of the date first written above.
By: _________________________________________ Richard K. Atkinson Treasurer and Investor Relations Officer
Acknowledged and Received on
October ___, 2001
THE BANK OF NEW YORK,
as Trustee
By: ___________________________________________ Name: ___________________________________________ Title:___________________________________________
Form of Series B Notes
Form of Letter to be Delivered by Accredited Investors
Nevada Power Company
P.O. Box 230
6226 W. Sahara Avenue
Las Vegas, Nevada 89146
Dear Sirs:
We are delivering this letter in connection with an offering of General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003, (the "Securities") of Nevada Power Company, a Nevada corporation (the "Company"), all as described in the Confidential Offering Memorandum (the "Offering Memorandum") relating to the offering.
We hereby confirm that:
(i) we are an "accredited investor" within the meaning of Rule
501(a)(1), (2) or (3) under the Securities Act of 1933, as amended (the
"Securities Act"), or an entity in which all of the equity owners are
accredited investors within the meaning of Rule 501(a)(1), (2) or (3)
under the Securities Act (an "Institutional Accredited Investor");
(ii) (A) any purchase of the Securities by us will be for our own account or for the account of one or more other Institutional Accredited Investors or as fiduciary for the account of one or more trusts, each of which is an "accredited investor" within the meaning of Rule 501(a)(7) under the Securities Act and for each of which we exercise sole investment discretion or (B) we are a "bank", within the meaning of Section 3(a)(2) of the Securities Act, or a "savings and loan association" or other institution described in Section 3(a)(5)(A) of the Securities Act that is acquiring the Securities as fiduciary for the account of one or more institutions for which we exercise sole investment discretion,
(iii) in the event that we purchase any of the Securities, we will acquire Securities having a minimum purchase price of not less than $100,000 for our own account or for any separate account for which we are acting;
(iv) we have such knowledge and experience in financial and business matters that we are capable of evaluating the merits and risks of purchasing the Securities;
(v) we are not acquiring the Securities with a view to distribution thereof or with any present intention of offering or selling any of the Securities, except inside the United States in accordance with Rule 144A under the Securities Act or outside the United States under Regulation S under the Securities Act, as provided below; provided
that the disposition of our property and the property of any accounts for which we are acting as fiduciary shall remain at all times within our control; and
(vi) we have received a copy of the Offering Memorandum relating to the offering of the Securities and acknowledge that we have had access to financial and other information, and have been afforded the opportunity to ask questions of representatives of the Company and receive answers thereto, as we deem necessary in connection with our decision to purchase the Securities.
We understand that the Securities are being offered in a transaction not involving any public offering within the United States within the meaning of the Securities Act and that the Securities have not been registered under the Securities Act, and we agree, on our own behalf and on behalf of each account for which we acquire any Securities, that if in the future we decide to resell, pledge or otherwise transfer the Securities, the Securities may be offered, resold, pledged or otherwise transferred only (i) in the United States to a person who we reasonably believe is a "qualified institutional buyer" (as defined in Rule 144A under the Securities Act) in a transaction meeting the requirements of Rule 144A, (ii) outside the United States in a transaction in accordance with Rule 904 under the Securities Act, (iii) under an exemption from registration under the Securities Act provided by Rule 144 thereunder (if available) or (iv) under an effective registration statement under the Securities Act, in each of cases (i) through (iv), subject to any applicable securities laws of any State of the United States or any other applicable jurisdiction. We understand that the registrar and transfer agent for the Securities will not be required to accept for registration of transfer any Securities acquired by us, except upon presentation of evidence satisfactory to the Company and the transfer agent that the foregoing restrictions on transfer have been complied with.
We acknowledge that you, the Company and others will rely upon our confirmations, acknowledgements and agreements set forth herein, and we agree to notify you promptly in writing if any of our representations or warranties herein ceases to be accurate and complete.
THIS LETTER SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF THE STATE OF NEW YORK, WITHOUT REGARD TO PRINCIPLES OF CONFLICTS OF LAWS.
Date:______________________ _________________________________ (Name of Purchaser) By: ______________________________ Name: Title: Address: |
Exhibit 4(c)
(See legends at the end of this Security for restrictions on transfer and change of form)
NEVADA POWER COMPANY
General and Refunding Mortgage Notes, Floating Rate, Series B, due October 15, 2003
Original Interest Accrual Date: October 18, 2001 Redeemable: Yes No X ---- -- Stated Maturity: October 15, 2003 Redemption Date: N/A Interest Rate: Rate of Interest Redemption Price: N/A (as defined herein) Interest Payment Dates: January 15, April 15, July 15, October 15 Regular Record Dates: January 1, April 1, July 1, October 1 |
This Security is not a Discount Security within the meaning of the within-mentioned Indenture.
Principal Amount Registered No. R-1
$140,000,000 CUSIP 641423 BB3
NEVADA POWER COMPANY, a corporation duly organized and existing under the laws of the State of Nevada (herein called the "Company," which term includes any successor corporation under the Indenture referred to below), for value received, hereby promises to pay to
****Cede & Co.****
, or registered assigns, the principal sum of ONE HUNDRED FORTY MILLION DOLLARS on the Stated Maturity specified above, and to pay interest thereon from the Original Interest Accrual Date specified above or from the most recent Interest Payment Date to which interest has been paid or duly provided for, quarterly in arrears on the Interest Payment Dates specified above in each year, commencing with the Interest Payment Date next succeeding the Original Interest Accrual Date specified above, and at Maturity, at the Interest Rate per annum specified herein, until the principal hereof is paid or duly provided for. The interest so payable, and paid or duly provided for, on any Interest Payment Date shall, as provided in such Indenture, be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on the Regular Record Date specified above (whether or not a Business Day) next preceding such Interest Payment Date. Notwithstanding the foregoing, interest payable at Maturity shall be paid to the Person to whom principal shall be paid. Except as otherwise provided in said Indenture, any such interest not so paid or duly provided for shall forthwith cease to be payable to the Holder on such Regular Record Date and may either be paid to the Person in whose name this Security (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date for the payment of such Defaulted Interest to be fixed by the Trustee, notice of which shall be given to Holders of Securities of this series not less than 15 days prior to such Special Record Date, or be paid at any time in any other lawful manner not inconsistent with the
requirements of any securities exchange on which the Securities of this series may be listed, and upon such notice as may be required by such exchange, all as more fully provided in said Indenture.
Payment of the principal of and premium, if any, on this Security and interest hereon at Maturity shall be made upon presentation of this Security at the office of the Corporate Trust Administration of The Bank of New York located at 101 Barclay Street, New York, New York 10286 or at such other office or agency as may be designated for such purpose by the Company from time to time. Payment of interest on this Security (other than interest at Maturity) shall be made by check mailed to the address of the Person entitled thereto as such address shall appear in the Security Register, except that if such Person shall be a securities depositary, such payment may be made by such other means in lieu of check, as shall be agreed upon by the Company, the Trustee and such Person. Payment of the principal of and premium, if any, and interest on this Security, as aforesaid, shall be made in such coin or currency of the United States of America as at the time of payment shall be legal tender for the payment of public and private debts.
If any Interest Payment Date for this Note (other than an Interest Payment Date at Maturity) would otherwise be a day that is not a Business Day (as defined herein), such Interest Payment Date shall be postponed until the next succeeding Business Day unless such Business Day falls in the next calendar month, in which case such Interest Payment Date shall be the next preceding Business Day. If the Maturity of this Note falls on a day that is not a Business Day, the payment of principal and interest will be made on the next succeeding Business Day, and no interest on such payment shall accrue for the period from and after such Stated Maturity, except as otherwise expressly provided for herein.
This Security is one of a duly authorized issue of securities of the Company (herein called the "Securities"), issued and issuable in one or more series under and equally secured by a General and Refunding Mortgage Indenture, dated as of May 1, 2001 (such Indenture as originally executed and delivered and as supplemented or amended from time to time thereafter, together with any constituent instruments establishing the terms of particular Securities, being herein called the "Indenture"), between the Company and The Bank of New York, trustee (herein called the "Trustee," which term includes any successor trustee under the Indenture), to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the property mortgaged, pledged and held in trust, the nature and extent of the security and the respective rights, limitations of rights, duties and immunities of the Company, the Trustee and the Holders of the Securities thereunder and of the terms and conditions upon which the Securities are, and are to be, authenticated and delivered and secured. The acceptance of this Security shall be deemed to constitute the consent and agreement by the Holder hereof to all of the terms and provisions of the Indenture. This Security is one of the series designated above.
The period beginning on, and including, October 18, 2001 and ending on, but excluding, the first Interest Payment Date and each successive period beginning on, and including, an Interest Payment Date and ending on, but excluding, the next succeeding Interest Payment Date is herein called an "Interest Period."
The rate of interest payable from time to time in respect of this Note (the "Rate of Interest") will be a floating rate determined by reference to LIBOR, determined as described below, plus a margin of 1.65% per annum. All percentages resulting from any calculation on this Note will be rounded to the nearest one hundredth-thousandth of a percentage point, with five one millionths of a percentage point rounded upwards (e.g., 9.876545% (or .09876545) would be rounded to 9.87655% (or .0987655)), and all dollar amounts used in or resulting from such calculation on the Notes will be rounded to the nearest cent (with one-half cent being rounded upward).
(a) At approximately 11:00 a.m. (London time) on the second day on which commercial banks are open for business (including dealings in U.S. Dollar deposits) in London (or, for purposes of paragraph (c)(ii) below, New York) prior to the commencement of the Interest Period for which such rate will apply (each such day an "Interest Determination Date"), The Bank of New York, or its successor in this capacity (the "Calculation Agent"), will calculate the Rate of Interest for such Interest Period as, subject to the provisions described below, the rate per annum equal to 1.65% above the rate appearing on the British Bankers Association Telerate Page 3750 (or such other page as may replace that page on the British Bankers Association Telerate Service) for three-month U.S. dollar deposits in the London inter-bank market on such Interest Determination Date.
(b) If on any Interest Determination Date an appropriate rate cannot be determined from the British Bankers Association Telerate Service, the Rate of Interest for the next Interest Period shall, subject to the provisions described below, be the rate per annum that the Calculation Agent certifies to be 1.65% per annum above the arithmetic mean of the offered quotations, as communicated to and at the request of the Calculation Agent by not less than two major banks in London selected by the Calculation Agent (the "Reference Banks," which expression shall include any successors nominated by the Calculation Agent), to leading banks in London by the principal London offices of the Reference Banks for three-month U.S. dollar deposits in the London inter-bank market as at 11:00 a.m. (London time) on such Interest Determination Date.
(c) If on any Interest Determination Date fewer than two of such offered rates are available, the Rate of Interest for the next Interest Period shall be whichever is the higher of:
(i) the Rate of Interest in effect for the last preceding Interest Period to which (a) or (b) above shall have applied; and
(ii) the Reserve Interest Rate. The "Reserve Interest Rate" shall be the rate per annum which the Calculation Agent determines to be 1.65% per annum above either (1) the arithmetic mean of the U.S. dollar offered rates which New York City banks selected by the Calculation Agent are or were quoting, on the relevant Interest Determination Date, for three-month deposits to the Reference Banks or those of them (being at least two in number) to which such quotations are or were, in the opinion of the Calculation Agent, being so made, or (2) in the event that the Calculation Agent can determine no such arithmetic mean, the arithmetic mean of the U.S. dollar offered rates which at least two New York City banks selected by the Calculation Agent are or were quoting on such Interest Determination Date to leading European banks for a period of three months; provided, however, that if the banks selected as aforesaid by the Calculation Agent are not quoting as mentioned above, the Rate of Interest shall be the Rate of Interest specified in (i) above.
The Calculation Agent shall, as soon as practicable after 11:00 a.m. (London time) on each Interest Determination Date, determine the Rate of Interest and calculate the amount of interest payable in respect of the following Interest Period (the "Interest Amount"). The Interest Amount shall be calculated by applying the Rate of Interest to the principal amount of each Note outstanding at the commencement of the Interest Period, multiplying each such amount by the actual number of days in the Interest Period concerned (which actual number of days shall include the first day but exclude the last day of such Interest Period) divided by 360 and rounding the resultant figure upwards to the nearest cent (half a cent being rounded upwards). The determination of the Rate of Interest and the Interest Amount by the Calculation Agent shall (in the absence of willful default, bad faith or manifest error) be final and binding on all parties.
Notwithstanding anything herein to the contrary, the interest rate on the Notes shall in no event be higher than the maximum rate permitted by New York law, as the same may be modified by United States law of general application.
Interest shall cease to accrue on this Note on Maturity unless, upon presentation of this Note, payment of principal is improperly withheld or refused, in which case, interest shall continue to accrue.
So long as any of this Note remains outstanding, the Company shall maintain under appointment a Calculation Agent, which shall initially be the Trustee, to calculate the Rate of Interest payable on this Note in respect of each Interest Period. If the Calculation Agent shall fail to establish the Rate of Interest for any Interest Period, or if the Company shall remove the Calculation Agent, the Company shall appoint another commercial or investment bank to act as the Calculation Agent. The Company may change the Calculation Agent without notice.
All certificates, communications, opinions, determinations, calculations, quotations and decisions given, expressed, made or obtained for the purposes of the provisions hereof relating to the payment and calculation of interest on this Note by the Calculation Agent shall (in the absence of willful default, bad faith or manifest error) be binding on the Company, the Calculation Agent and all of the holders and owners of beneficial interests in this Note, and no liability shall (in the absence of gross negligence, bad faith or willful misconduct) attach to the Calculation Agent in connection with the exercise or non-exercise by it of its powers, duties and discretions.
The Securities of this series will not be entitled to the benefit of any sinking fund or other voluntary or mandatory redemption provisions.
If an Event of Default shall occur and be continuing, the principal of this Security may be declared due and payable in the manner and with the effect provided in the Indenture.
The Indenture permits, with certain exceptions as therein provided, the Trustee to enter into one or more supplemental indentures for the purpose of adding any provisions to, or changing in any manner or eliminating any of the provisions of, the Indenture with the consent of the Holders of not less than a majority in aggregate principal amount of the Securities of all series then Outstanding under the Indenture, considered as one class; provided, however, that if there shall be Securities of more than one series Outstanding under the Indenture and if a proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such series, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all series so directly affected, considered as one class, shall be required; and provided, further, that if the Securities of any series shall have been issued in more than one Tranche and if the proposed supplemental indenture shall directly affect the rights of the Holders of Securities of one or more, but less than all, of such Tranches, then the consent only of the Holders of a majority in aggregate principal amount of the Outstanding Securities of all Tranches so directly affected, considered as one class, shall be required; and provided, further, that the Indenture permits the Trustee to enter into one or more supplemental indentures for limited purposes without the consent of any Holders of Securities. The Indenture also contains provisions permitting the Holders of a majority in principal amount of the Securities then Outstanding, on behalf of the Holders of all Securities, to waive compliance by the Company with certain provisions of the Indenture and certain past defaults under the Indenture and their consequences. Any such consent or waiver by the Holder of this Security shall be conclusive and binding upon such Holder and upon all future Holders of this Security and of any Security issued upon the registration of transfer hereof or in exchange therefor or in lieu hereof, whether or not notation of such consent or waiver is made upon this Security.
As provided in the Indenture and subject to certain limitations therein set forth, this Security or any portion of the principal amount hereof will be deemed to have been paid for all purposes of the Indenture and to be no longer Outstanding thereunder, and, at the election of the Company, the Company's entire indebtedness in respect thereof will be satisfied and discharged, if there has been irrevocably deposited with the Trustee or any Paying Agent (other than the Company), in trust, money in an amount which will be sufficient and/or Eligible Obligations, the principal of and interest on which when due, without regard to any reinvestment thereof, will provide moneys which, together with moneys so deposited, will be sufficient to pay when due the principal of and interest on this Security when due.
As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Security is registrable in the Security Register, upon surrender of this Security for registration of transfer at the Corporate Trust Office of The Bank of New York in New York, New York or such other office or agency as may be designated by the Company from time to time, duly endorsed by, or accompanied by a written instrument of transfer in form satisfactory to the Company and the Security Registrar duly executed by, the Holder hereof or his attorney duly authorized in writing, and thereupon one or more new Securities of this series of authorized denominations and of like tenor and aggregate principal amount, will be issued to the designated transferee or transferees.
The Securities of this series are issuable only as registered Securities, without coupons, and in denominations of $100,000 and integral multiples of $1000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, Securities of this series are exchangeable for a like aggregate principal amount of Securities of the same series and Tranche, of any authorized denominations, as requested by the Holder surrendering the same, and of like tenor upon surrender of the Security or Securities to be exchanged at the office of The Bank of New York in New York, New York or such other office or agency as may be designated by the Company from time to time.
No service charge shall be made for any such registration of transfer or exchange, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection therewith.
Prior to due presentment of this Security for registration of transfer, the Company, the Trustee and any agent of the Company or the Trustee may treat the Person in whose name this Security is registered as the absolute owner hereof for all purposes, whether or not this Security be overdue, and neither the Company, the Trustee nor any such agent shall be affected by notice to the contrary.
The Securities shall be governed by and construed in accordance with the laws of the State of New York.
As used herein, "Business Day" shall mean any day, other than a Saturday or Sunday, on which commercial banks and foreign exchange markets are open for business, including dealings in deposits in U.S. dollars, in New York. All other terms used in this Security which are defined in the Indenture shall have the meanings assigned to them in the Indenture.
As provided in the Indenture, no recourse shall be had for the payment of the principal of or premium, if any, or interest on any Securities, or any part thereof, or for any claim based thereon or otherwise in respect thereof, or of the indebtedness represented thereby, or upon any obligation, covenant or agreement under the Indenture, against, and no personal liability whatsoever shall attach to, or be incurred by, any incorporator, stockholder, officer or director, as such, past, present or future of the Company or of any predecessor or successor corporation (either directly or through the Company or a predecessor or successor corporation), whether by virtue of any constitutional provision, statute or rule of law, or by the enforcement of any assessment or penalty or otherwise; it being expressly agreed and
understood that the Indenture and all the Securities are solely corporate obligations and that any such personal liability is hereby expressly waived and released as a condition of, and as part of the consideration for, the execution of the Indenture and the issuance of the Securities.
Unless the certificate of authentication hereon has been executed by the Trustee or an Authenticating Agent by manual signature, this Security shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.
[The remainder of this page is intentionally left blank.]
IN WITNESS WHEREOF, the Company has caused this instrument to be duly executed.
NEVADA POWER COMPANY
By: ________________________________________
Richard K. Atkinson
Treasurer and Investor Relations Officer
CERTIFICATE OF AUTHENTICATION
This is one of the Securities of the series designated therein referred to in the within-mentioned Indenture.
Dated: October ____, 2001
THE BANK OF NEW YORK, as Trustee
By: ________________________________________
Authorized Signatory
[LEGENDS FOR GLOBAL CERTIFICATE]
Unless this certificate is presented by an authorized representative of The Depository Trust Company, a New York corporation ("DTC"), to the Company or its agent for registration of transfer, exchange, or payment, and any certificate issued is registered in the name of Cede & Co. or in such other name as is requested by an authorized representative of DTC (and any payment is made to Cede & Co. or to such other entity as is requested by an authorized representative of DTC), ANY TRANSFER, PLEDGE, OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY OR TO ANY PERSON IS WRONGFUL inasmuch as the registered owner hereof, Cede & Co., has an interest herein.
This Security may not be transferred or exchanged, nor may any purported transfer be registered, except (i) this Security may be transferred in whole, and appropriate registration of transfer effected, if such transfer is by Cede & Co., as nominee for The Depository Trust Company (the "Depositary"), to the Depositary, or by the Depositary to another nominee thereof, or by any nominee of the Depositary to any other nominee thereof, or by the Depositary or any nominee thereof to any successor securities depositary or any nominee thereof; and (ii) this Security may be exchanged for definitive Securities registered in the respective names of the beneficial holders hereof, and thereafter shall be transferable without restrictions if: (A) the Depositary, or any successor securities depositary, shall have notified the Company and the Trustee that (i) it is unwilling or unable to continue to act as securities depositary with respect to the Securities, (ii) has ceased to be qualified to act as such, or (iii) has ceased to be a clearing agency registered under the Securities Exchange Act of 1934 and the Trustee shall not have been notified by the Company within ninety (90) days of the identity of a successor securities depositary with respect to the Securities; (B) the Company shall have delivered to the Trustee a Company Order to the effect that the Company has elected to terminate the book-entry system; or (C) an Event of Default shall have occurred and be continuing.
[LEGENDS FOR RESTRICTED SECURITIES]
THIS SECURITY (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER THE UNITED STATES SECURITES ACT OF 1933 (THE "SECURITIES ACT"), AND THIS SECURITY MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM. EACH PURCHASER OF THIS SECURITY MAY BE RELYING ON THE EXEMPTION FROM THE PROVISIONS OF SECTION 5 OF THE SECURITIES ACT PROVIDED BY RULE 144A THEREUNDER.
THE HOLDER OF THIS SECURITY AGREES FOR THE BENEFIT OF THE COMPANY THAT
(A) THIS SECURITY MAY BE OFFERED, RESOLD, PLEDGED OR OTHERWISE TRANSFERRED ONLY
(I) IN THE U.S. TO A PERSON WHOM THE SELLER REASONABLY BELIEVES IS A QUALIFIED
INSTITUTIONAL BUYER (AS DEFINED IN RULE 144A UNDER THE SECURITIES ACT) IN A
TRANSACTION MEETING THE REQUIREMENTS OF RULE 144A, (II) OUTSIDE THE U.S. IN A
TRANSACTION IN ACCORDANCE WITH RULE 904 UNDER THE SECURITIES ACT, (III) PURSUANT
TO AN EXEMPTION FROM REGISTRATION UNDER THE SECURITIES ACT PROVIDED BY RULE 144
THEREUNDER (IF AVAILABLE) OR (IV) PURSUANT TO AN EFFECTIVE REGISTRATION
STATEMENT UNDER THE SECURITIES ACT, IN EACH OF CASES (I) THROUGH (IV) IN
ACCORDANCE WITH ANY APPLICABLE SECURITIES LAWS OF ANY STATE OF THE UNITED
STATES, AND (B) THE HOLDER WILL, AND EACH SUBSEQUENT HOLDER IS REQUIRED TO,
NOTIFY ANY PURCHASER OF THIS SECURITY FROM IT OF THE RESALE RESTRICTIONS
REFERRED TO IN (A) ABOVE.
To assign this Security, fill in the form below:
I or we assign and transfer this Security to
and irrevocably appoint____________ agent to transfer this Security on the books of the Company. The agent may substitute another to act for him.
Date: _____________________ Your Signature:___________________
Signature Guarantee: ______________________________________________________
(Signature must be guaranteed)
The signature(s) should be guaranteed by an eligible guarantor institution (banks, stockbrokers, savings and loan associations and credit unions with membership in an approved signature guarantee medallion program), pursuant to S.E.C. Rule 17 Ad-15.
In connection with any transfer or exchange of any of the Securities evidenced by this certificate occurring prior to the date that is two years after the later of the date of original issuance of such Securities and the last date, if any, on which such Securities were owned by the Company or any Affiliate of the Company, the undersigned confirms that such Securities are being:
CHECK ONE BOX BELOW:
______ 1 acquired for the undersigned's own account, without present intention to transfer; or ______ 2 transferred to the Company; or ______ 3 transferred pursuant to and in compliance with |
Rule 144A under the Securities Act of 1933, as amended (the "Securities Act"); or
______ 4 transferred pursuant to an effective registration statement under the Securities Act; or ______ 5 transferred to an institutional "accredited investor" (as defined in Rule 501 (a) (1), (2), (3) or (7) under the Securities Act) upon delivery of accredited investor's letter attached as Exhibit B to Officer's Certificate; or ______ 6 transferred pursuant to another available exemption from the registration requirements of the Securities Act of 1933. |
Unless one of the above items is checked, the Securities Registrar will refuse to register any of the Securities evidenced by this certificate in the name of any person other than the registered Holder thereof; provided, however, that if item (5) or (6) is checked, the Securities Registrar or the Company may require, prior to registering any such transfer of the Securities, in their sole discretion, such legal opinions, certifications and other information as the Securities Registrar or the Company may reasonably request to confirm that such transfer is being made pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act of 1933, such as the exemption provided by Rule 144 under such Act.
______________________________ Signature Signature Guarantee: _____________________________ ______________________________ (Signature must be guaranteed) Signature |
The signature(s) should be guaranteed by an eligible guarantor institution (banks, stockbrokers, savings and loan associations and credit unions with membership in an approved signature guarantee medallion program), pursuant to S.E.C. Rule 17 Ad-15.
TO BE COMPLETED BY PURCHASER IF (1) OR (3) ABOVE IS CHECKED.
The undersigned represents and warrants that it is purchasing this Security for its own account or an account with respect to which it exercises sole investment discretion and that it and any such account is a "qualified institutional buyer" within the meaning of Rule 144A under the Securities Act of 1933, as amended, and is aware that the sale to it is being made in reliance on Rule 144A and acknowledges that it has received such information regarding the Company as the undersigned has requested pursuant to Rule 144A or has determined not to request such information and that it is aware that the transferor is relying upon the undersigned's foregoing representations in order to claim the exemption from registration provided by Rule 144A.
EXHIBIT 4(D)
NEVADA POWER COMPANY
TO
BANKERS TRUST COMPANY
as Trustee
TWENTY-EIGHTH SUPPLEMENTAL INDENTURE
Dated as of July 1, 2001
THIS TWENTY-EIGHTH SUPPLEMENTAL INDENTURE dated as of July 1, 2001, made by and between NEVADA POWER COMPANY (formerly DESERT Merger Sub, Inc., a wholly owned subsidiary of Sierra Pacific Resources and successor by merger to Nevada Power Company), a corporation duly organized and existing under the laws of the State of Nevada (the "Company"), having its principal place of business at Las Vegas, Nevada, party of first part, and BANKERS TRUST COMPANY (successor to First Interstate Bank of Nevada, N.A., formerly First National Bank of Nevada, Reno, Nevada), a banking corporation duly organized and existing under and by virtue of the banking laws of the State of New York, having its principal place of business at Four Albany Street, New York, New York, (hereinafter sometimes called the "Trustee"), party of the second part;
WHEREAS, the Company has heretofore executed and delivered to the Trustee its Indenture of Mortgage and Deed of Trust ("Original Indenture") dated October 1, 1953, to secure the payment of the principal of and interest and premium, if any, on all bonds of the Company at any time outstanding thereunder; and, for the purpose of amending and supplementing and further confirming the lien of the Original Indenture, has heretofore executed and delivered the following Supplemental Indentures and Instrument of Further Assurance, each dated as hereinafter set forth:
Instrument Date ---------- ---- First Supplemental Indenture August 1, 1954 Instrument of Further Assurance as of April 1, 1956 Second Supplemental Indenture September 1, 1956 Third Supplemental Indenture as of May 1, 1959 Fourth Supplemental Indenture as of October 1, 1960 Fifth Supplemental Indenture as of December 1, 1961 Sixth Supplemental Indenture as of October 1, 1963 Seventh Supplemental Indenture as of August 1, 1964 Eighth Supplemental Indenture as of April 1, 1968 Ninth Supplemental Indenture as of October 1, 1969 Tenth Supplemental Indenture as of October 1, 1970 Eleventh Supplemental Indenture as of November 1, 1972 Twelfth Supplemental Indenture as of December 1, 1974 Thirteenth Supplemental Indenture as of October 1, 1976 Fourteenth Supplemental Indenture as of May 1, 1977 Fifteenth Supplemental Indenture as of September 1, 1978 Sixteenth Supplemental Indenture as of December 1, 1981 Seventeenth Supplemental Indenture as of August 1, 1982 Eighteenth Supplemental Indenture as of November 1, 1986 Nineteenth Supplemental Indenture as of October 1, 1989 Twentieth Supplemental Indenture as of May 1, 1992 Twenty-First Supplemental Indenture as of June 1, 1992 Twenty-Second Supplemental Indenture as of June 1, 1992 Twenty-Third Supplemental Indenture as of October 1, 1992 Twenty-Fourth Supplemental Indenture as of October 1, 1992 -2- |
Twenty-Fifth Supplemental Indenture as of January 1, 1993 Twenty-Sixth Supplemental Indenture as of May 1, 1995 Twenty-Seventh Supplemental Indenture as of July 1, 1999 |
the Original Indenture, as amended and supplemented by the instruments listed above and as to be supplemented by this Twenty-Eighth Supplemental Indenture and as it may from time to time be amended or supplemented pursuant to the provisions thereof, is hereinafter sometimes called the "Indenture";
WHEREAS, the Original Indenture, the Instrument of Further Assurance and the Supplemental Indentures listed in the foregoing paragraph were recorded in Offices of the County Recorders of the States of Nevada, Arizona and Utah as set forth in Exhibit A attached hereto and incorporated herein by reference;
WHEREAS, in addition to twenty-two series of Bonds heretofore issued under the Indenture, all of which have been retired, there have heretofore been issued under the Indenture First Mortgage Bonds of series and in principal amounts as follows:
Title Issued Outstanding ----- ------ ----------- 7 5/8% Bonds of Series L Due 2002 $15,000,000 $15,000,000 6.70% Bonds of Series V due 2022 $105,000,000 $105,000,000 6.60% Bonds of Series W due 2019 $39,500,000 $39,500,000 7.20% Bonds of Series X Due 2022 $78,000,000 $78,000,000 8.50% Bonds of Series Z due 2023 $45,000,000 $45,000,000 |
WHEREAS, the Company in the exercise of the power and authority conferred upon and reserved to it under the provisions of the Indenture, and pursuant to a resolution duly adopted by its Board of Directors, has resolved and determined to create and issue two new series of Bonds to be designated, respectively, "First Mortgage Bonds, Series BB Due 2020" (hereinafter referred to as "Bonds of Series BB") and "First Mortgage Bonds, Series CC Due 2009" (hereinafter referred to as "Bonds of Series CC") and to make, execute and deliver to the Trustee this Twenty-Eighth Supplemental Indenture, in the form hereof, as a further supplement to the Indenture; and
WHEREAS, all conditions and requirements necessary to make this Twenty-Eighth Supplemental Indenture a valid, binding and legal instrument have been done, performed and fulfilled, and the execution and delivery hereof have been in all respects duly authorized;
NOW, THEREFORE, in consideration of the premises and of the sum of one dollar ($1), lawful money of the United States of America, duly paid by the Trustee to the Company, and of other good and valuable consideration, receipt whereof is hereby acknowledged, and for the purpose of securing the due and punctual payment of the principal of and interest on all Bonds issued and outstanding from time to time under the Indenture, including specifically, but without limitation, Bonds of Series BB and Bonds of Series CC to be issued pursuant to this Twenty-Eighth Supplemental Indenture, and to secure the performance and observation of each and every
of the covenants and conditions contained in the Indenture, and without in any way limiting the generality or effect of the Indenture insofar as by any provision thereof any of the properties therein or hereinafter referred to are now subject, or are now intended to be subject to the lien and operation thereof, but to such extent confirming such lien and operation, the Company has executed and delivered this Twenty-Eighth Supplemental Indenture and has granted, bargained, sold, warranted, aliened, remised, released, conveyed, assigned, transferred, mortgaged, pledged, set over and confirmed, and by these presents does grant, bargain, sell, warrant, alien, remise, release, convey, assign, transfer, mortgage, pledge, set over and confirm, unto Bankers Trust Company, as Trustee aforesaid, and to its successors in the trust hereby created, in trust upon the conditions, terms and provisions of the Indenture, subject to the encumbrances and other matters permitted by the Indenture, all and singular the following premises, properties, interests and rights, all to the same extent and with the same force and effect as though owned by the Company at the date of execution of the Original Indenture and described in the same detail in the Granting Clauses of the Original Indenture, such premises, properties, interests and rights having been generally described and referred to in the Original Indenture; and to such ends the Company hereby supplements, as below set forth, the Granting Clauses of the Original Indenture:
GRANTING CLAUSES
All of the premises, property, franchises and rights of every kind and description, real, personal and mixed, tangible and intangible, now owned or hereafter acquired by the Company and wherever situate.
Together with all and singular the tenements, hereditament and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders, tolls, rents, revenues, issues, income, products and profits thereof and all the estate, right, title, interest and claim whatsoever at law as well as in equity, which the Company now has or may hereafter acquire in and to the aforesaid property and franchises and every part and parcel thereof.
Excepting and excluding, however, any and all property, premises and rights of the kinds or classes which by the terms of the Indenture are excepted and excluded from the lien and operation thereof, and therein sometimes referred to as "Excepted Property" (subject, however, to the Trustee's rights to possession of Excepted Property in case of default, as set forth under "Excepted Property" in the Original Indenture).
TO HAVE AND TO HOLD in trust with power of sale for the equal and proportionate benefit and security of all holders of all Bonds and the interest coupons appertaining thereto, now or hereafter issued under the Indenture, and for the enforcement and payment of Bonds and interest thereon when payable, and the performance of and compliance with the covenants and conditions of the Indenture, without any preference, distinction or priority as to lien or otherwise of any Bonds or coupons over any others thereof by reason of the difference in the time of the actual issue, sale or negotiation thereof, or by reason of the date of maturity thereof, or for any other reason whatsoever, except as otherwise expressly provided in the Indenture, so that each and every Bond shall have the same lien and so that the interest and principal of every Bond
shall, subject to the terms thereof, be equally and proportionately secured by said lien, as if such Bond had been made, executed, delivered, sold and negotiated simultaneously with the execution and delivery of the Original Indenture.
The Trustee executes this Twenty-Eighth Supplemental Indenture only on the condition that it shall have and enjoy with respect thereto all of the rights, privileges and immunities as set forth in the Indenture.
The Company has agreed and covenanted and does hereby agree and covenant with the Trustee and its successors and assigns, and with the respective holders from time to time of the Bonds, or any thereof, as follows:
PART I
ARTICLE I
DESCRIPTION OF BONDS OF SERIES BB DUE 2020 AND SERIES CC DUE 2009
[sec] 1.01 The twenty-eighth and twenty-ninth series of Bonds to be executed, authenticated and delivered under and secured by the Indenture shall be, respectively, the Bonds of Series BB and the Bonds of Series CC. The Bonds of Series BB shall be designated as "First Mortgage Bonds, Series BB Due 2020" of the Company and the Bonds of Series CC shall be designated as "First Mortgage Bonds, Series CC Due 2009." The Bonds of Series BB and Series CC shall be executed, authenticated and delivered in accordance with the provisions of, and shall in all respects be subject to, all of the terms, conditions and covenants of the Indenture.
[sec] 1.02 The Bonds of Series BB shall be evidenced by a single registered Bond in the principal amount and denomination of One Hundred Million Dollars ($100,000,000), shall be dated July 27, 2001, shall mature June 1, 2020 and shall bear no interest, which may be executed by the Company and delivered to the Trustee for authentication and delivery. The principal of all Bonds of Series BB shall be payable at the office of the Trustee in New York, New York.
The single Bond of the Series BB shall be numbered 1 and shall upon issuance be delivered by the Company to and registered in the name of Ambac Assurance Corporation ("Ambac") and shall be transferable only as required to effect an assignment thereof to a successor-in-interest of Ambac under the Insurance Agreement dated as of June 1, 2000 between Ambac and the Company (the "Insurance Agreement"). This bond is issued to Ambac as security for the payment by the Company of its reimbursement obligations under the Insurance Agreement, which was entered into in connection with the delivery by Ambac of its Municipal Bond Insurance Policy Number 17386BE insuring certain payments of principal of, and interest on, certain bonds (the "2000A Clark County Bonds") issued under Indenture of Trust No. 1 dated as of June 1, 2000 between Clark County, Nevada and The Bank of New York, as Trustee. The proceeds of the 2000A Clark County Bonds were loaned to the Company pursuant to a Financing Agreement No. 1 dated as of June 1, 2000 between Clark County, Nevada and the Company. The single Bond of the BB Series shall be held by Ambac subject to the terms of the Pledge Agreement dated as of July 27, 2001 between Ambac and the Company.
Bonds issued upon transfer shall be numbered from 2 upwards and issued in the same $100,000,000 denomination but, to the extent that payments of principal shall theretofore have been made on the Bonds of the BB Series, the registered holder thereof shall duly note on the Bond of the BB Series a like amount of principal in the Schedule of Prepayments to such bond and upon any transfer of said Bond, the Schedule of Prepayments shall transfer to the subsequent issued bond.
[sect] 1.03 The Bonds of Series BB and the Trustee's Certificate of Authentication shall be substantially in the following forms, respectively:
[FORM OF BOND OF SERIES BB]
NEVADA POWER COMPANY
FIRST MORTGAGE BOND, SERIES BB DUE 2020
Due June 1, 2020
No. BB-1 $100,000,000
NEVADA POWER COMPANY, a Nevada corporation (hereinafter sometimes called the "Company" which term shall include any successor corporation as defined in the Indenture referred to below), for value received, hereby promises to pay to AMBAC ASSURANCE CORPORATION, or to its successor, the sum of One Hundred Million Dollars ($100,000,000) on June 1, 2020. No interest shall be payable in respect of this Bond.
This Bond is issued to Ambac Assurance Corporation ("Ambac") as security for the payment by the Company of its reimbursement obligations under that certain Insurance Agreement dated as of June 1, 2000 between the Company and Ambac (the "Insurance Agreement"). The Insurance Agreement was entered into in connection with the delivery by Ambac of its Municipal Bond Insurance Policy Number 17386BE insuring certain payments of principal of, and interest on, certain bonds (the "Clark County Bonds") issued under Indenture of Trust No. 1 between Clark County, Nevada and The Bank of New York, as Trustee (the "Clark County Indenture"). The proceeds of the Clark County Bonds have been loaned to the Company pursuant to a Financing Agreement No. 1 dated as of June 1, 2000 between Clark County, Nevada and the Company (the "Clark County Agreement"). This Bond shall be held by Ambac subject to the terms of the Pledge Agreement dated as of July 27, 2001 between Ambac Assurance Corporation and the Company.
Notwithstanding any other provision of this Bond, no principal shall be due and payable on this Bond unless and until an Event of Default shall have occurred under Section 4.01 of the Insurance Agreement by reason of a failure by the Company to pay its reimbursement obligations under Section 2.01 of the Insurance Agreement. If such an Event of Default under the Insurance Agreement shall occur, it shall be deemed to be a default, for purposes of Section
13.02(b) of the Indenture, in the payment of an amount of principal of this Bond equal to the amount of such unpaid reimbursement obligation.
This Bond is the single registered bond evidencing the bonds of a series (herein sometimes referred to as the "Bonds of the BB Series") of an authorized issue of bonds of the Company, known as First Mortgage Bonds, not limited as to maximum aggregate principal amount except as otherwise provided in the Indenture hereinafter mentioned, all issued or issuable in one or more series (which several series may be of different denominations, dates and tenor) under and equally and ratably secured (except insofar as any sinking fund, established in accordance with the provisions of the Indenture hereinafter mentioned, may afford additional security for other bonds of any particular series) by an Indenture of Mortgage and Deed of Trust dated as of October 1, 1953, as amended and supplemented by the following Supplemental Indentures and Instrument of Further Assurance, each dated as hereinafter set forth:
Instrument Date ---------- ----- First Supplemental Indenture August 1, 1954 Instrument of Further Assurance as of April 1, 1956 Second Supplemental Indenture September 1, 1956 Third Supplemental Indenture as of May 1, 1959 Fourth Supplemental Indenture as of October 1, 1960 Fifth Supplemental Indenture as of December 1, 1961 Sixth Supplemental Indenture as of October 1, 1963 Seventh Supplemental Indenture as of August 1, 1964 Eighth Supplemental Indenture as of April 1, 1968 Ninth Supplemental Indenture as of October 1, 1969 Tenth Supplemental Indenture as of October 1, 1970 Eleventh Supplemental Indenture as of November 1, 1972 Twelfth Supplemental Indenture as of December 1, 1974 Thirteenth Supplemental Indenture as of October 1, 1976 Fourteenth Supplemental Indenture as of May 1, 1977 Fifteenth Supplemental Indenture as of September 1, 1978 Sixteenth Supplemental Indenture as of December 1, 1981 Seventeenth Supplemental Indenture as of August 1, 1982 Eighteenth Supplemental Indenture as of November 1, 1986 Nineteenth Supplemental Indenture as of October 1, 1989; Twentieth Supplemental Indenture as of May 1, 1992 Twenty-First Supplemental Indenture as of June 1, 1992 Twenty-Second Supplemental Indenture as of June 1, 1992 Twenty-Third Supplemental Indenture as of October 1, 1992 Twenty-Fourth Supplemental Indenture as of October 1, 1992 Twenty-Fifth Supplemental Indenture as of January 1, 1993 Twenty-Sixth Supplemental Indenture as of May 1, 1995 Twenty-Seventh Supplemental Indenture as of July 1, 1999 Twenty-Eighth Supplemental Indenture as of July 1, 2001 |
(which Indenture of Mortgage and Deed of Trust as so amended and supplemented is hereinafter in this Bond called the "Indenture"), executed by the Company to Bankers Trust Company (successor to First Interstate Bank of Nevada, N.A., formerly First National Bank of Nevada, Reno, Nevada) ("Trustee"), as Trustee, to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the properties mortgaged and pledged, the nature and extent of the security, the terms and conditions upon which the Bonds of Series BB are and are to be secured and the rights, duties and immunities thereunder of the holders or registered owners thereof, of the Company, and of the Trustee. As provided in the Indenture, said Bonds may be issued in series, for various principal sums, may bear different dates and mature at different times, may bear interest at different rates and may otherwise vary as in the Indenture provided or permitted. The Bonds of Series BB are described in said Twenty-Eighth Supplemental Indenture dated as of July 1, 2001 ("Twenty-Eighth Supplemental Indenture") executed by the Company to Bankers Trust Company, as Trustee, and are issuable as single registered bonds.
Said Indenture, among other things, provides that no bondholder or bondholders may institute any suit, action or proceeding for the collection of this Bond, or claim for interest thereon, or to enforce the lien of said Indenture, if and to the extent that the institution or prosecution thereof or the entry of a judgment or a decree therein would, under applicable law, result in the surrender, impairment, waiver or loss of the lien of said Indenture upon any property subject thereto.
Without limiting the foregoing, this Bond shall also be deemed to be prepaid by the Company, in whole at any time or in part from time to time, if and to the extent that the Company shall have elected to prepay installments under the Clark County Agreement of like principal amount as the Clark County Bonds that it elects to redeem in accordance with Section 3.01(A) of the Clark County Indenture. Such redemption shall be at the amounts, at the times and in the manner provided in Article III of the Clark County Indenture.
In event of such prepayment of the Clark County Bonds, the Company shall notify Ambac and the Trustee that a like principal amount of this bond shall be deemed to have been prepaid. Ambac shall surrender this bond to the Trustee upon the expiration of the Insurance Agreement.
In case all or substantially all of the electric properties of the Company are sold to or taken through the exercise of the right of eminent domain or the right to purchase by any
municipal or governmental body or agency and released under the provisions of Article XI of the Indenture, the Company shall call for redemption and redeem all of the Bonds of Series BB then outstanding for 100% of the principal amount thereof.
In case an event of default, as defined in the Indenture, shall occur and be continuing, the principal of all the Bonds outstanding may be declared and may become due and payable in the manner and with the effect provided in the Indenture.
The Company and the Trustee and any paying agent may deem and treat the person in whose name this Bond shall be registered upon the bond register for the Bonds of the BB Series as the absolute owner of such Bond for the purpose of receiving payment of or on account of the principal of and interest on this Bond and for all other purposes, whether or not this Bond be overdue, and neither the Company nor the Trustee nor any paying agent shall be affected by any notice to the contrary; and all such payments so made to such registered owner or upon his order shall be valid and effectual to satisfy and discharge the liability upon this Bond to the extent of the sum or sums so paid.
Before any transfer of this Bond by the registered holder or his or its legal representative will be recognized or given effect by the Company or the Trustee, the registered holder shall note the amounts of all principal prepayments hereon, and shall notify the Company and the Trustee of the name and address of the transferee and shall afford the Company and the Trustee the opportunity of verifying the notation as to prepayment of principal. By the acceptance hereof the holder of this Bond and each transferee shall be deemed to have agreed to indemnify and hold harmless the Company and the Trustee against all losses, claims, damages or liability arising out of any failure on the part of the holder or of any such transferee to comply with the part of the holder or of any such transferee to comply with the requirements of the preceding sentence.
No recourse under or upon any obligation, covenant or agreement contained in the Indenture or in any indenture supplemental thereto, or in any Bond or coupon thereby secured, or because of any indebtedness thereby secured, shall be had against any incorporator, or against any past, present or future stockholder, officer, or director, as such, of the Company or any successor corporation, either directly or through the Company or of any successor corporation
under any rule of law, statute or constitutional provision or by the enforcement of any assessment or by any legal or equitable proceeding or otherwise; it being expressly agreed and understood that the Indenture, any indenture supplemental thereto and the obligations thereby secured, are solely corporate obligations, and that no personal liability whatever shall attach to, or be incurred by, such incorporators, stockholders, officers or directors, as such, of the Company or of any successor corporation, or any of them, because of the incurring of the indebtedness thereby authorized, or under or by reason of any of the obligations, covenants or agreements contained in the Indenture or in any indenture supplemental thereto or in any of the Bonds or coupons thereby secured, or implied therefrom.
Each registered owner hereof by his acceptance hereof waives any right to exchange any unpaid portion of this Bond for another Bond under Section 10.01 of the Indenture.
This Bond has not been registered under the Securities Act of 1933, as amended, and may not be offered or sold in contravention of said Act and is not transferable except to a successor to Ambac under the Insurance Agreement.
This bond shall not become or be valid or obligatory for any purpose until the authentication certificate endorsed hereon shall have been signed by the Trustee.
IN WITNESS WHEREOF, Nevada Power Company has caused this bond to be executed in its name and behalf by the manual or facsimile signature of its Treasurer and its corporate seal, or a facsimile thereof, to be affixed or printed hereon and attested by the manual or facsimile signature of its Secretary or one of its Assistant Secretaries.
NEVADA POWER COMPANY
Dated: July __, 2001 By:____________________________________________ Treasurer Attest: ______________________________ Secretary |
AUTHENTICATION CERTIFICATE
This bond is the single fully-registered bond of the series designated therein, referred to in the within-mentioned Indenture.
BANKERS TRUST COMPANY, AS TRUSTEE
By______________________
Authorized Signatory
[sect] 1.04 The Bonds of Series CC shall be evidenced by a single registered Bond in the principal amount and denomination of Fifteen Million Dollars ($15,000,000), shall be dated July 27, 2001, shall mature October 1, 2009 and shall bear no interest, which may be executed by the Company and delivered to the Trustee for authentication and delivery. The principal of all Bonds of Series CC shall be payable at the office of the Trustee in New York, New York.
The single Bond of the Series CC shall be numbered 1 and shall upon issuance be delivered by the Company to and registered in the name of Ambac and shall be transferable only as required to effect an assignment thereof to a successor-in-interest of Ambac under the Insurance Agreement. This bond is issued to Ambac as security for the payment by the Company of its reimbursement obligations under the Insurance Agreement, which was entered into in connection with the delivery by Ambac of its Municipal Bond Insurance Policy Number 17387BE insuring certain payments of principal of, and interest on, certain bonds (the "2000B Clark County Bonds") issued under Indenture of Trust No. 2 dated as of June 1, 2000 between Clark County, Nevada and The Bank of New York, as Trustee. The proceeds of the 2000B Clark County Bonds were loaned to the Company pursuant to a Financing Agreement No. 2 dated as of June 1, 2000 between Clark County, Nevada and the Company. The single Bond of the CC Series shall be held by Ambac subject to the terms of the Pledge Agreement dated as of July 27, 2001 between Ambac and the Company.
Bonds issued upon transfer shall be numbered from 2 upwards and issued in the same $15,000,000 denomination but, to the extent that payments of principal shall theretofore have been made on the Bonds of the CC Series, the registered holder thereof shall duly note on the Bond of the CC Series a like amount of principal in the Schedule of Prepayments to such bond and upon any transfer of said Bond, the Schedule of Prepayments shall transfer to the subsequent issued bond.
[sect] 1.05 The Bonds of Series CC and the Trustee's Certificate of Authentication shall be substantially in the following forms, respectively:
[FORM OF BOND OF SERIES CC]
NEVADA POWER COMPANY
FIRST MORTGAGE BOND, SERIES CC DUE 2009
Due October 1, 2009
No. CC-1 $15,000,000
NEVADA POWER COMPANY, a Nevada corporation (hereinafter sometimes called the "Company" which term shall include any successor corporation as defined in the Indenture referred to below), for value received, hereby promises to pay to AMBAC ASSURANCE CORPORATION, or to its successor, the sum of Fifteen Million Dollars ($15,000,000) on October 1, 2009. No interest shall be payable in respect of this Bond.
This Bond is issued to Ambac Assurance Corporation ("Ambac") as security for the payment by the Company of its reimbursement obligations under that certain Insurance Agreement dated as of June 1, 2000 between the Company and Ambac (the "Insurance Agreement"). The Insurance Agreement was entered into in connection with the delivery by Ambac of its Municipal Bond Insurance Policy Number 17387BE insuring certain payments of principal of, and interest on, certain bonds (the "Clark County Bonds") issued under Indenture of Trust No. 2 between Clark County, Nevada and The Bank of New York, as Trustee (the "Clark County Indenture"). The proceeds of the Clark County Bonds have been loaned to the Company pursuant to a Financing Agreement No. 2 dated as of June 1, 2000 between Clark County, Nevada and the Company (the "Clark County Agreement"). This Bond shall be held by Ambac subject to the terms of the Pledge Agreement dated as of July 27, 2001 between Ambac Assurance Corporation and the Company.
Notwithstanding any other provision of this Bond, no principal shall be due and payable on this Bond unless and until an Event of Default shall have occurred under Section 4.01 of the Insurance Agreement by reason of a failure by the Company to pay its reimbursement obligations under Section 2.01 of the Insurance Agreement. If such an Event of Default under the Insurance Agreement shall occur, it shall be deemed to be a default, for purposes of Section 13.02(b) of the Indenture, in the payment of an amount of principal of this Bond equal to the amount of such unpaid reimbursement obligation.
This Bond is the single registered bond evidencing the bonds of a series (herein sometimes referred to as the "Bonds of the CC Series") of an authorized issue of bonds of the Company, known as First Mortgage Bonds, not limited as to maximum aggregate principal amount except as otherwise provided in the Indenture hereinafter mentioned, all issued or issuable in one or more series (which several series may be of different denominations, dates and tenor) under and equally and ratably secured (except insofar as any sinking fund, established in accordance with the provisions of the Indenture hereinafter mentioned, may afford additional security for other bonds of any particular series) by an Indenture of Mortgage and Deed of Trust dated as of October 1, 1953, as amended and supplemented by the following Supplemental Indentures and Instrument of Further Assurance, each dated as hereinafter set forth:
Instrument Date ---------- ---- First Supplemental Indenture August 1, 1954 Instrument of Further Assurance as of April 1, 1956 Second Supplemental Indenture September 1, 1956 Third Supplemental Indenture as of May 1, 1959 Fourth Supplemental Indenture as of October 1, 1960 Fifth Supplemental Indenture as of December 1, 1961 Sixth Supplemental Indenture as of October 1, 1963 Seventh Supplemental Indenture as of August 1, 1964 Eighth Supplemental Indenture as of April 1, 1968 Ninth Supplemental Indenture as of October 1, 1969 Tenth Supplemental Indenture as of October 1, 1970 Eleventh Supplemental Indenture as of November 1, 1972 -12- |
Twelfth Supplemental Indenture as of December 1, 1974 Thirteenth Supplemental Indenture as of October 1, 1976 Fourteenth Supplemental Indenture as of May 1, 1977 Fifteenth Supplemental Indenture as of September 1, 1978 Sixteenth Supplemental Indenture as of December 1, 1981 Seventeenth Supplemental Indenture as of August 1, 1982 Eighteenth Supplemental Indenture as of November 1, 1986 Nineteenth Supplemental Indenture as of October 1, 1989; Twentieth Supplemental Indenture as of May 1, 1992 Twenty-First Supplemental Indenture as of June 1, 1992 Twenty-Second Supplemental Indenture as of June 1, 1992 Twenty-Third Supplemental Indenture as of October 1, 1992 Twenty-Fourth Supplemental Indenture as of October 1, 1992 Twenty-Fifth Supplemental Indenture as of January 1, 1993 Twenty-Sixth Supplemental Indenture as of May 1, 1995 Twenty-Seventh Supplemental Indenture as of July 1, 1999 Twenty-Eighth Supplemental Indenture as of July 1, 2001 |
(which Indenture of Mortgage and Deed of Trust as so amended and supplemented is hereinafter in this Bond called the "Indenture"), executed by the Company to Bankers Trust Company (successor to First Interstate Bank of Nevada, N.A., formerly First National Bank of Nevada, Reno, Nevada) ("Trustee"), as Trustee, to which Indenture and all indentures supplemental thereto reference is hereby made for a description of the properties mortgaged and pledged, the nature and extent of the security, the terms and conditions upon which the Bonds of Series CC are and are to be secured and the rights, duties and immunities thereunder of the holders or registered owners thereof, of the Company, and of the Trustee. As provided in the Indenture, said Bonds may be issued in series, for various principal sums, may bear different dates and mature at different times, may bear interest at different rates and may otherwise vary as in the Indenture provided or permitted. The Bonds of Series CC are described in said Twenty-Eighth Supplemental Indenture dated as of July 1, 2001 ("Twenty-Eighth Supplemental Indenture") executed by the Company to Bankers Trust Company, as Trustee, and are issuable as single registered bonds.
Said Indenture, among other things, provides that no bondholder or bondholders may institute any suit, action or proceeding for the collection of this Bond, or claim for interest thereon, or to enforce the lien of said Indenture, if and to the extent that the institution or prosecution thereof or the entry of a judgment or a decree therein would, under applicable law, result in the surrender, impairment, waiver or loss of the lien of said Indenture upon any property subject thereto.
in whole or in part, upon the occurrence of an event specified in Section 3.01(B) of the Clark County Indenture. In any such event this Bond shall be deemed to be prepaid by the Company, in whole or in identical part, as the case may be, at 100% of the unpaid principal amount thereof so prepaid.
Without limiting the foregoing, this Bond shall also be deemed to be prepaid by the Company, in whole at any time or in part from time to time, if and to the extent that the Company shall have elected to prepay installments under the Clark County Agreement of like principal amount as the Clark County Bonds that it elects to redeem in accordance with Section 3.01(A) of the Clark County Indenture. Such redemption shall be at the amounts, at the times and in the manner provided in Article III of the Clark County Indenture.
In event of such prepayment of the Clark County Bonds, the Company shall notify Ambac and the Trustee that a like principal amount of this bond shall be deemed to have been prepaid. Ambac shall surrender this bond to the Trustee upon the expiration of the Insurance Agreement.
In case all or substantially all of the electric properties of the Company are sold to or taken through the exercise of the right of eminent domain or the right to purchase by any municipal or governmental body or agency and released under the provisions of Article XI of the Indenture, the Company shall call for redemption and redeem all of the Bonds of Series CC then outstanding for 100% of the principal amount thereof.
In case an event of default, as defined in the Indenture, shall occur and be continuing, the principal of all the Bonds outstanding may be declared and may become due and payable in the manner and with the effect provided in the Indenture.
The Company and the Trustee and any paying agent may deem and treat the person in whose name this Bond shall be registered upon the bond register for the Bonds of the CC Series as the absolute owner of such Bond for the purpose of receiving payment of or on account of the principal of and interest on this Bond and for all other purposes, whether or not this Bond be overdue, and neither the Company nor the Trustee nor any paying agent shall be affected by any notice to the contrary; and all such payments so made to such registered owner or upon his order
shall be valid and effectual to satisfy and discharge the liability upon this Bond to the extent of the sum or sums so paid.
Before any transfer of this Bond by the registered holder or his or its legal representative will be recognized or given effect by the Company or the Trustee, the registered holder shall note the amounts of all principal prepayments hereon, and shall notify the Company and the Trustee of the name and address of the transferee and shall afford the Company and the Trustee the opportunity of verifying the notation as to prepayment of principal. By the acceptance hereof the holder of this Bond and each transferee shall be deemed to have agreed to indemnify and hold harmless the Company and the Trustee against all losses, claims, damages or liability arising out of any failure on the part of the holder or of any such transferee to comply with the part of the holder or of any such transferee to comply with the requirements of the preceding sentence.
No recourse under or upon any obligation, covenant or agreement contained in the Indenture or in any indenture supplemental thereto, or in any Bond or coupon thereby secured, or because of any indebtedness thereby secured, shall be had against any incorporator, or against any past, present or future stockholder, officer, or director, as such, of the Company or any successor corporation, either directly or through the Company or of any successor corporation under any rule of law, statute or constitutional provision or by the enforcement of any assessment or by any legal or equitable proceeding or otherwise; it being expressly agreed and understood that the Indenture, any indenture supplemental thereto and the obligations thereby secured, are solely corporate obligations, and that no personal liability whatever shall attach to, or be incurred by, such incorporators, stockholders, officers or directors, as such, of the Company or of any successor corporation, or any of them, because of the incurring of the indebtedness thereby authorized, or under or by reason of any of the obligations, covenants or agreements contained in the Indenture or in any indenture supplemental thereto or in any of the Bonds or coupons thereby secured, or implied therefrom.
Each registered owner hereof by his acceptance hereof waives any right to exchange any unpaid portion of this Bond for another Bond under Section 10.01 of the Indenture.
This Bond has not been registered under the Securities Act of 1933, as amended, and may not be offered or sold in contravention of said Act and is not transferable except to a successor to Ambac under the Insurance Agreement.
This bond shall not become or be valid or obligatory for any purpose until the authentication certificate endorsed hereon shall have been signed by the Trustee.
IN WITNESS WHEREOF, Nevada Power Company has caused this bond to be executed in its name and behalf by the manual or facsimile signature of its Treasurer and its corporate seal, or a facsimile thereof, to be affixed or printed hereon and attested by the manual or facsimile signature of its Secretary or one of its Assistant Secretaries.
NEVADA POWER COMPANY
Dated: July __, 2001 By:_______________________ Treasurer Attest: ________________________ Secretary |
AUTHENTICATION CERTIFICATE
This bond is the single fully-registered bond of the series designated therein, referred to in the within-mentioned Indenture.
BANKERS TRUST COMPANY, AS TRUSTEE
By ______________________
Authorized Signatory
ARTICLE II
AUTHORIZED PRINCIPAL AMOUNT
[sect] 2.01 Bonds of Series BB may be executed by the Company and authenticated and delivered by the Trustee at any time and from time to time, in the manner and amount permitted by the Indenture; provided, however, that no Bonds of Series BB in excess of One Hundred Million Dollars ($100,000,000) principal amount (other than Bonds of Series BB which may be so executed, authorized and delivered in lieu of other Bonds of Series BB as authenticated under Article II or Section 10.01 of the Original Indenture) shall be executed by the Company, authenticated or delivered by the Trustee or secured by the Indenture, except in such additional principal amounts as may be authorized by a supplemental indenture or indentures which the Company and the Trustee are hereby authorized to execute and deliver for that purpose.
[sect] 2.02 Bonds of Series CC may be executed by the Company and authenticated and delivered by the Trustee at any time and from time to time, in the manner and amount permitted by the Indenture; provided, however, that no Bonds of Series CC in excess of Fifteen Million Dollars ($15,000,000) principal amount (other than Bonds of Series CC which may be so executed, authorized and delivered in lieu of other Bonds of Series CC as authenticated under Article II or Section 10.01 of the Original Indenture) shall be executed by the Company, authenticated or delivered by the Trustee or secured by the Indenture, except in such additional principal amounts as may be authorized by a supplemental indenture or indentures which the Company and the Trustee are hereby authorized to execute and deliver for that purpose.
ARTICLE III
REPRESENTATIONS AND WARRANTIES
[sec] 3.01 The Company represents and warrants that, as of the date of execution of this Twenty-Eighth Supplemental Indenture, it has good and marketable title in fee simple to all the real properties described in the Granting Clauses of the Original Indenture, the First Supplemental Indenture, the Instrument of Further Assurance, the Second Supplemental Indenture, the Third Supplemental Indenture, the Fourth Supplemental Indenture, the Fifth Supplemental Indenture, the Sixth Supplemental Indenture, the Seventh Supplemental Indenture, the Eighth Supplemental Indenture, the Ninth Supplemental Indenture, the Tenth Supplemental Indenture, the Eleventh Supplemental Indenture, the Twelfth Supplemental Indenture, the Thirteenth Supplemental Indenture, the Fourteenth Supplemental Indenture, the Fifteenth Supplemental Indenture, the Sixteenth Supplemental Indenture, the Seventeenth Supplemental Indenture, the Eighteenth Supplemental Indenture, the Nineteenth Supplemental Indenture, the Twentieth Supplemental Indenture, the Twenty-First Supplemental Indenture, the Twenty-Second Supplemental Indenture, the Twenty-Third Supplemental Indenture, the Twenty-Fourth Supplemental Indenture, the Twenty-Fifth Supplemental Indenture, the Twenty-Sixth Supplemental Indenture and the Twenty-Seventh Supplemental Indenture (except any property heretofore released from the lien of the Indenture in accordance with the terms thereof), free and clear of any liens and encumbrances except Permitted Encumbrances and those, if any, referred to in said Granting Clauses, and that it has good and marketable title and is lawfully possessed of all other properties described in said Granting Clauses (except any properties therein described as to be acquired by the Company after the date of this Twenty-Eighth Supplemental Indenture and except any property heretofore released from the lien of the Indenture in accordance with the terms thereof), and the Indenture constitutes a direct and valid first mortgage lien on all such properties, subject only to Permitted Encumbrances and those, if any, referred to in said Granting Clauses. The Company represents and warrants that it has and covenants that it will continue to have, subject to the provisions of the Indenture, good right, full power and lawful authority to grant, bargain, sell, warrant, alien, remise, release, convey, assign, transfer, mortgage, pledge, set over and confirm to the Trustee all properties of every kind and nature described or referred to in said Granting Clauses (except any properties therein described as to be acquired by the Company after the date of this Twenty-Eighth Supplemental Indenture) which by the provisions of the Indenture are intended to be subject to the lien of the Indenture and that it will defend the title to such property and every part thereof to the Trustee forever, for the benefit of the holders of the Bonds, against the claims and demands of all persons whomsoever.
PART II
MISCELLANEOUS PROVISIONS
Except insofar as herein otherwise expressly provided, all of the definitions, provisions, terms and conditions of the Indenture shall be deemed to be incorporated in, and made a part of, this Twenty-Eighth Supplemental Indenture; and the Original Indenture as amended and supplemented by the First Supplemental Indenture, the Second Supplemental Indenture, the
Third Supplemental Indenture, the Fourth Supplemental Indenture, the Fifth Supplemental Indenture, the Sixth Supplemental Indenture, the Seventh Supplemental Indenture, the Eighth Supplemental Indenture, the Ninth Supplemental Indenture, the Tenth Supplemental Indenture, the Eleventh Supplemental Indenture, the Twelfth Supplemental Indenture, the Thirteenth Supplemental Indenture, the Fourteenth Supplemental Indenture, the Fifteenth Supplemental Indenture, the Sixteenth Supplemental Indenture, the Seventeenth Supplemental Indenture, the Eighteenth Supplemental Indenture, the Nineteenth Supplemental Indenture, the Twentieth Supplemental Indenture, the Twenty-First Supplemental Indenture, the Twenty-Second Supplemental Indenture, the Twenty-Third Supplemental Indenture, the Twenty-Fourth Supplemental Indenture, Twenty-Fifth Supplemental Indenture, Twenty-Sixth Supplemental Indenture and the Twenty-Seventh Supplemental Indenture and is in all respects ratified and confirmed and supplemented by this Twenty-Eighth Supplemental Indenture; and the Original Indenture as amended and supplemented shall be read, taken and construed as one and the same instrument.
This Twenty-Eighth Supplemental Indenture shall be effective as of the date first hereinabove set forth, and may be executed simultaneously or from time to time in several counterparts, and each counterpart shall constitute an original instrument, and it shall not be necessary in making proof of this Twenty-Eighth Supplemental Indenture or of any counterpart thereof to produce or account for any of the other counterparts.
[The remainder of this page is intentionally left blank.]
IN WITNESS WHEREOF, said Nevada Power Company has caused this Twenty-Eighth Supplemental Indenture to be executed on its behalf by its Treasurer and its corporate seal to be hereto affixed, and the said seal and this Twenty-Eighth Supplemental Indenture to be attested by its Secretary; and said Bankers Trust Company in evidence of its acceptance of the trust hereby created has caused this Twenty-Eighth Supplemental Indenture to be executed on its behalf by its Vice President and its corporate seal to be hereto affixed and said seal and this Twenty-Eighth Supplemental Indenture to be attested by its Associate, all as of the 1st day of July, 2001.
NEVADA POWER COMPANY
By:_______________________________
Richard K. Atkinson
Treasurer
[S E A L]
ATTEST:
BANKERS TRUST COMPANY, as Trustee
By:______________________________
Vice President
[S E A L]
ATTEST:
STATE OF NEVADA ) )ss. COUNTY OF CLARK ) |
On this ____ day of July, 2001, personally appeared before me, a Notary Public in and for said County and State, ___________________________ and _________________________, known to me to be ___________________________ and _________________________, respectively, of Nevada Power Company, one of the corporations that executed the foregoing instrument, and upon oath did each depose that he is the officer of said corporation as above designated; that he is acquainted with the seal of said corporation and that the seal affixed to said instrument is the corporate seal of said corporation; that the signatures to said instrument were made by officers of said corporation as indicated after said signatures, and that the said corporation executed the said instrument freely and voluntarily and for the uses and purposes therein mentioned.
STATE OF NEW YORK )
)ss.
COUNTY OF NEW YORK )
[Notarial seal] ____________________________________ Tracy A. Salzmann Notary Public, State of New York Registration #01SA6040727 Qualified in New York County My Commission Expires April 24, 2002 |
EXHIBIT A
The Original Indenture, First Supplemental Indenture, an Instrument of Further Assurance, Second Supplemental Indenture, Third Supplemental Indenture, Fourth Supplemental Indenture, Fifth Supplemental Indenture, Sixth Supplemental Indenture, Seventh Supplemental Indenture, Eighth Supplemental Indenture, Ninth Supplemental Indenture, Tenth Supplemental Indenture, Eleventh Supplemental Indenture, Twelfth Supplemental Indenture, Thirteenth Supplemental Indenture, Fourteenth Supplemental Indenture, Fifteenth Supplemental Indenture, Sixteenth Supplemental Indenture, Seventeenth Supplemental Indenture, Eighteenth Supplemental Indenture, Nineteenth Supplemental Indenture, Twentieth Supplemental Indenture, Twenty-First Supplemental Indenture, Twenty-Second Supplemental Indenture, Twenty-Third Supplemental Indenture, Twenty-Fourth Supplemental Indenture, Twenty-Fifth Supplemental Indenture, Twenty-Sixth Supplemental Indenture and Twenty-Seventh Supplemental Indenture were recorded in Offices of the County Recorders of the States of Nevada, Arizona and Utah as follows:
NEVADA CLARK COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Nov. 6, 1953 417,677 Trust Deeds First Supplemental Indenture Sept. 23, 1954 20,904 Official Records Instrument of Further Assurance Apr. 19, 1956 75,779 Official Records Second Supplemental Indenture Sept. 19, 1956 89,423 Official Records Third Supplemental Indenture May 15, 1959 160,878 Official Records Fourth Supplemental Indenture Oct. 28, 1960 215,907 Official Records Fifth Supplemental Indenture Dec. 4, 1961 267,362 Official Records Sixth Supplemental Indenture Oct. 18, 1963 391,466 Official Records Seventh Supplemental Indenture Aug. 7, 1964 451,010 Official Records Eighth Supplemental Indenture May 10, 1968 700,126 Official Records Ninth Supplemental Indenture Oct. 16, 1969 791,246 Official Records Tenth Supplemental Indenture Oct. 2, 1970 53,871 Official Records Eleventh Supplemental Indenture Oct. 27, 1972 233,640 Official Records Twelfth Supplemental Indenture Dec. 6, 1974 438,246 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 629,589 Official Records Fourteenth Supplemental Indenture May 4, 1977 693,961 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 898,343 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 1,453,990 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 1,569,991 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 00622 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 00576 Official Records Twentieth Supplemental Indenture April 30, 1992 01212 Official Records Twenty-First Supplemental Indenture June 19, 1992 01239 Official Records Twenty-Second Supplemental Indenture June 19, 1992 01240 Official Records Twenty-Third Supplemental Indenture October 26, 1992 00858 Official Records Twenty-Fourth Supplemental Indenture November 2, 1992 00901 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 00710 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 00625 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 01207 Official Records |
NEVADA
NYE COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Sept. 19, 1956 24,334 Trust Deeds First Supplemental Indenture Sept. 19, 1956 24,335 Official Records Instrument of Further Assurance Sept. 19, 1956 24,336 Official Records Second Supplemental Indenture Sept. 19, 1956 24,337 Official Records Third Supplemental Indenture May 15, 1959 31,466 Official Records Fourth Supplemental Indenture Oct. 28, 1960 37,060 Official Records Fifth Supplemental Indenture Dec. 5, 1961 39,876 Official Records Sixth Supplemental Indenture Oct. 18, 1963 46,249 Official Records Seventh Supplemental Indenture Aug. 7, 1964 48,660 Official Records Eighth Supplemental Indenture May 10, 1968 05,910 Official Records Ninth Supplemental Indenture Oct. 17, 1969 15,192 Official Records Tenth Supplemental Indenture Oct. 5, 1970 20,294 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 35,265 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 45,632 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 55,802 Official Records Fourteenth Supplemental Indenture May 4, 1977 58,169 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 70,767 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 54,601 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 65,354 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 171,431 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 245632 Official Records Twentieth Supplemental Indenture April 30, 1992 307547 Official Records Twenty-First Supplemental Indenture June 19, 1992 310469 Official Records Twenty-Second Supplemental Indenture June 19, 1992 310470 Official Records Twenty-Third Supplemental Indenture October 26, 1992 320357 Official Records Twenty-Fourth Supplemental Indenture November 2, 1992 320802 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 324817 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 372838 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 475120 Official Records |
NEVADA
LINCOLN COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Sept. 1, 1972 52,162 Official Records First Supplemental Indenture Sept. 1, 1972 52,163 Official Records Instrument of Further Assurance Sept. 1, 1972 52,164 Official Records Second Supplemental Indenture Sept. 1, 1972 52,165 Official Records Third Supplemental Indenture Sept. 1, 1972 52,166 Official Records Fourth Supplemental Indenture Sept. 1, 1972 52,167 Official Records Fifth Supplemental Indenture Sept. 1, 1972 52,168 Official Records Sixth Supplemental Indenture Sept. 1, 1972 52,169 Official Records Seventh Supplemental Indenture Sept. 1, 1972 52,170 Official Records Eighth Supplemental Indenture Sept. 1, 1972 52,171 Official Records Ninth Supplemental Indenture Sept. 1, 1972 52,172 Official Records Tenth Supplemental Indenture Sept. 1, 1972 52,173 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 52,330 Official Records Twelfth Supplemental Indenture Dec. 6, 1974 55,557 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 58,659 Official Records Fourteenth Supplemental Indenture May 4, 1977 59,627 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 62,731 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 74,010 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 75,970 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 85,911 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 92444 Official Records Twentieth Supplemental Indenture April 30, 1992 98382 Official Records Twenty-First Supplemental Indenture June 19, 1992 98558 Official Records Twenty-Second Supplemental Indenture June 19, 1992 98559 Official Records Twenty-Third Supplemental Indenture October 26, 1992 99552 Official Records Twenty-Fourth Supplemental Indenture November 2, 1992 99062 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 99782 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 103516 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 113157 Official Records |
ARIZONA
NAVAJO COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Oct. 5, 1970 330 Official Records First Supplemental Indenture Oct. 5, 1970 330 Official Records Instrument of Further Assurance Oct. 5, 1970 330 Official Records Second Supplemental Indenture Oct. 5, 1970 330 Official Records Third Supplemental Indenture Oct. 5, 1970 330 Official Records Fourth Supplemental Indenture Oct. 5, 1970 330 Official Records Fifth Supplemental Indenture Oct. 5, 1970 330 Official Records Sixth Supplemental Indenture Oct. 5, 1970 330 Official Records Seventh Supplemental Indenture Oct. 5, 1970 330 Official Records Eighth Supplemental Indenture Oct. 5, 1970 330 Official Records Ninth Supplemental Indenture Oct. 5, 1970 330 Official Records Tenth Supplemental Indenture Oct. 5, 1970 330 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 376 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 426 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 473 Official Records Fourteenth Supplemental Indenture May 4, 1977 486 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 531 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 647 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 691 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 846 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 970 Official Records Twentieth Supplemental Indenture April 30, 1992 1076 Official Records Twenty-First Supplemental Indenture June 19, 1992 1083 Official Records Twenty-Second Supplemental Indenture June 19, 1992 1083 Official Records Twenty-Third Supplemental Indenture October 26, 1992 1103 Official Records Twenty-Fourth Supplemental Indenture October 30, 1992 1104 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 1112 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 1995/7363 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 1999/16074 Official Records |
ARIZONA
COCONINO COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Oct. 1, 1970 370 Official Records First Supplemental Indenture Oct. 1, 1970 370 Official Records Instrument of Further Assurance Oct. 1, 1970 370 Official Records Second Supplemental Indenture Oct. 1, 1970 370 Official Records Third Supplemental Indenture Oct. 1, 1970 370 Official Records Fourth Supplemental Indenture Oct. 1, 1970 370 Official Records Fifth Supplemental Indenture Oct. 1, 1970 370 Official Records Sixth Supplemental Indenture Oct. 1, 1970 370 Official Records Seventh Supplemental Indenture Oct. 1, 1970 370 Official Records Eighth Supplemental Indenture Oct. 1, 1970 370 Official Records Ninth Supplemental Indenture Oct. 1, 1970 370 Official Records Tenth Supplemental Indenture Oct. 5, 1970 370 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 445 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 528 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 606 Official Records Fourteenth Supplemental Indenture May 4, 1977 628 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 697 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 862 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 896 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 1125 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 1304 Official Records Twentieth Supplemental Indenture April 30, 1992 1471 Official Records Twenty-First Supplemental Indenture June 19, 1992 1483 Official Records Twenty-Second Supplemental Indenture June 19, 1992 1483 Official Records Twenty-Third Supplemental Indenture October 26, 1992 1515 Official Records Twenty-Fourth Supplemental Indenture October 30, 1992 1517 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 1535 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 95-14068 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 3017077 Official Records |
ARIZONA
MOHAVE COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Aug. 28, 1972 50 Official Records First Supplemental Indenture Aug. 28, 1972 50 Official Records Instrument of Further Assurance Aug. 28, 1972 50 Official Records Second Supplemental Indenture Aug. 28, 1972 50 Official Records Third Supplemental Indenture Aug. 28, 1972 50 Official Records Fourth Supplemental Indenture Aug. 28, 1972 50 Official Records Fifth Supplemental Indenture Aug. 28, 1972 50 Official Records Sixth Supplemental Indenture Aug. 28, 1972 50 Official Records Seventh Supplemental Indenture Aug. 28, 1972 51 Official Records Eighth Supplemental Indenture Aug. 28, 1972 51 Official Records Ninth Supplemental Indenture Aug. 28, 1972 51 Official Records Tenth Supplemental Indenture Aug. 28, 1972 51 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 67 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 250 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 355 Official Records Fourteenth Supplemental Indenture May 4, 1977 390 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 489 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 765 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 865 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 1264 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 1612 Official Records Twentieth Supplemental Indenture April 30, 1992 92-12800 Official Records Twenty-First Supplemental Indenture June 19, 1992 92-33181 Official Records Twenty-Second Supplemental Indenture June 19, 1992 92-33182 Official Records Twenty-Third Supplemental Indenture October 26, 1992 92-58584 Official Records Twenty-Fourth Supplemental Indenture October 30, 1992 92-59727 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 2160 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 95-25569 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 99047383 Official Records |
UTAH
KANE COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Sept. 12, 1972 35 Official Records First Supplemental Indenture Sept. 12, 1972 35 Official Records Instrument of Further Assurance Sept. 12, 1972 35 Official Records Second Supplemental Indenture Sept. 12, 1972 35 Official Records Third Supplemental Indenture Sept. 12, 1972 35 Official Records Fourth Supplemental Indenture Sept. 12, 1972 35 Official Records Fifth Supplemental Indenture Sept. 12, 1972 35 Official Records Sixth Supplemental Indenture Sept. 12, 1972 35 Official Records Seventh Supplemental Indenture Sept. 12, 1972 35 Official Records Eighth Supplemental Indenture Sept. 12, 1972 35 Official Records Ninth Supplemental Indenture Sept. 12, 1972 35 Official Records Tenth Supplemental Indenture Sept. 12, 1972 35 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 35 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 44 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 53 Official Records Fourteenth Supplemental Indenture May 4, 1977 55 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 59 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 71 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 074 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 093 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 0106 Official Records Twentieth Supplemental Indenture April 30, 1992 72900 Official Records Twenty-First Supplemental Indenture June 19, 1992 73283 Official Records Twenty-Second Supplemental Indenture June 19, 1992 73284 Official Records Twenty-Third Supplemental Indenture October 26, 1992 74584 Official Records Twenty-Fourth Supplemental Indenture October 30, 1992 74641 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 75203 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 83330 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 99595 Official Records |
UTAH
WASHINGTON COUNTY
RECORDED DOC. NO. RECORDS -------- -------- ------- Original Indenture Sept. 22, 1972 124 Official Records First Supplemental Indenture Sept. 22, 1972 124 Official Records Instrument of Further Assurance Sept. 22, 1972 124 Official Records Second Supplemental Indenture Sept. 22, 1972 124 Official Records Third Supplemental Indenture Sept. 22, 1972 124 Official Records Fourth Supplemental Indenture Sept. 22, 1972 124 Official Records Fifth Supplemental Indenture Sept. 22, 1972 124 Official Records Sixth Supplemental Indenture Sept. 22, 1972 124 Official Records Seventh Supplemental Indenture Sept. 22, 1972 124 Official Records Eighth Supplemental Indenture Sept. 22, 1972 124 Official Records Ninth Supplemental Indenture Sept. 22, 1972 124 Official Records Tenth Supplemental Indenture Sept. 22, 1972 124 Official Records Eleventh Supplemental Indenture Oct. 30, 1972 127 Official Records Twelfth Supplemental Indenture Dec. 9, 1974 163 Official Records Thirteenth Supplemental Indenture Oct. 19, 1976 204 Official Records Fourteenth Supplemental Indenture May 4, 1977 218 Official Records Fifteenth Supplemental Indenture Sept. 5, 1978 239 Official Records Sixteenth Supplemental Indenture Dec. 4, 1981 302 Official Records Seventeenth Supplemental Indenture Aug. 19, 1982 313 Official Records Eighteenth Supplemental Indenture Nov. 13, 1986 431 Official Records Nineteenth Supplemental Indenture Oct. 12, 1989 537 Official Records Twentieth Supplemental Indenture April 30, 1992 405624 Official Records Twenty-First Supplemental Indenture June 19, 1992 409301 Official Records Twenty-Second Supplemental Indenture June 19, 1992 409302 Official Records Twenty-Third Supplemental Indenture October 26, 1992 417975 Official Records Twenty-Fourth Supplemental Indenture October 30, 1992 418495 Official Records Twenty-Fifth Supplemental Indenture January 11, 1993 423543 Official Records Twenty-Sixth Supplemental Indenture May 18, 1995 500264 Official Records Twenty-Seventh Supplemental Indenture August 5, 1999 00657403 Official Records |
The foregoing document was recorded as follows:
RECORDED DOC. NO. RECORDS -------- -------- ------- Navajo County, Arizona July 30, 2001 2001-14624 Official Records Coconino County, Arizona July 27, 2001 3100982 Official Records Mohave County, Arizona July 27, 2001 2001-45343 Official Records Kane County, Utah July 27, 2001 106741 Official Records Washington County, Utah July 27, 2001 729347 Official Records Lincoln County, Nevada July 27, 2001 116700 Official Records Clark County, Nevada July 27, 2001 02870 Official Records Nye County, Nevada July 31, 2001 518675 Official Records |
EXHIBIT 10(A)
[EXECUTION COPY]
$75,000,000
CREDIT AGREEMENT
dated as of
November 30, 2001
among
SIERRA PACIFIC RESOURCES,
UNION BANK OF CALIFORNIA, N.A.,
as Sole Bookrunner and Administrative Agent,
WELLS FARGO BANK, N.A.,
as Syndication Agent,
and
BANK ONE, NA,
BNP PARIBAS and
MELLON BANK, N.A.,
as Co-Documentation Agents,
and
the LENDERS party hereto from time to time
Co-Arranged By
UNION BANK OF CALIFORNIA, N.A. and
WELLS FARGO BANK, N.A.
TABLE OF CONTENTS
Page ---- ARTICLE I DEFINITIONS; CONSTRUCTION....................................1 SECTION 1.01 Defined Terms..........................................1 SECTION 1.02 Classification of Loans and Borrowings................15 SECTION 1.03 Terms Generally.......................................15 SECTION 1.04 Accounting Terms; GAAP................................16 ARTICLE II THE CREDITS.................................................16 SECTION 2.01 The Commitments.......................................16 SECTION 2.02 Loans and Borrowings..................................16 SECTION 2.03 Requests for Revolving Borrowings.....................17 SECTION 2.04 Funding of Borrowings.................................18 SECTION 2.05 Interest Elections....................................18 SECTION 2.06 Termination, Reduction and Extension of Commitments...19 SECTION 2.07 Repayment of Loans; Evidence of Debt..................22 SECTION 2.08 Prepayment of Loans...................................23 SECTION 2.09 Fees..................................................23 SECTION 2.10 Interest..............................................24 SECTION 2.11 Alternate Rate of Interest............................24 SECTION 2.12 Increased Costs.......................................25 SECTION 2.13 Break Funding Payments................................26 SECTION 2.14 Taxes.................................................26 SECTION 2.15 Payments Generally; Pro Rata Treatment; Sharing of Set-offs..............................................27 SECTION 2.16 Mitigation Obligations; Replacement of Lenders........29 ARTICLE III REPRESENTATIONS AND WARRANTIES..............................29 SECTION 3.01 Corporate Status......................................29 SECTION 3.02 Corporate Power and Authorization.....................30 SECTION 3.03 Execution and Binding Effect..........................30 SECTION 3.04 Governmental Approvals and Filings....................30 SECTION 3.05 Absence of Conflicts..................................30 SECTION 3.06 Audited Financial Statements..........................31 SECTION 3.07 Interim Financial Statements..........................31 SECTION 3.08 Absence of Undisclosed Liabilities....................31 SECTION 3.09 Absence of Material Adverse Change....................31 SECTION 3.10 Accurate and Complete Disclosure......................32 SECTION 3.11 Margin Regulations....................................32 SECTION 3.12 Litigation............................................32 SECTION 3.13 Absence of Events of Default..........................32 SECTION 3.14 Absence of Other Conflicts............................32 SECTION 3.15 Insurance.............................................33 SECTION 3.16 Title to Property; No Liens...........................33 SECTION 3.17 Taxes.................................................33 |
TABLE OF CONTENTS
(Continued)
Page ---- SECTION 3.18 Borrower Not An Investment Company; PUHCA Exemption...33 SECTION 3.19 Environmental Matters.................................34 SECTION 3.20 ERISA.................................................34 SECTION 3.21 Pari Passu Status.....................................35 SECTION 3.22 Indebtedness..........................................35 |
ARTICLE IV CONDITIONS..................................................36
SECTION 4.01 Effective Date........................................36
SECTION 4.02 Conditions to All Loans...............................38
ARTICLE V AFFIRMATIVE COVENANTS.......................................39
SECTION 5.01 Basic Reporting Requirements..........................39 SECTION 5.02 Insurance.............................................42 SECTION 5.03 Payment of Taxes and Other Potential Charges and Priority Claims.......................................42 SECTION 5.04 Preservation of Corporate Status and Franchises.......42 SECTION 5.05 Governmental Approvals and Filings....................43 SECTION 5.06 Maintenance of Properties.............................43 SECTION 5.07 Avoidance of Other Conflicts..........................43 SECTION 5.08 Financial Accounting Practices........................43 SECTION 5.09 Use of Proceeds.......................................43 SECTION 5.10 End of Fiscal Periods.................................44 |
ARTICLE VI NEGATIVE COVENANTS..........................................44
SECTION 6.01 Financial Covenants...................................44 SECTION 6.02 Liens.................................................44 SECTION 6.03 Mergers...............................................45 SECTION 6.04 Dispositions of Properties............................46 SECTION 6.05 Investments and Acquisitions..........................47 SECTION 6.06 Dividends and Stock Repurchases.......................47 SECTION 6.07 Transactions with Affiliates..........................47 SECTION 6.08 Change of Business....................................47 SECTION 6.09 Equal and Ratable Lien................................47 SECTION 6.10 Restrictive Agreements................................48 SECTION 6.11 Limitation on Indebtedness............................48 SECTION 6.12 Maintenance of Ownership of Significant Subsidiaries..48 |
ARTICLE VII DEFAULTS....................................................48
SECTION 7.01 Events of Default.....................................48
SECTION 7.02 Consequences of an Event of Default...................51
ARTICLE VIII THE AGENTS..................................................52
SECTION 8.01 Appointment...........................................52
SECTION 8.02 General Nature of Administrative Agent's Duties.......52
TABLE OF CONTENTS
(Continued)
Page ---- SECTION 8.03 Exercise of Powers....................................53 SECTION 8.04 General Exculpatory Provisions........................53 SECTION 8.05 Administration by the Administrative Agent............54 SECTION 8.06 Lenders Not Relying on Administrative Agent or Other Lenders.........................................55 SECTION 8.07 Indemnification.......................................55 SECTION 8.08 Administrative Agent in its Individual Capacity.......55 SECTION 8.09 Holders of Notes......................................56 SECTION 8.10 Successor Administrative Agent........................56 SECTION 8.11 Additional Administrative Agents......................57 SECTION 8.12 Calculations..........................................57 SECTION 8.13 Syndication Agent.....................................57 SECTION 8.14 Sole Bookrunner.......................................57 SECTION 8.15 Co-Documentation Agents...............................58 |
ARTICLE IX MISCELLANEOUS...............................................58
SECTION 9.01 Amendments and Waivers................................58 SECTION 9.02 No Implied Waiver; Cumulative Remedies................59 SECTION 9.03 Notices...............................................59 SECTION 9.04 Expenses; Taxes; Indemnity............................60 SECTION 9.05 Severability..........................................61 SECTION 9.06 Prior Understandings..................................61 SECTION 9.07 Duration; Survival....................................61 SECTION 9.08 Counterparts..........................................61 SECTION 9.09 Limitation on Payments................................61 SECTION 9.10 Set-Off...............................................62 SECTION 9.11 Sharing of Collections................................62 SECTION 9.12 Successors and Assigns; Participations; Assignments...63 SECTION 9.13 Governing Law; Submission to Jurisdiction Waiver of Jury Trial; Limitation of Liability................65 SCHEDULES --------- Schedule I COMMITMENTS Schedule II JURISDICTIONS Schedule III LITIGATION Schedule IV LIENS Schedule V ENVIRONMENTAL CLAIMS Schedule VI EXISTING INDEBTEDNESS EXHIBITS -------- Exhibit A FORM OF ASSIGNMENT AND ACCEPTANCE Exhibit B FORM OF BORROWING REQUEST Exhibit C FORM OF PROMISSORY NOTE |
iii-
TABLE OF CONTENTS
(Continued)
Exhibit D FORM OF QUARTERLY COMPLIANCE CERTIFICATE
CREDIT AGREEMENT, dated as of November 30, 2001, among SIERRA PACIFIC RESOURCES, a Nevada corporation, UNION BANK OF CALIFORNIA, N.A., as Sole Bookrunner and Administrative Agent, WELLS FARGO BANK, N.A., as Syndication Agent, BANK ONE, NA, BNP PARIBAS and MELLON BANK, N.A., as Co-Documentation Agents, the LENDERS party hereto from time to time and UNION BANK OF CALIFORNIA, N.A. and WELLS FARGO BANK, N.A., as Co-Lead Arrangers.
WHEREAS, the Borrower (as defined below) has requested, and the Lenders (as defined below) have agreed to make available, the credit facilities described below upon the terms and conditions contained herein.
NOW, THEREFORE, in consideration of the premises and of the mutual covenants herein contained and intending to be legally bound hereby, the parties hereto agree as follows:
ARTICLE I
DEFINITIONS; CONSTRUCTION
As used in this Agreement, the following terms have the following meanings:
A. Prior to the Occurrence of Both an Acceptable NPC Rate Case and an Acceptable SPPC Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ---------- ---------- ---------- ---------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- Eurodollar Spread 0.65% 0.875% 0.975% 1.05% 1.25% -------------------------------------------------------------------------------------------------------------------- ABR Spread 0% 0% 0% 0.05% 0.25% -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 3, 0.10% per annum, (B) in the case of Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum.
B. Upon and After the Occurrence of Both an Acceptable NPC Rate Case and an Acceptable SPPC Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ---------- ---------- ---------- ---------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- Eurodollar Spread 0.525% 0.75% 0.85% 0.925% 1.125% -------------------------------------------------------------------------------------------------------------------- ABR Spread 0% 0% 0% 0% 0.125% -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 4, 0.05% per annum, and (B) in the case of Category 5, 0.25% per annum.
For purposes of the foregoing pricing tables, (1) if either Moody's or S&P shall
not have in effect a rating for the Index Debt of Borrower (other than by reason
of the circumstances referred to in the last sentence of this definition), then
such rating agency shall be deemed to have established a rating in Category 5,
(2) if the ratings established or deemed to have been established by Moody's and
S&P for the Index Debt of Borrower shall be changed (other than as a result of a
change in the rating system of Moody's or S&P), such change shall be effective
as of two Business Days after it is first announced by the applicable rating
agency, (3) if more than one Category is applicable at any one time, the
Applicable Rate shall be based on the applicable Category having the lowest
number (i.e., Category 1 is lower than Category 2), and (4) upon the occurrence
of both an Acceptable NPC Rate Case and an Acceptable SPPC Rate Case and at all
times thereafter, the pricing table set forth above under the caption "Upon and
After the Occurrence of Both an Acceptable NPC Rate Case and an Acceptable SPPC
Rate Case" shall be effective. Each change in the Applicable Rate (including any
change based on the occurrence of both an Acceptable NPC Rate Case and an
Acceptable SPPC Rate Case) shall apply during the period commencing on the
effective date of such change and ending on the date immediately preceding the
effective date of the next such change. If the rating system of Moody's or S&P
shall change, or if either such rating agency shall cease to be in the business
of rating corporate
debt obligations, the Borrower and the Lenders shall negotiate in good faith to amend this definition to reflect such changed rating system or the unavailability of ratings from such rating agency and, pending the effectiveness of any such amendment, the Applicable Rate shall be determined by reference to the rating most recently in effect prior to such change or cessation.
Exchange Act of 1934 and the rules of the Securities and Exchange Commission thereunder as in effect on the date hereof) of shares representing more than 20% of the aggregate ordinary voting power represented by the issued and outstanding capital stock of the Borrower; or (b) for any period of 12 consecutive calendar months, a majority of the Board of Directors of the Borrower shall no longer be composed of individuals (i) who were members of said Board on the first day of such period, (ii) whose election or nomination to said Board was approved by individuals referred to in clause (i) above constituting at the time of such election or nomination at least a majority of said Board or (iii) whose election or nomination to said Board was approved by individuals referred to in clauses (i) and (ii) above constituting at the time of such election or nomination at least a majority of said Board.
financial condition of the primary obligor prior to such obligation being a stated or determinable amount, or (c) to purchase Property, securities or services primarily for the purpose of assuring the owner of any such primary obligation of the ability of the primary obligor to make payment of such primary obligation, or (d) otherwise to assure or hold harmless the holder of any such primary obligation against loss in respect thereof. The amount of any Contingent Obligation shall be deemed to be an amount equal to the stated or determinable amount of the primary obligation in respect of which such Contingent Obligation is made or, if not stated or if indeterminable, the maximum reasonably anticipated liability in respect thereof, except as specified in clause (b)(ii) above.
transactions with members of the Federal Reserve System arranged by Federal funds brokers, as published on the next succeeding Business Day by the Federal Reserve Bank of New York, or, if such rate is not so published for any day that is a Business Day, the average (rounded upwards, if necessary, to the next 1/100 of 1%) of the quotations for such day for such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by it.
a Borrowing initially shall be the date on which such Borrowing is made and, thereafter shall be the effective date of the most recent conversion or continuation of such Borrowing.
other nationally recognized securities rating agency approved for purposes hereof by the Required Lenders and the Borrower.
intercompany eliminations) of such Subsidiary as at the end of the Borrower's latest fiscal quarter exceeded 10% of the total assets of the Borrower and its Subsidiaries at such date, computed and consolidated in accordance with GAAP; or (c) the equity in the income from continuing operations before income taxes, extraordinary items and cumulative effect of a change in accounting principles of such Subsidiary for the period of four consecutive fiscal quarters ending at the end of the Borrower's latest fiscal quarter exceeded 10% of such income of the Borrower and its Subsidiaries for such period, computed and consolidated in accordance with GAAP; or (d) such Subsidiary is the parent of one or more other Subsidiaries of the Borrower and, together with such Subsidiaries, would, if considered in the aggregate, constitute a Significant Subsidiary pursuant to the foregoing clause (a), (b) or (c).
majority of the directors of such corporation (irrespective of whether or not at the time stock of any class or classes of such corporation shall have or might have voting power by reason of the happening of any contingency) is at the time owned by such Person and/or one or more Subsidiaries of such Person and (ii) any partnership, limited liability company, association, joint venture or other entity in which such Person and/or one or more Subsidiaries of such Person has more than a 50% equity interest at the time.
For purposes of this Agreement, Loans may be classified and referred to by Class (e.g., a "Revolving Loan") or by Type (e.g., a "Eurodollar Loan" or an "ABR Loan") or by Class and Type (e.g., a "Eurodollar Revolving Loan"). Borrowings also may be classified and referred to by Class (e.g., a "Revolving Borrowing") or by Type (e.g., a "Eurodollar Borrowing") or by Class and Type (e.g., a "Eurodollar Revolving Borrowing").
The definitions of terms herein shall apply equally to the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words "include", "includes" and
"including" shall be deemed to be followed by the phrase "without limitation". The word "will" shall be construed to have the same meaning and effect as the word "shall". Unless the context requires otherwise (a) any definition of or reference to any agreement, instrument or other document herein shall be construed as referring to such agreement, instrument or other document as from time to time amended, supplemented or otherwise modified (subject to any restrictions on such amendments, supplements or modifications set forth herein), (b) any reference herein to any Person shall be construed to include such Person's successors and assigns, (c) the words "herein", "hereof" and "hereunder", and words of similar import, shall be construed to refer to this Agreement in its entirety and not to any particular provision hereof and (d) all references herein to Articles, Sections, Exhibits and Schedules shall be construed to refer to Articles and Sections of, and Exhibits and Schedules to, this Agreement.
Except as otherwise expressly provided herein, all terms of an accounting or financial nature shall be construed in accordance with GAAP, as in effect from time to time.
ARTICLE II
THE CREDITS
To request a Revolving Borrowing, the Borrower shall notify the Administrative Agent of such request by telephone (a) in the case of a Eurodollar Revolving Borrowing, not later than 12:00 noon, New York, New York time, three Business Days before the date of the proposed Borrowing, or (b) in the case of an ABR Borrowing, not later than 12:00 noon, New York, New York time, one Business Day before the date of the proposed Borrowing. Each such telephonic Borrowing Request shall be irrevocable and shall be confirmed promptly by hand delivery or telecopy to the Administrative Agent of a written Borrowing Request in the form attached hereto as Exhibit B and signed by the Borrower. Each such telephonic and written Borrowing Request shall specify the following information in compliance with Section 2.02:
(i) the aggregate amount of the requested Borrowing;
(ii) the date of such Borrowing, which shall be a Business Day;
(iii) whether such Borrowing is to be an ABR Borrowing or a Eurodollar Borrowing;
(iv) in the case of a Eurodollar Borrowing, the initial Interest Period to be applicable thereto, which shall be a period contemplated by the definition of the term "Interest Period"; and
(v) the location and number of the Borrower's account to which funds are to be disbursed, which shall comply with the requirements of Section 2.04.
If no election as to the Type of Revolving Borrowing is specified, then the requested Revolving Borrowing shall be an ABR Borrowing. If no Interest Period is specified with respect to any Eurodollar Revolving Borrowing, then the Borrower shall be deemed to have selected an Interest Period of one month's duration. Promptly following receipt of a Borrowing Request in accordance with this Section, the Administrative Agent shall advise each Lender of
the details thereof and of the amount of such Lender's Loan to be made as part of the requested Borrowing.
(i) the Borrowing to which such Interest Election Request applies and, if different options are being elected with respect to different portions thereof, the portions thereof to be allocated to each resulting Borrowing (in which case the information to be specified pursuant to clauses (iii) and (iv) of this paragraph shall be specified for each resulting Borrowing);
(ii) the effective date of the election made pursuant to such Interest Election Request, which shall be a Business Day;
(iii) whether the resulting Borrowing is to be an ABR Borrowing, or a Eurodollar Borrowing; and
(iv) if the resulting Borrowing is a Eurodollar Borrowing, the Interest Period to be applicable thereto after giving effect to such election, which shall be a period contemplated by the definition of the term "Interest Period".
If any such Interest Election Request requests a Eurodollar Borrowing but does not specify an Interest Period, then the Borrower shall be deemed to have selected an Interest Period of one month's duration.
with Section 2.08, the sum of the total Revolving Credit Exposures would exceed the total Commitments.
(x) if Lenders having Commitments totaling an
amount equal to at least 51% of the aggregate amount of the
Commitments then in effect do not agree as contemplated by
Section 2.06(e)(i), then the Revolving Termination Date shall
not be extended pursuant to this Section 2.06(e) and the
Commitments of all
of the Lenders shall remain in effect until the Revolving Termination Date except as otherwise provided in this Agreement; and
(y) the Borrower may not request any extension of the Revolving Termination Date pursuant to this Section 2.06(e)(i) more frequently than once in any calendar year.
(ii) Any Loan by any Lender the Commitment of which is to terminate pursuant to Section 2.06(e)(i) hereof that would otherwise be made or converted by such Lender as a Eurodollar Loan having an Interest Period ending after the date such Commitment is to terminate shall be made or continued as an ABR Loan and all ABR Loans of such Lender that would otherwise be converted into Eurodollar Loans having such Interest Periods shall remain as ABR Loans.
(iii) It shall be a condition precedent to any
extension of the Revolving Termination Date that: (a) on the date of such
extension no Default or Event of Default shall have occurred and be continuing;
(b) the representations and warranties made by the Borrower in Article III
shall be true and correct on and as of the date of such extension (or if any
such representation or warranty is expressly stated to have been made as of a
specific date, as of such specific date); and (c) on the date of such extension
there shall have been no material adverse change in the consolidated financial
condition, operations, business or prospects taken as a whole of the Borrower
and its Subsidiaries from that set forth in its financial statements as of
September 30, 2001 referred to in Section 3.06 hereof or, if the Borrower has
delivered its financial statements for any fiscal year to the Lenders and the
Administrative Agent pursuant to Section 5.01(a) hereof, as of the date of the
most recent such financial statements. Each request for an extension of the
Revolving Termination Date pursuant to Section 2.06(e) shall constitute a
certification by the Borrower to the effect set forth in the preceding sentence
(both as of the date of such request and, unless the Borrower notifies the
Administrative Agent prior to the date of such extension, as of the date of
such extension).
Lender) to the extent of the Commitments, Loans and Notes assumed and purchased, the Substitute Lender shall succeed to the rights, obligations and benefits of such Lender hereunder in such respect (except for such rights, obligations and benefits of the Lender as have accrued (other than principal, accrued interest or facility fees) or are required to be performed by it on or prior to the date of such assumption and purchase) (and such Lender shall be released from its Commitment except for any liability arising or relating to any event occurring prior to the date of such assumption and purchase) and the Substitute Lender shall be deemed to have agreed to the relevant extension of the Revolving Termination Date and, anything in Section 2.06(e) to the contrary notwithstanding, whether such extension is effective shall be determined accordingly; provided that following any such assumption and purchase the Commitments of each Substitute Lender (including any Commitments theretofore held by it) shall be not less than $10,000,000.
(a) the Administrative Agent determines (which determination shall be conclusive, absent manifest error) that adequate and reasonable means do not exist for ascertaining the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period; or
(b) the Administrative Agent is advised by the Required Lenders that the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period will not adequately
and fairly reflect the cost to such Lenders (or Lender) of making or maintaining their Loans (or its Loan) included in such Borrowing for such Interest Period;
then the Administrative Agent shall give notice thereof to the Borrower and the Lenders by telephone or telecopy as promptly as practicable thereafter and, until the Administrative Agent notifies the Borrower and the Lenders that the circumstances giving rise to such notice no longer exist, (i) any Interest Election Request that requests the conversion of any Borrowing to, or continuation of any Borrowing as, a Eurodollar Borrowing shall be ineffective, and (ii) if any Borrowing Request requests a Eurodollar Revolving Borrowing, such Borrowing shall be made as an ABR Revolving Borrowing.
(i) impose, modify or deem applicable any reserve, special deposit or similar requirement against assets of, deposits with or for the account of, or credit extended by, any Lender or its Parent (except any such reserve requirement reflected in the Adjusted LIBO Rate); or
(ii) impose on any Lender or its Parent or the London interbank market any other condition affecting this Agreement or Eurodollar Loans made by such Lender;
and the result of any of the foregoing shall be to increase the cost to such Lender or its Parent of making or maintaining any Eurodollar Loan (or of maintaining its obligation to make any such Loan) or to reduce the amount of any sum received or receivable by such Lender hereunder (whether of principal, interest or otherwise), then the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or its Parent, as the case may be, for such additional costs incurred or reduction suffered.
Taxes or Other Taxes were correctly or legally imposed or asserted by the relevant Governmental Authority. A certificate as to the amount of such payment or liability delivered to the Borrower by a Lender, a Co-Lead Arranger, the Syndication Agent or the Administrative Agent (on its own behalf or on behalf of a Lender, a Co-Lead Arranger or the Syndication Agent) shall be conclusive, absent manifest error.
Commitments of the Lenders, pro rata according to the amounts of their respective Commitments; (ii) each Borrowing shall be allocated pro rata among the Lenders according to the amounts of their respective Commitments (in the case of the making of Revolving Loans) or their respective Loans (in the case of conversions and continuations of Loans); (iii) each payment or prepayment of principal of Loans by the Borrower shall be made for the account of the Lenders pro rata in accordance with the respective unpaid principal amounts of the Loans held by them; and (iv) each payment of interest on Loans by the Borrower shall be made for the account of the Lenders pro rata in accordance with the amounts of interest on such Loans then due and payable to the respective Lenders.
ARTICLE III
REPRESENTATIONS AND WARRANTIES
The Borrower hereby represents and warrants to the Administrative Agent and each Lender as follows:
The Borrower and each Significant Subsidiary is a corporation, trust or limited liability company duly organized, validly existing and in good standing under the Laws of its jurisdiction of organization. The Borrower and each Significant Subsidiary has the power (corporate or otherwise) and authority to own its Property and to transact the business in which it is engaged or presently proposes to engage. The Borrower and each Significant Subsidiary is duly qualified to do business as a foreign corporation, trust or limited liability company and is in good standing in all jurisdictions in which the ownership of its Properties or the nature of its activities or both makes such qualification necessary or advisable. Schedule II states as of the
date hereof the jurisdiction of organization of the Borrower and each Subsidiary of the Borrower, and the jurisdictions in which the Borrower and each Subsidiary of the Borrower is qualified to do business as a foreign corporation, trust or limited liability company.
The Borrower has the corporate power and authority to execute, deliver, perform, and take all actions contemplated by this Agreement and each of the other Loan Documents to which it is a party, and all such actions have been duly and validly authorized by all necessary corporate proceedings on its part. Without limiting the foregoing, the Borrower has the corporate power and authority to borrow pursuant to the Loan Documents to the fullest extent permitted hereby and thereby from time to time, and has taken all necessary corporate action to authorize such borrowings.
This Agreement and each of the other Loan Documents to which the Borrower is a party and which is required to be delivered on or before the Effective Date pursuant to Section 4.01 has been duly and validly executed and delivered by the Borrower. This Agreement and each such other Loan Document constitutes, and when executed and delivered by the Borrower will constitute, the legal, valid and binding obligation of the Borrower, enforceable against the Borrower in accordance with its terms, except as the enforceability hereof or thereof may be limited by bankruptcy, insolvency or other similar laws of general application affecting the enforcement of creditors' rights or by general principles of equity limiting the availability of equitable remedies.
No Governmental Action is required for the due execution, delivery and performance by the Borrower of this Agreement or any of the other Loan Documents to which it is a party.
Neither the execution and delivery of any of the Loan Documents by the Borrower, nor the consummation of the transactions herein or therein contemplated by the Borrower, nor the performance of or the compliance with the terms and conditions hereof or thereof by the Borrower, does or will:
(a) violate or conflict with any Law; or
(i) the articles of incorporation or by-laws (or other constituent documents) of the Borrower or any Subsidiary of the Borrower;
(ii) any agreement or instrument creating, evidencing or securing any Indebtedness to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound; or
(iii) any other material agreement or instrument to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders consolidated balance sheets of the Borrower and its consolidated Subsidiaries as of December 31, 1998, 1999 and 2000 and the related consolidated statements of income, retained earnings and changes in cash flows for the fiscal years then ended, as examined and reported on by independent certified public accountants for the Borrower, who delivered an unqualified opinion in respect thereof. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of each such fiscal year and the results of their operations and their retained earnings and changes in cash flows for the fiscal years then ended, all in conformity with GAAP.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders an interim consolidated balance sheet of the Borrower and its consolidated Subsidiaries as of the end of the third fiscal quarter of the fiscal year beginning January 1, 2001, together with the related consolidated statements of income, retained earnings and changes in cash flows for the applicable fiscal period ending on such date. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of such fiscal quarter and the results of their operations and their retained earnings and changes in cash flows for the fiscal periods then ended, all in conformity with GAAP, subject to normal and recurring year-end audit adjustments.
Neither the Borrower nor any Subsidiary of the Borrower has
any liability or obligation of any nature whatever (whether absolute, accrued,
contingent or otherwise, whether or not due), forward or long-term commitments
or unrealized or anticipated losses from unfavorable commitments, except (a) as
disclosed in the financial statements referred to in Sections 3.06 and 3.07, and
(b) liabilities, obligations, commitments and losses incurred after September
30, 2001, in the ordinary course of business and consistent with past practices.
Since September 30, 2001, there has been no material adverse change in the business, operations, condition (financial or otherwise), or prospects of the Borrower and its Subsidiaries taken as a whole.
All information heretofore, contemporaneously or hereafter provided by or on behalf of the Borrower to any Agent or any Lender pursuant to or in connection with any Loan Document or any transaction contemplated hereby or thereby is or will be (as the case may be) true and accurate in all material respects on the date as of which such information is dated (or, if not dated, when received by such Agent or such Lender) and does not or will not (as the case may be) omit to state any material fact necessary to make such information not misleading at such time in light of the circumstances in which it was provided. The Borrower has disclosed to each Agent and each Lender in writing every fact or circumstance which has, or which so far as the Borrower can reasonably foresee is reasonably likely and is reasonably likely to have, a Material Adverse Effect.
No part of the proceeds of any Loan hereunder will be used for the purpose of buying or carrying any "margin stock", as such term is used in Regulation U of the Board, as amended from time to time, or to extend credit to others for the purpose of buying or carrying any "margin stock". Neither the Borrower nor any Subsidiary of the Borrower is engaged in the business of extending credit to others for the purpose of buying or carrying "margin stock". Neither the Borrower nor any Subsidiary of the Borrower owns any "margin stock". Neither the making of any Loan nor any use of proceeds of any such Loan will violate or conflict with the provisions of Regulation T, U or X of the Board, as amended from time to time.
There is no pending or (to the Borrower's knowledge after due inquiry) threatened action, suit, proceeding or investigation (including any Environmental Claim) by or before any Governmental Authority against or affecting the Borrower or any Subsidiary of the Borrower which, if adversely decided, individually or in the aggregate, would reasonably be expected to have a Material Adverse Effect, except for (a) matters described in the financial statements referred to in Section 3.06 and (b) matters set forth in Schedule III.
No event has occurred and is continuing and no condition exists which constitutes a Default or an Event of Default.
Neither the Borrower nor any Subsidiary of the Borrower is in violation of or conflict with, or is subject to any contingent liability on account of any violation of or conflict with:
(a) any Law (including ERISA, the Code, any applicable occupational health, safety or welfare Law or any applicable Environmental Law);
(b) its articles of incorporation or by-laws (or other constituent documents); or
(c) any agreement or instrument to which it is party or which it or any of its properties (now owned or hereafter acquired) may be subject or bound;
except for matters which, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.
The Borrower and each Subsidiary of the Borrower maintains with financially sound and reputable insurers insurance with respect to its properties and business and against at least such liabilities, casualties and contingencies and in at least such types and amounts as is customary in the case of corporations engaged in the same or a similar business or having similar properties similarly situated.
The Borrower and each Subsidiary of the Borrower has good and
marketable title in fee simple to all real Property owned or purported to be
owned by it and good title to all other Property of whatever nature owned or
purported to be owned by it, including but not limited to all Property reflected
in the most recent audited balance sheet referred to in Section 3.06 or
submitted pursuant to Section 5.01(b), as the case may be (except as sold or
otherwise disposed of in the ordinary course of business after the date of such
balance sheet), subject to no Liens except for (i) Liens reflected in the most
recent audited balance sheet referred to in Section 3.06 or submitted pursuant
to Section 5.01(b), as the case may be, (ii) Liens consisting of zoning or
planning restrictions, easements, permits and other restrictions or limitations
on the use of real Property or irregularities in title thereto which do not
materially detract from the value of, or impair the use of, such Property by the
Borrower or any Subsidiary of the Borrower in the operation of its business,
(iii) Liens for current Taxes not yet due and delinquent and (iv) Liens set
forth on Schedule IV.
All tax and information returns required to be filed by or on behalf of the Borrower or any Subsidiary of the Borrower have been properly prepared, executed and filed. All Taxes upon the Borrower or any Subsidiary of the Borrower or upon any of their respective Properties, incomes, sales or franchises which are due and payable have been paid, other than those not yet delinquent and payable without premium or penalty, and except for those being diligently contested in good faith by appropriate proceedings, and in each case adequate reserves and provisions for Taxes have been made on the books of the Borrower and each Subsidiary of the Borrower. The reserves and provisions for Taxes on the books of the Borrower and each Subsidiary of the Borrower are adequate for all open years and for its current fiscal period. Neither the Borrower nor any Subsidiary of the Borrower knows of any proposed additional assessment or basis for any material assessment for additional Taxes (whether or not reserved against).
Neither the Borrower nor any Subsidiary of the Borrower is an "investment company" or a company controlled by an "investment company" within the meaning of the Investment Company Act of 1940. The Borrower is a "holding company" within the meaning of
(a) The Borrower and each of its Subsidiaries have complied with and are in compliance with, all applicable Environmental Laws and the requirements of any permits issued under such Environmental Laws. Except as disclosed on Schedule V, there are no pending or threatened Environmental Claims against the Borrower or any of its Subsidiaries (including any such claim arising out of the ownership, lease or operation by the Borrower or any of its Subsidiaries of any real Property no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries. Except as disclosed on Schedule V, there are no facts, circumstances, conditions or occurrences with respect to the business or operations of the Borrower or any of its Subsidiaries, or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries (including any real Property formerly owned, leased or operated by the Borrower or any of its Subsidiaries but no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any Property adjoining or adjacent to any such real Property that could be expected (i) to form the basis of an Environmental Claim against the Borrower or any of its Subsidiaries or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries or (ii) to cause any real Property owned, leased or operated by the Borrower or any of its Subsidiaries to be subject to any restrictions on the ownership, occupancy or transferability of such real Property by the Borrower or any of its Subsidiaries under any applicable Environmental Law.
(b) Hazardous Materials have not at any time been generated, used, treated or stored on, or transported to or from, any real Property owned, leased or operated by the Borrower or any of its Subsidiaries where such generation, use, treatment or storage has violated or could be expected to violate any Environmental Law. Hazardous Materials have not at any time been Released on or from any real Property owned, leased or operated by Borrower or any of its Subsidiaries where such Release has violated or would be expected to violate any applicable Environmental Law.
(c) Notwithstanding anything to the contrary in this Section, the representations made in this Section shall not be untrue unless the effect of all violations, claims, restrictions, failures and noncompliances of the types described in this Section would reasonably be expected to, individually or in the aggregate, have a Material Adverse Effect.
(a) Each Plan (and each related trust, insurance contract or fund) is in substantial compliance with its terms and with all applicable Laws, including without limitation ERISA and the Code; each Plan (and each related trust, if any) which is intended to be qualified under Section 401(a) of the Code has received a determination letter from the Internal Revenue Service to the effect that it meets the requirements of Sections 401(a) and 501(a) of the Code; no Reportable Event has occurred; no Multiemployer Plan is insolvent or in reorganization; no Plan has an Unfunded Current Liability; no Plan which is subject to Section 412 of the
Code or Section 302 of ERISA has an accumulated funding deficiency within the
meaning of such sections of the Code or ERISA or has applied for or received a
waiver of an accumulated funding deficiency or an extension of any amortization
period within the meaning of Section 412 of the Code or Section 303 or 304 of
ERISA; all contributions required to be made with respect to a Plan have been
timely made; neither the Borrower nor any Subsidiary of the Borrower nor any
ERISA Affiliate has incurred any material liability (including any indirect,
contingent or secondary liability) to or on account of a Plan pursuant to
Section 409, 502(i), 502(l), 515, 4062, 4063, 4064, 4069, 4201, 4204 or 4212 of
ERISA or Section 401(a)(29), 4971 or 4975 of the Code or expects to incur any
such liability under any of the foregoing sections with respect to any Plan; no
condition exists which presents a material risk to the Borrower or any
Subsidiary of the Borrower or any ERISA Affiliate of incurring a liability to
or on account of a Plan pursuant to the foregoing provisions of ERISA and the
Code; no proceedings have been instituted to terminate or appoint a trustee to
administer any Plan; no action, suit, proceeding, hearing, audit or
investigation with respect to the administration, operation or the investment
of assets of any Plan (other than routine claims for benefits) is pending,
expected or threatened; using actuarial assumptions and computation methods
consistent with Part 1 of subtitle E of Title IV of ERISA, the aggregate
liabilities of the Borrower and its Subsidiaries and its ERISA Affiliates to
all Multiemployer Plans in the event of a complete withdrawal therefrom, as of
the close of the most recent fiscal year of each such Plan ended prior to the
date of the most recent Borrowing, would not have a Material Adverse Effect;
each group health plan (as defined in Section 607(1) of ERISA or Section
4980B(g)(2) of the Code) which covers or has covered employees or former
employees of the Borrower, any Subsidiary of the Borrower, or any ERISA
Affiliate has at all times been operated in compliance with the provisions of
Part 6 of subtitle B of Title I of ERISA and Section 4980B of the Code; no Lien
imposed under the Code or ERISA on the assets of the Borrower or any Subsidiary
of the Borrower or any ERISA Affiliate exists or is likely to arise on account
of any Plan; and the Borrower and its Subsidiaries may cease contributions to
or terminate any Plan maintained by any of them without incurring any material
liability.
(b) Each Foreign Pension Plan, if any, has been maintained in substantial compliance with its terms and with the requirements of any and all applicable Laws, statutes, rules, regulations and orders and has been maintained, where required, in good standing with applicable regulatory authorities. All contributions required to be made with respect to a Foreign Pension Plan have been timely made. Neither the Borrower nor any of its Subsidiaries has incurred any obligation in connection with the termination of or withdrawal from any Foreign Pension Plan. The present value of the accrued benefit liabilities (whether or not vested) under each Foreign Pension Plan, determined as of the end of the Borrower's most recently ended fiscal year on the basis of actuarial assumptions, each of which is reasonable, did not exceed the current value of the assets of such Foreign Pension Plan allocable to such benefit liabilities.
The claims and rights of the Lenders against the Borrower hereunder are not subordinated to, but rank at least pari passu with, the claims and rights of other holders of its unsecured indebtedness except to the extent otherwise provided by Law (including without limitation the Bankruptcy Code and the provisions of 31 U.S.C. [sec] 3713).
ARTICLE IV
CONDITIONS
This Agreement and the other Loan Documents shall become effective as against the Lenders and the Agents on the first date on which all of the following conditions shall be satisfied or waived:
(i) Each of the representations and warranties made by the Borrower herein and in each other Loan Document shall be true and correct in all material respects on and as of the Effective Date as if made on and as of such date, both before and after giving effect to the Loans requested to be made on such date.
(ii) No Default or Event of Default shall have occurred and be continuing on the Effective Date.
The obligation of each Lender to make, convert or continue any Loan on the occasion of any Borrowing is subject to satisfaction of the conditions precedent set forth in Section 4.01 and satisfaction of the following further conditions precedent:
Each request by the Borrower for any Loan or conversion or continuation thereof shall constitute a representation and warranty by the Borrower that the conditions set forth in this Section 4.02 have been satisfied as of the date of such request. Failure of the Administrative Agent to receive notice from the Borrower to the contrary before such Loan is made shall constitute a further representation and warranty by the Borrower that the conditions referred to in this Section 4.02 have been satisfied as of the date such Loan is made.
ARTICLE V
AFFIRMATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender:
retained earnings and changes in cash flows for such fiscal year, in conformity with GAAP, subject to normal and recurring year-end audit adjustments.
(i) Any Default or Event of Default.
(ii) The occurrence or existence of any event or condition (including (A) the violation or alleged violation of any Environmental Law by the Borrower or any Subsidiary of the Borrower or the assertion of any Environmental Claim against the Borrower or any Subsidiary of the Borrower, (B) the commencement of any other action, suit, proceeding or investigation by or before any Governmental Authority against or affecting the Borrower or any Subsidiary of the Borrower, or (C) the violation, breach or default or alleged violation, breach or default by the Borrower or any Subsidiary of the Borrower or any other Person under any agreement or instrument material to the business, operations, condition (financial or otherwise) or prospects of the Borrower and its Subsidiaries taken as a whole) which event or condition, either individually or in the aggregate, has, or would reasonably be expected to have, a Material Adverse Effect.
(iii) Any change in the rating of the Index Debt of the Borrower.
Borrower reserves the right to restrict access to any of its generating facilities in accordance with reasonably adopted practices relating to safety and security. The Borrower hereby authorizes such officers, employees and independent accountants to discuss with the Administrative Agent or any Lender the affairs of the Borrower and its Subsidiaries.
(i) any Reportable Event and any request for a waiver under Section 412(d) of the Code for any Plan;
(ii) the distribution under Section 4041 of ERISA of a notice of intent to terminate any Plan or any action taken by the Borrower or an ERISA Affiliate to terminate any Plan, in each case with respect to which there are insufficient assets to pay benefits as they become due;
(iii) the institution by the PBGC of proceedings under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan, or the receipt by the Borrower or any ERISA Affiliate of a notice from a Multiemployer Plan that such action has been taken by the PBGC with respect to such Multiemployer Plan;
(iv) the complete or partial withdrawal from a Multiemployer Plan by the Borrower or any ERISA Affiliate that results in liability under Section 4201 or 4204 of ERISA (including the obligation to satisfy secondary liability as a result of a purchaser default) or the receipt by the Borrower or any ERISA Affiliate of notice from a Multiemployer Plan that it is in reorganization or insolvency pursuant to Section 4241 or 4245 of ERISA or that it intends to terminate or has terminated under Section 4041A of ERISA; and
(v) the adoption of an amendment to any Plan that, pursuant to Section 401(a)(29) of the Code or Section 307 of ERISA, would result in the loss of tax-exempt status of the trust of which such Plan is a part if the Borrower or an ERISA Affiliate fails to timely provide security to the Plan in accordance with the provisions of said Sections.
The Borrower shall, and shall cause each of its Subsidiaries to, maintain with financially sound and reputable insurers insurance with respect to its properties and business and against such liabilities, casualties and contingencies and of such types and in such amounts as is customary in the case of corporations engaged in the same or similar businesses or having similar properties similarly situated and as is satisfactory from time to time to the Required Lenders in their reasonable discretion.
The Borrower shall, and shall cause each of its Subsidiaries to, pay or discharge
(a) on or prior to the date on which penalties or Liens attach thereto, all Taxes imposed upon it or any of its Properties;
(b) on or prior to the date when due, all lawful claims of materialmen, mechanics, carriers, warehousemen, landlords and other like Persons which, if unpaid, might result in the creation of a Lien upon any such Property; and
(c) on or prior to the date when due, all other lawful claims which, if unpaid, might result in the creation of a Lien upon any such Property or which, if unpaid, might give rise to a claim entitled to priority over general creditors of the Borrower or such Subsidiary in a case under the Bankruptcy Code;
The Borrower shall keep and maintain in full force and effect all Governmental Actions necessary or advisable in connection with execution and delivery of any Loan Document, consummation of the transactions herein or therein contemplated, performance of or compliance with the terms and conditions hereof or thereof or to ensure the legality, validity, binding effect or enforceability hereof or thereof.
The Borrower shall, and shall cause each Significant Subsidiary to, maintain or cause to be maintained in good repair, working order and condition the properties now or hereafter owned, leased or otherwise possessed by it and shall make or cause to be made all needful and proper repairs, renewals, replacements and improvements thereto so that the business carried on in connection therewith may be properly and advantageously conducted at all times.
The Borrower shall not, and shall not permit any of its Subsidiaries to, violate or conflict with, be in violation of or in conflict with, or be or remain subject to any liability (contingent or otherwise) on account of any violation or conflict with:
(a) any Law;
(b) its articles of incorporation or by-laws; or
(c) any agreement or instrument to which it or any of its Subsidiaries is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound,
except for matters which would not reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
The Borrower shall, and shall cause each of its Subsidiaries to, make and keep books, records and accounts which, in reasonable detail, accurately and fairly reflect its transactions and dispositions of its assets and maintain a system of internal accounting controls sufficient to provide reasonable assurances that (a) transactions are executed in accordance with management's general or specific authorization, (b) transactions are recorded as necessary (i) to permit preparation of financial statements in conformity with GAAP and (ii) to maintain accountability for assets, (c) access to assets is permitted only in accordance with management's general or specific authorization and (d) the recorded accountability for assets is compared with the existing assets at reasonable intervals and appropriate action is taken with respect to any differences.
The Borrower shall apply the proceeds of all Loans hereunder only for working capital and general corporate purposes of the Borrower, including commercial paper backup.
The Borrower shall not use the proceeds of any Loans hereunder directly or indirectly for any unlawful purpose, in any manner inconsistent with Section 3.11, or inconsistent with any other provision of any Loan Document.
The Borrower shall cause (a) each of its, and each of its Subsidiary's, fiscal years to end on December 31 and (b) each of its, and each of its Subsidiary's, fiscal quarters to end on March 31, June 30, September 30 and December 31.
ARTICLE VI
NEGATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender as follows:
(a) Liens existing on the date hereof and securing obligations existing on the date hereof, as such Liens and obligations are listed on Schedule IV;
(b) Liens securing obligations of NPC issued under and pursuant to the terms and conditions of either (i) the NPC First Mortgage Indenture or (ii) the NPC General and Refunding Mortgage Indenture;
(c) Liens securing obligations of SPPC issued under and pursuant to the terms and conditions of either (i) the SPPC First Mortgage Indenture or (ii) the SPPC General and Refunding Mortgage Indenture;
(f) Liens on SPPC First Mortgage Bonds issued as collateral for medium-term notes issued pursuant to the Collateral Trust Indenture, dated as of June 1, 1992, between SPPC and Bankers Trust Company, as Trustee;
(g) Liens on "transition property" arising pursuant to
Section 843 of the California Public Utility Code for the benefit of
holders of rate reduction bonds issued pursuant to a valid financing
order of the California Public Utilities Commission;
(h) Liens arising from taxes, assessments, charges or claims described in Section 5.03 that are not yet due or that remain payable without penalty or to the extent permitted to remain unpaid under the proviso to such Section 5.03;
(i) Deposits or pledges of cash or securities in the ordinary course of business to secure (i) worker's compensation, unemployment insurance or other social security obligations, (ii) performance of bids, tenders, trade contracts (other than for payment of money) or leases, (iii) stay, surety or appeal bonds, or (iv) other obligations of a like nature incurred in the ordinary course of business;
(j) Zoning restrictions, easements, minor restrictions on the use of real Property, minor irregularities in title thereto and other minor Liens that do not secure the payment of money or the performance of an obligation and that do not in the aggregate materially detract from the value of an asset to, or materially impair its use in the business of, the Borrower or such Subsidiary; and
"Permitted Liens" shall in no event include any Lien imposed by, or required to be granted pursuant to, ERISA or any Environmental Law.
The Borrower shall not, and shall not permit any of its
Subsidiaries to, (a) merge with or into or consolidate with any other Person,
(b) liquidate, wind-up, dissolve or divide, or
(c) agree, become or remain liable (contingently or otherwise) to do any of the foregoing, except that:
all Property Disposed of pursuant to this Section 6.04(d) from and after the date hereof shall not exceed $120,000,000.
Prior to the making of any Investment or the consummation of any Acquisition by the Borrower or any of its Subsidiaries, the amount or purchase price of which, as the case may be, when aggregated with the amounts and purchase prices of other Investments and Acquisitions made by the Borrower and its Subsidiaries, would exceed $70,000,000 in the aggregate at any time, the Borrower shall deliver to the Administrative Agent (i) a certificate, in a form reasonably satisfactory to the Administrative Agent, certifying that no Default or Event of Default exists or will result from such Acquisition and (ii) pro forma financial statements in support of such certification.
The Borrower shall not declare or pay any dividend on its capital stock (except for dividends in the form of capital stock), or redeem or repurchase any of its capital stock, if a Default or Event of Default shall have occurred and be continuing or shall exist at such time or after giving effect to such transaction.
The Borrower shall not enter into any transaction of any kind with any Person that Controls the Borrower or is Controlled by the Borrower or is under common Control with the Borrower other than (a) salary, bonus, employee stock option and other compensation arrangements with directors or officers in the ordinary course of business, (b) transactions that are fully disclosed to the board of directors (or executive committee thereof) of the Borrower and expressly authorized by a resolution of the board of directors (or executive committee) of the Borrower which is approved by a majority of the directors (or executive committee) not having an interest in the transaction, (c) transactions between or among the Borrower and its Wholly-Owned Subsidiaries and (d) transactions on overall terms at least as favorable to the Borrower as would be the case in an arm's-length transaction between unrelated parties of equal bargaining power.
The Borrower shall not make any material change in the nature of its business as carried on at the date hereof.
If, notwithstanding the prohibition contained in Section 6.02, the Borrower or any of its Subsidiaries is subjected to any Lien upon any of its Property, other than those permitted by the provisions of Section 6.02, the Borrower will, and will cause its Subsidiaries to, make or cause to be made effective provisions whereby the Borrowings will be secured equally and ratably with any and all other obligations thereby secured, such security to be pursuant to agreements reasonably satisfactory to the Administrative Agent and, in any such case, the Borrowings shall have the benefit, to the fullest extent that, and with such priority as, the Lenders may be entitled under applicable law, of an equitable Lien on such Property. Such
violation of Section 6.02 will constitute an Event of Default, whether or not provision is made for an equal and ratable Lien pursuant to this Section 6.09, and no such Lien or agreements with respect thereto shall be deemed to be a waiver of or consent to such Event of Default by the Administrative Agent or any Lender.
Except as otherwise permitted under this Article VI, and except for agreements referenced in or permitted by covenants contained within Article VI of the NPC Credit Agreement and Article VI of the SPPC Credit Agreement, the Borrower will not, and will not permit any of its Subsidiaries to, directly or indirectly, enter into, incur or permit to exist any agreement or other arrangement that prohibits, restricts or imposes any condition upon (a) the ability of the Borrower or any of its Subsidiaries to create, incur or permit to exist any Lien upon any of its Property or assets, or (b) the ability of any Subsidiary of the Borrower to pay dividends or other distributions with respect to any shares of its capital stock or to make or repay loans or advances to the Borrower or any other Subsidiary or to guarantee Indebtedness of the Borrower or any other Subsidiary of the Borrower.
The Borrower shall not create, incur, assume or suffer to exist any Indebtedness (including, without limitation, any Contingent Obligations, the Loans and any senior notes issued in connection with the Borrower's Corporate Premium Income Equity Securities (PIES)), or become or remain liable (contingently or otherwise) for any Indebtedness, in excess of $1,045,000,000 in the aggregate at any one time outstanding.
The Borrower (a) shall not, and shall not permit any of its Subsidiaries to, sell, transfer, assign or otherwise dispose of any shares of common stock of any Significant Subsidiary, any securities convertible into shares of common stock of any Significant Subsidiary or any warrants, rights or options to acquire such common stock or such convertible securities, and (b) shall not permit any Significant Subsidiary to issue any shares of common stock, any securities convertible into shares of common stock or any warrants, rights or options to acquire any such common stock or convertible securities, to any other Person (other than the Borrower or any Wholly-Owned Subsidiary of the Borrower).
ARTICLE VII
DEFAULTS
(a) The Borrower shall fail to pay when due principal of any Loan.
(b) The Borrower shall fail to pay when due interest on any Loan, any fees, indemnity or expenses, or any other amount due hereunder or under any other Loan Document and such failure shall have continued for a period of three (3) Business Days.
(c) Any representation or warranty made or deemed made by the Borrower in or pursuant to or in connection with any Loan Document, or any statement made by the Borrower in any financial statement, certificate, report, exhibit or document furnished by the Borrower to the Administrative Agent or any Lender pursuant to or in connection with any Loan Document, shall prove to have been false or misleading in any material respect as of the time when made or deemed made (including by omission of material information necessary to make such representation, warranty or statement not misleading).
(d) The Borrower shall default in the performance or observance of any covenant contained in Article VI or any of the covenants contained in Section 5.01(f)(i), 5.09 or 5.10.
(e) The Borrower shall default in the performance or observance of any other covenant, agreement or duty under this Agreement or any other Loan Document and (i) in the case of a default under Section 5.01 (other than as referred to in subsection (f)(i) thereof) such default shall have continued for a period of ten (10) Business Days and (ii) in the case of any other default such default shall have continued for a period of 30 days after notice from the Administrative Agent to the Borrower.
(f) The Borrower or any Subsidiary of the Borrower shall (i)
fail to make any payment (x) on account of any Indebtedness under the
NPC Credit Agreement or the SPPC Credit Agreement, (y) on account of
any Indebtedness aggregating $10,000,000 or more in principal amount or
(z) aggregating $10,000,000 or more on any Indebtedness, or any
interest or premium thereon, in each case, when due (whether by
scheduled maturity, required prepayment, acceleration, demand or
otherwise), and, in each case, such failure shall have continued beyond
any applicable grace period specified in any agreement or instrument
relating to such Indebtedness, or (ii) fail to perform or observe any
other term, covenant or condition on its part to be performed or
observed under any agreement or instrument relating to any Indebtedness
when required to be performed or observed, and such failure shall have
continued beyond any applicable grace period specified in any agreement
or instrument relating to such Indebtedness, if the effect of such
failure to perform or observe is to accelerate, or to permit the
acceleration of, the maturity of such Indebtedness, the unpaid
principal amount of which then aggregates $10,000,000 or more.
(g) One or more final judgments or orders for the payment of money shall have been entered against the Borrower or any Subsidiary of the Borrower, which judgments or orders exceed $10,000,000 in the aggregate, and such judgments or orders shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(h) One or more writs or warrants of attachment, garnishment, execution, distraint or similar process exceeding in value the aggregate amount of $10,000,000 shall have been issued against the Borrower or any Subsidiary of the Borrower or any of their
respective properties and shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(i) Any Governmental Action now or hereafter made by or with any Governmental Authority in connection with any Loan Document is not obtained or shall have ceased to be in full force and effect or shall have been modified or amended or shall have been held to be illegal or invalid, and the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that the consequence of any of the foregoing events would reasonably be expected to have, individually or in the aggregate, a Material Adverse Effect.
(j) Any Loan Document or any material term or provision thereof shall have ceased to be in full force and effect, or the Borrower or any Governmental Authority with jurisdiction over the Borrower shall, or shall purport to, terminate, repudiate, declare voidable or void or otherwise contest, any Loan Document or any material term or provision thereof or any obligation or liability of the Borrower thereunder.
(k) An event or condition specified in Section 5.01(h) hereof shall occur or exist with respect to any Plan or Multiemployer Plan or any Lien arises pursuant to ERISA and, as a result of such event or condition or Lien, together with all other such events or conditions or Liens, the Borrower or any ERISA Affiliate shall incur or shall be reasonably likely to incur a liability to a Plan, a Multiemployer Plan or the PBGC or suffer an encumbrance to exist in favor of any thereof (or any combination of the foregoing) which would constitute a Material Adverse Effect.
(l) The Borrower or any Subsidiary of the Borrower shall have violated any Environmental Law or become subject to any Environmental Claim and, in either case, the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that such event would reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
(m) A proceeding shall have been instituted in respect of the Borrower or any Subsidiary of the Borrower:
(i) seeking to have an order for relief entered in respect of such Person, or seeking a declaration or entailing a finding that such Person is insolvent or a similar declaration or finding, or seeking dissolution, winding-up, charter revocation or forfeiture, liquidation, reorganization, arrangement, adjustment, composition or other similar relief with respect to such Person, its assets or its debts under any Law relating to bankruptcy, insolvency, relief of debtors or protection of creditors, termination of legal entities or any other similar Law now or hereafter in effect, or
(ii) seeking appointment of a receiver, trustee, liquidator, assignee, sequestrator or other custodian for such Person or for all or any substantial part of its Property,
and such proceeding shall result in the entry, making or grant of any such order for relief, declaration, finding, relief or appointment, or such proceeding shall remain undismissed and unstayed for a period of thirty (30) consecutive days.
(n) The Borrower or any Subsidiary of the Borrower shall become insolvent; shall fail to pay, become unable to pay, or state that it is or will be unable to pay, its debts as they become due; shall voluntarily suspend transaction of its business; shall make a general assignment for the benefit of creditors; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(i), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such order for relief, declaration, finding or relief described therein; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(ii), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such appointment or to the taking of possession by any such custodian of all or any substantial part of its Property; shall dissolve, wind-up, revoke or forfeit its charter (or other constituent documents) or liquidate itself or any substantial part of its Property; or shall take any action in furtherance of any of the foregoing.
(o) A Change in Control shall occur.
(p) The Borrower shall fail to maintain ongoing utility segment-identifiable assets (exclusive of cash and marketable securities) and operating income relating to the generation or transmission and/or distribution of electricity or gas in a proportion equal to at least 80% of total assets (exclusive of cash and marketable securities) and operating income.
(a) If an Event of Default specified in Section 7.01 (other than subsections (m) and (n) thereof) shall occur and be continuing or shall exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder or under any other Loan Document, at law, in equity or otherwise, the Lenders shall be under no further obligation to make Loans hereunder, and the Administrative Agent may, and, upon the written request of the Required Lenders shall, by notice to the Borrower, from time to time do any or all of the following:
(i) Declare the Commitments terminated, whereupon the Commitments will terminate and any fees hereunder shall be immediately due and payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(ii) Declare the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations to be immediately due and payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(b) If an Event of Default specified in subsection (m) or (n) of Section 7.01 shall occur or exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder or under any other Loan Document, at law, in equity or otherwise, the Commitments shall automatically terminate and the Lenders shall be under no further obligation to make Loans, and the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations shall become immediately due and payable without
presentment, demand, protest or notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
ARTICLE VIII
THE AGENTS
Each Lender hereby irrevocably appoints Union Bank of California, N.A. to act as Administrative Agent for such Lender under this Agreement and the other Loan Documents. Each Lender hereby irrevocably authorizes the Administrative Agent to take such action on behalf of such Lender under the provisions of this Agreement and the other Loan Documents, and to exercise such powers and to perform such duties, as are expressly delegated to or required of the Administrative Agent by the terms hereof or thereof, together with such powers as are reasonably incidental thereto. Union Bank of California, N.A. hereby agrees to act as Administrative Agent on behalf of the Lenders on the terms and conditions set forth in this Agreement and the other Loan Documents, subject to its right to resign as provided in Section 8.10. Each Lender hereby irrevocably authorizes the Administrative Agent to execute and deliver each of the Loan Documents executed after the date hereof and to accept delivery of such of the other Loan Documents delivered after the date hereof as may not require execution by the Administrative Agent (with such consents of the Lenders as required pursuant to Section 9.01). Each Lender agrees that the rights and remedies granted to the Administrative Agent under the Loan Documents shall be exercised exclusively by the Administrative Agent, and that no Lender shall have any right individually to exercise any such right or remedy, except to the extent expressly provided herein or therein.
Notwithstanding anything to the contrary elsewhere in this Agreement or in any other Loan Document:
(a) The Administrative Agent shall have no duties or responsibilities except those expressly set forth in this Agreement and the other Loan Documents, and no implied duties or responsibilities on the part of the Administrative Agent shall be read into this Agreement or any other Loan Document or shall otherwise exist.
(b) The duties and responsibilities of the Administrative Agent under this Agreement and the other Loan Documents shall be mechanical and administrative in nature, and the Administrative Agent shall not have a fiduciary relationship in respect of any Lender.
(c) The Administrative Agent is and shall be solely the agent of the Lenders. The Administrative Agent does not assume, and shall not at any time be deemed to have, any relationship of agency or trust with or for, or any other duty or responsibility to, the Borrower or any other Person (except only for its relationship as agent for, and its express duties and responsibilities to, the Lenders as provided in this Agreement and the other Loan Documents).
(d) The Administrative Agent shall be under no obligation to take any action hereunder or under any other Loan Document if the Administrative Agent believes in
good faith that taking such action may conflict with any Law or any provision of this Agreement or any other Loan Document, or may require the Administrative Agent to qualify to do business in any jurisdiction where it is not then so qualified.
The Administrative Agent shall take any action of the type
specified in this Agreement or any other Loan Document as being within the
Administrative Agent's rights, powers or discretion in accordance with
directions from the Required Lenders (or, to the extent this Agreement or such
other Loan Document expressly requires the direction or consent of some other
Person or set of Persons, then instead in accordance with the directions of such
other Person or set of Persons). In the absence of such directions, the
Administrative Agent shall have the authority (but under no circumstances shall
be obligated), in its sole discretion, to take any such action, except to the
extent that this Agreement or such other Loan Document expressly requires the
direction or consent of the Required Lenders (or some other Person or set of
Persons), in which case the Administrative Agent shall not take such action
absent such direction or consent. Any action or inaction pursuant to such
direction, discretion or consent shall be binding on all the Lenders. The
Administrative Agent shall not have any liability to any Person as a result of
(a) the Administrative Agent acting or refraining from acting in accordance with
the directions of the Required Lenders (or other applicable Person or set of
Persons), (b) the Administrative Agent refraining from acting in the absence of
instructions to act from the Required Lenders (or other applicable Person or set
of Persons), whether or not the Administrative Agent has discretionary power to
take such action, or (c) the Administrative Agent taking discretionary action it
is authorized to take under this Section (subject, in the case of clauses (b)
and (c), to the provisions of Section 8.04(a)).
Notwithstanding anything to the contrary elsewhere in this Agreement or any other Loan Document:
(a) The Administrative Agent shall not be liable for any action taken or omitted to be taken by it under or in connection with this Agreement or any other Loan Document, unless caused by its own gross negligence or willful misconduct.
(b) The Administrative Agent shall not be responsible for (i) the execution, delivery, effectiveness, enforceability, genuineness, validity or adequacy of this Agreement or any other Loan Document, (ii) any recital, representation, warranty, document, certificate, report or statement in, provided for in, or received under or in connection with, this Agreement or any other Loan Document, (iii) any failure of the Borrower or any Lender to perform any of their respective obligations under this Agreement or any other Loan Document, or (iv) the existence, validity, enforceability, perfection, recordation, priority, adequacy or value, now or hereafter, of any Lien or other direct or indirect security afforded or purported to be afforded by any of the Loan Documents or otherwise from time to time.
(c) The Administrative Agent shall not be under any
obligation to ascertain, inquire or give any notice relating to (i)
the performance or observance of any of the terms or conditions of
this Agreement or any other Loan Document on the part of the Borrower,
(ii) the business, operations, condition (financial or otherwise) or
prospects of
the Borrower or any other Person, or (iii) except to the extent set forth in Section 8.05(f), the existence of any Default or Event of Default.
(d) The Administrative Agent shall not be under any obligation, either initially or on a continuing basis, to provide any Lender with any notices, reports or information of any nature, whether in its possession presently or hereafter, except for such notices, reports and other information expressly required by this Agreement or any other Loan Document to be furnished by the Administrative Agent to such Lender.
(a) The Administrative Agent may rely upon any notice or other communication of any nature (written or oral, including but not limited to telephone conversations, whether or not such notice or other communication is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the proper party or parties, and the Administrative Agent shall not have any duty to verify the identity or authority of any Person giving such notice or other communication.
(b) The Administrative Agent may consult with legal counsel (including, without limitation, in-house counsel for the Administrative Agent or in-house or other counsel for the Borrower), independent public accountants and any other experts selected by it from time to time, and the Administrative Agent shall not be liable for any action taken or omitted to be taken in good faith by it in accordance with the advice of such counsel, accountants or experts.
(c) The Administrative Agent may conclusively rely upon the truth of the statements and the correctness of the opinions expressed in any certificates or opinions furnished to the Administrative Agent in accordance with the requirements of this Agreement or any other Loan Document. Whenever the Administrative Agent shall deem it necessary or desirable that a matter be proved or established with respect to the Borrower or any Lender, such matter may be established by a certificate of the Borrower or such Lender, as the case may be, and the Administrative Agent may conclusively rely upon such certificate (unless other evidence with respect to such matter is specifically prescribed in this Agreement or another Loan Document).
(d) The Administrative Agent may fail or refuse to take any action unless it shall be indemnified to its satisfaction from time to time against any and all amounts, liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs, expenses or disbursements of any kind or nature which may be imposed on, incurred by or asserted against the Administrative Agent by reason of taking or continuing to take any such action.
(e) The Administrative Agent may perform any of its duties under this Agreement or any other Loan Document by or through agents or attorneys-in-fact. The Administrative Agent shall not be responsible for the negligence or misconduct of any agents or attorneys-in-fact selected by it with reasonable care.
(f) The Administrative Agent shall not be deemed to have any knowledge or notice of the occurrence of any Default or Event of Default unless the Administrative Agent has received notice from a Lender or the Borrower referring to this Agreement, describing such Default or Event of Default, and stating that such notice is a "notice of default". If the Administrative Agent receives such a notice, the Administrative Agent shall give prompt notice thereof to each Lender.
Each Lender acknowledges as follows:
(a) Neither the Administrative Agent nor any other Lender has made any representations or warranties to it, and no act taken hereafter by the Administrative Agent or any other Lender shall be deemed to constitute any representation or warranty by the Administrative Agent or such other Lender to it.
(b) It has, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it has deemed appropriate, made its own credit and legal analysis and decision to enter into this Agreement and the other Loan Documents.
(c) It will, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it shall deem appropriate at the time, make its own decisions to take or not take action under or in connection with this Agreement and the other Loan Documents.
With respect to its Commitment and the Obligations owing to it, the Administrative Agent shall have the same rights and powers under this Agreement and each other Loan Document as any other Lender and may exercise the same as though it were not the Administrative Agent, and the terms "Lenders," "holders of Notes" and like terms shall include
the Administrative Agent in its individual capacity as such. The Administrative Agent and its affiliates may, without liability to account, make loans to, accept deposits from, acquire debt or equity interests in, act as trustee under indentures of, and engage in any other business with, the Borrower and any stockholder, subsidiary or affiliate of the Borrower, as though the Administrative Agent were not the Administrative Agent hereunder.
The Administrative Agent may deem and treat the Lender which is payee of a Note as the owner and holder of such Note for all purposes hereof unless and until an Assignment and Acceptance with respect to the assignment or transfer thereof shall have been filed with the Administrative Agent in accordance with Section 9.12. Any authority, direction or consent of any Person who at the time of giving such authority, direction or consent is shown in the Register as being a Lender shall be conclusive and binding on each present and subsequent holder, transferee or assignee of any Note or Notes payable to such Lender or of any Note or Notes issued in exchange therefor.
The Administrative Agent shall not be liable for any calculation, apportionment or distribution of payments made by it in good faith, in the absence of its own gross negligence or willful misconduct. If such calculation, apportionment or distribution is subsequently determined to have been made in error, the sole recourse of any Lender to whom payment was due but not made (except as provided in the preceding sentence) shall be to recover from the other Lenders any payment in excess of the amount to which they are determined to be entitled or, if the amount due was not paid by the Borrower, to recover such amount from the Borrower.
As Syndication Agent, Wells Fargo Bank, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Wells Fargo Bank, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Wells Fargo Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Sole Bookrunner, Union Bank of California, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Union Bank of California, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Union Bank of California, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Co-Documentation Agents, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Bank One, NA, BNP Paribas or Mellon Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
ARTICLE IX
MISCELLANEOUS
(a) Increase the Commitment of any Lender over the amount thereof then in effect, without the written consent of each Lender affected thereby;
(b) Extend the Revolving Termination Date, without the written consent of all the Lenders;
(c) Reduce the principal amount of or extend the time for any payment of principal of any Loan, or reduce the rate of interest or extend the time for payment of any interest borne by any Loan, or extend the time for payment of or reduce the amount of any fees, or reduce the amount of or postpone the date for payment of any other obligation, without the written consent of each Lender affected thereby;
(d) Change the definition of "Required Lenders" or amend this
Section 9.01 or Section 9.12(a) or any other provision of this
Agreement that requires the consent of all of the Lenders to the taking
or failure to take action hereunder, without the written consent of all
the Lenders; or
(e) Amend or waive any of the provisions of Article VIII, or impose additional duties upon the Administrative Agent or otherwise adversely affect the rights, interests or obligations of the Administrative Agent, without the written consent of the Administrative Agent;
No course of dealing and no delay or failure of the Administrative Agent or any Lender in exercising any right, power or privilege under this Agreement or any other Loan Document shall affect any other or future exercise thereof or the exercise of any other right, power or privilege; nor shall any single or partial exercise of any such right, power or privilege or any abandonment or discontinuance of steps to enforce such a right, power or privilege preclude any further exercise thereof or of any other right, power or privilege. The rights and remedies of the Administrative Agent and the Lenders under this Agreement and any other Loan Document are cumulative and not exclusive of any rights or remedies which the Administrative Agent or any Lender would otherwise have hereunder or thereunder, at law, in equity or otherwise.
(b) Any Lender giving any notice to the Borrower or any other party to a Loan Document shall simultaneously send a copy thereof to the Administrative Agent, and the Administrative Agent shall promptly notify the other Lenders of the receipt by it of any such notice.
(c) The Administrative Agent and each Lender may rely on any notice (whether or not such notice is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the Borrower, and neither the Administrative Agent nor any Lender shall have any duty to verify the identity or authority of any Person giving such notice.
(a) The Borrower agrees to pay or cause to be paid and to save the Administrative Agent and each of the Lenders harmless against liability for the payment of all reasonable out-of-pocket costs and expenses (including but not limited to reasonable fees and expenses of counsel) incurred by the Administrative Agent or any Lender from time to time arising from or relating to (i) in the case of the Administrative Agent, the negotiation, syndication, preparation, execution, delivery, administration and performance of this Agreement and the other Loan Documents, (ii) in the case of the Syndication Agent, the syndication of this Agreement and the other Loan Documents, (iii) in the case of the Administrative Agent, any amendments, modifications, supplements, waivers or consents to this Agreement or any other Loan Document (whether or not ultimately entered into or granted), and (iv) in the case of the Administrative Agent or any Lender, the enforcement or preservation of rights under this Agreement or any other Loan Document (including but not limited to any such costs or expenses arising from or relating to (A) collection or enforcement of an outstanding Loan or any other amount owing hereunder or thereunder by the Administrative Agent or such Lender, and (B) any litigation, proceeding, dispute, work-out, restructuring or rescheduling related in any way to this Agreement or the Loan Documents).
(b) The Borrower hereby agrees to pay all stamp, document, transfer, recording, filing, registration, search, sales and excise fees and taxes and all similar impositions now or hereafter determined by the Administrative Agent or any Lender to be payable in connection with this Agreement or any other Loan Documents or any other documents, instruments or transactions pursuant to or in connection herewith or therewith (which determination shall be conclusive provided it is reached in good faith), and the Borrower agrees to save the Administrative Agent and each Lender harmless from and against any and all present or future claims, liabilities or losses with respect to or resulting from any omission to pay or delay in paying any such fees, taxes or impositions.
(c) The Borrower hereby agrees to reimburse and indemnify each of the Indemnified Parties from and against any and all losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements of any kind or nature whatsoever (including, without limitation, the reasonable fees and disbursements of counsel for such Indemnified Party in connection with any investigative, administrative or judicial proceeding commenced or threatened, whether or not such Indemnified Party shall be designated a party thereto) that may at any time be imposed on, asserted against or incurred by such Indemnified Party as a result of, or arising out of, or in any way related to or by reason of, this Agreement or any other Loan Document, any transaction from time to time contemplated hereby or thereby, or any transaction financed in whole or in part or directly or indirectly with the proceeds of any Loan (and without in any way limiting the generality of the foregoing, including any violation or breach of any Environmental Law or any other Law by the Borrower or any Subsidiary of the Borrower; any Environmental Claim arising out of the management, use, control, ownership or operation of Property by any of such Persons, including all onsite and off-site activities involving Hazardous Materials; or any exercise by the Administrative Agent or any Lender of any of its rights or remedies under this Agreement or any other Loan Document); but excluding any such losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements resulting solely from the gross negligence or willful misconduct of such Indemnified Party, as finally determined by a court of competent jurisdiction. If and to the extent that the foregoing obligations of the Borrower under this
subsection (c), or any other indemnification obligation of the Borrower hereunder or under any other Loan Document, are unenforceable for any reason, the Borrower hereby agrees to make the maximum contribution to the payment and satisfaction of such obligations which is permissible under applicable Law.
The provisions of this Agreement are intended to be severable. If any provision of this Agreement shall be held invalid or unenforceable in whole or in part in any jurisdiction such provision shall, as to such jurisdiction, be ineffective to the extent of such invalidity or unenforceability without in any manner affecting the validity or enforceability thereof in any other jurisdiction or the remaining provisions hereof in any jurisdiction.
This Agreement and the other Loan Documents, as such agreements shall be amended from time to time, supersede all prior and contemporaneous understandings and agreements, whether written or oral, among the parties hereto relating to the transactions provided for herein and therein.
All representations and warranties of the Borrower contained herein or in any other Loan Document or made in connection herewith or therewith shall survive the making, and shall not be waived by the execution and delivery, of this Agreement or any other Loan Document, any investigation by or knowledge of the Administrative Agent or any Lender, the making of any Loan, or any other event or condition whatever. All covenants and agreements of the Borrower contained herein or in any other Loan Document shall continue in full force and effect from and after the date hereof so long as the Borrower may borrow hereunder and until payment in full of all Obligations. Without limitation, all obligations of the Borrower hereunder or under any other Loan Document to make payments to or indemnify the Administrative Agent or any Lender shall survive the payment in full of all other Obligations, termination of the Borrower's right to borrow hereunder, and all other events and conditions whatever. In addition, all obligations of each Lender to make payments to or indemnify the Administrative Agent shall survive the payment in full by the Borrower of all Obligations, termination of the Borrower's right to borrow hereunder, and all other events or conditions whatever.
This Agreement may be executed in any number of counterparts and by the different parties hereto on separate counterparts each of which, when so executed, shall be deemed an original, but all such counterparts shall constitute but one and the same instrument.
The parties hereto intend to conform to all applicable Laws in effect from time to time limiting the maximum rate of interest that may be charged or collected. Accordingly, notwithstanding any other provision hereof or of any other Loan Document, the Borrower shall not be required to make any payment to or for the account of any Lender, and each Lender shall refund any payment made by the Borrower, to the extent that such requirement or such failure to
refund would violate or conflict with nonwaivable provisions of applicable Laws limiting the maximum amount of interest which may be charged or collected by such Lender.
The Borrower hereby agrees that, to the fullest extent
permitted by Law, if any Obligation of the Borrower shall be due and payable (by
acceleration or otherwise), each Lender shall have the right, without notice to
the Borrower, to set-off against and to appropriate and apply to such Obligation
any indebtedness, liability or obligation of any nature owing to the Borrower by
such Lender, including but not limited to all deposits (whether time or demand,
general or special, provisionally credited or finally credited, whether or not
evidenced by a certificate of deposit) now or hereafter maintained by the
Borrower with such Lender. Such right shall be absolute and unconditional in all
circumstances and, without limitation shall exist whether or not such Lender or
any other Person shall have given notice or made a demand to the Borrower or any
other Person, whether such indebtedness, obligation or liability owed to the
Borrower is contingent, absolute, matured or unmatured (it being agreed that
such Lender may deem such indebtedness, obligation or liability to be then due
and payable at the time of such setoff), and regardless of the existence or
adequacy of any collateral, guaranty or any other security, right or remedy
available to any Lender or any other Person. The Borrower hereby agrees that, to
the fullest extent permitted by Law, any Participant and any branch, subsidiary
or affiliate of any Lender or any Participant shall have the same rights of
set-off as a Lender as provided in this Section (regardless of whether such
Participant, branch, subsidiary or affiliate would otherwise be deemed in
privity with or a direct creditor of the Borrower). The rights provided by this
Section are in addition to all other rights of set-off and banker's lien and all
other rights and remedies which any Lender (or any such Participant, branch,
subsidiary or affiliate) may otherwise have under this Agreement, any other Loan
Document, at law or in equity, or otherwise, and nothing in this Agreement or
any other Loan Document shall be deemed a waiver or prohibition of or
restriction on the rights of set-off or bankers' lien of any such Person.
The Lenders hereby agree among themselves that if any Lender
shall receive (by voluntary payment, realization upon security, set-off or from
any other source) any amount on account of the Loans, interest thereon, or any
other Obligation contemplated by this Agreement or the other Loan Documents to
be made by the Borrower pro rata to all Lenders (or pro rata to holders of
Notes) in greater proportion than any such amount received by any other
applicable Lender, then the Lender receiving such proportionately greater
payment shall notify each other Lender and the Administrative Agent of such
receipt, and equitable adjustment will be made in the manner stated in this
Section 9.11 so that, in effect, all such excess amounts will be shared ratably
among all of the applicable Lenders. The Lender receiving such excess amount
shall purchase (which it shall be deemed to have done simultaneously upon the
receipt of such excess amount) for cash from the other applicable Lenders a
participation in the applicable Obligations owed to such other Lenders in such
amount as shall result in a ratable sharing by all applicable Lenders of such
excess amount (and to such extent the receiving Lender shall be a Participant).
If all or any portion of such excess amount is thereafter recovered from the
Lender making such purchase, such purchase shall be rescinded and the purchase
price restored to the extent of such recovery, together with interest or other
amounts, if any, required by Law to be paid by the Lender making such purchase.
The Borrower hereby consents to and confirms the foregoing
arrangements. Each Participant shall be bound by this Section as fully as if it were a Lender hereunder.
(i) any such Lender's obligations under this Agreement and the other Loan Documents shall remain unchanged,
(ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations,
(iii) the parties hereto shall continue to deal solely and directly with such Lender in connection with such Lender's rights and obligations under this Agreement and each of the other Loan Documents,
(iv) such Participant shall be bound by the provisions of
Section 9.11, and
(v) no Participant (unless such Participant is an Affiliate of such Lender, or is itself a Lender) shall be entitled to require such Lender to take or refrain from taking action under this Agreement or under any other Loan Document, except that such Lender may agree with such Participant that such Lender will not, without such Participant's consent, take any action, or consent to the taking of any action, of the type described in Section 9.01(a), (b) or (c).
(i) any such assignment to a Purchasing Lender which is not a Lender or an affiliate of a Lender shall be made only with the consent (which in each case shall not be unreasonably withheld) of the Borrower (so long as no Default or Event of Default shall have occurred and be continuing) and the Administrative Agent;
(ii) if a Lender makes such an assignment of less than all of its then remaining rights and obligations under this Agreement and the other Loan Documents, such transferor Lender shall retain, after such assignment, a minimum principal amount of $5,000,000 of the Commitments and Loans then outstanding, and such assignment, unless made to an assignee who is a Lender hereunder prior to such assignment, shall be in a minimum principal amount of $5,000,000 of the Commitments and Loans then outstanding;
(iii) each such assignment shall be of a constant, and not a varying, percentage of the Commitment of the transferor Lender and of all of the transferor Lender's rights and obligations under this Agreement and the other Loan Documents; and
(iv) each such assignment shall be made pursuant to an Assignment and Acceptance.
In order to effect any such assignment, the transferor Lender and the Purchasing Lender shall execute and deliver to the Administrative Agent a duly completed Assignment and Acceptance (including the consents required by clause (i) of the preceding sentence) with respect to such assignment, together with any Note or Notes subject to such assignment and a processing and recording fee of $3,500; and, upon receipt thereof, the Administrative Agent shall accept such Assignment and Acceptance. Upon receipt of notice from the transferor Lender that it has received the consideration described in the Assignment and Acceptance, the Administrative Agent shall record such acceptance in the Register. Upon such execution, delivery, acceptance and recording, from and after the close of business at the Administrative Agent's Principal Office on the settlement date specified in such Assignment and Acceptance:
(x) the Purchasing Lender shall be a party hereto and, to the extent provided in such Assignment and Acceptance, shall have the rights and obligations of a Lender hereunder, and
(y) the transferor Lender thereunder shall be released from its obligations under this Agreement to the extent so transferred (and, in the case of an Assignment and Acceptance covering all or the remaining portion of a transferor Lender's rights and obligations under this Agreement, such transferor Lender shall cease to be a party to this Agreement) from and after the settlement date.
On or prior to the settlement date specified in an Assignment and Acceptance, the Borrower, at its expense, shall execute and deliver to the Administrative Agent (for delivery to the Purchasing Lender) new Notes evidencing such Purchasing Lender's assigned Commitment or Loans and (for delivery to the transferor Lender) replacement Notes in the principal amount of the Loans or Commitment retained by the transferor Lender (such Notes to be in exchange for, but not in payment of, those Notes then held by such transferor Lender). Each such Note shall be dated the date and be substantially in the form of the predecessor Note. The Administrative Agent shall mark the predecessor Notes "exchanged" and deliver them to the Borrower. Accrued interest
and accrued fees shall be paid to the Purchasing Lender at the same time or times provided in the predecessor Notes and this Agreement.
(ii) WAIVES ANY OBJECTION WHICH IT MAY HAVE AT ANY TIME TO THE LAYING OF VENUE OF ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, WAIVES ANY CLAIM THAT ANY SUCH RELATED LITIGATION HAS BEEN BROUGHT IN AN INCONVENIENT FORUM, AND WAIVES ANY RIGHT TO OBJECT, WITH RESPECT TO ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, THAT SUCH COURT DOES NOT HAVE JURISDICTION OVER IT;
(iii) CONSENTS AND AGREES TO SERVICE OF ANY SUMMONS, COMPLAINT OR OTHER LEGAL PROCESS IN ANY RELATED LITIGATION BY REGISTERED OR CERTIFIED U.S. MAIL, POSTAGE PREPAID, TO IT AT THE ADDRESS FOR NOTICES DESCRIBED IN SECTION 9.03, AND CONSENTS AND AGREES THAT SUCH SERVICE SHALL CONSTITUTE IN EVERY RESPECT VALID AND EFFECTIVE SERVICE (BUT NOTHING HEREIN SHALL AFFECT THE VALIDITY OR EFFECTIVENESS OF PROCESS SERVED IN ANY OTHER MANNER PERMITTED BY LAW); AND
(iv) WAIVES THE RIGHT TO TRIAL BY JURY IN ANY RELATED LITIGATION.
LIABILITY). EACH PARTY TO THIS AGREEMENT HEREBY WAIVES, RELEASES AND AGREES NOT TO SUE UPON ANY CLAIM FOR ANY SUCH DAMAGES, WHETHER SUCH CLAIM PRESENTLY EXISTS OR ARISES HEREAFTER AND WHETHER OR NOT SUCH CLAIM IS KNOWN OR SUSPECTED TO EXIST IN ITS FAVOR.
* * *
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed and delivered as of the day and year first above written.
Address SIERRA PACIFIC RESOURCES ------- Sierra Pacific Resources 6100 Neil Road P.O. Box 30150 By_______________________ Reno, Nevada 89520 Name: |
Attn: Richard K. Atkinson Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address UNION BANK OF CALIFORNIA, ------- N.A., as Administrative Agent, as Co-Lead Arranger, Union Bank of California, N.A. as Sole Bookrunner and as a 445 South Figueroa Street, 15/th/ Floor Lender Los Angeles, CA 90071 Attn: Robert Olson By__________________________ Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address WELLS FARGO BANK, N.A., as ------- Syndication Agent, as Co-Lead Arranger and as a Wells Fargo Bank, N.A. Lender 555 Montgomery Street, 17/th/ Floor San Francisco, CA 94111 Attn: Dennis Bloch By__________________________ Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address BANK ONE, NA, as ------- Co-Documentation Agent and as a Lender Bank One, NA 1 Bank One Plaza, Suite IL1-0363 Chicago, IL 60670 Attn: Dawn M. Lawler By__________________________ Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address BNP PARIBAS, as ------- Co-Documentation Agent and as a Lender BNP Paribas 787 Seventh Avenue New York, NY 10019 Attn: Sean Finnegan By__________________________ Name: Title: By__________________________ Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address MELLON BANK, N.A., as ------- Co-Documentation Agent and as a Lender Mellon Bank, N.A. One Mellon Center 500 Grant Street, Room 4530 Pittsburgh, PA 15258-0001 By__________________________ Attn: Mark W. Rogers Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address BAYERISCHE LANDESBANK ------- GIROZENTRALE Bayerische Landesbank Girozentrale 560 Lexington Avenue New York, NY 10022 By__________________________ Attn: Jim Monaghan Name: Title: By__________________________ Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address LEHMAN COMMERCIAL PAPER INC. ------- Lehman Commercial Paper Inc. 101 Hudson Street Jersey City, NJ 07302 By__________________________ Attn: Michele Swanson Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address FIRST UNION NATIONAL BANK ------- First Union National Bank 301 South College Street Charlotte, NC 38388-0251 By__________________________ Attn: Joe Dancy Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
Address MERRILL LYNCH BANK USA ------- Merrill Lynch Bank USA 15 W. South Temple, Suite 300 Salt Lake City, UT 84101 By__________________________ Attn: Butch Alder Name: |
Title:
Signature Page to Sierra Pacific Resources Credit Agreement
[See definitions of "Commitment" in Section 1.01]
LENDER COMMITMENT AMOUNT ------ ----------------- Union Bank of California, N.A. $15,000,000.00 Wells Fargo Bank, N.A. $15,000,000.00 Bank One, N.A. $10,588,235.29 BNP Paribas $10,588,235.29 Bayerische Landesbank Girozentrale $ 7,941,176.47 Mellon Bank, N.A. $ 7,058,823.53 Lehman Commercial Paper Inc. $ 3,529,411.78 First Union National Bank $ 2,647,058.82 Merrill Lynch Bank USA $ 2,647,058.82 Total: $75,000,000.00 |
EXHIBIT 10(B)
THIS AGREEMENT, dated May 21, 2001, is made by and between Sierra Pacific Resources, a Nevada corporation (the "Company"), and Walter M. Higgins (the "Executive").
WHEREAS, the Company considers it essential to the best interests of its stockholders to foster the continued employment of key management personnel; and
WHEREAS, the Board recognizes that, as is the case with many publicly held corporations, the possibility of a Change in Control exists and that such possibility, and the uncertainty and questions which it may raise among management, may result in the departure or distraction of management personnel to the detriment of the Company and its stockholders; and
WHEREAS, the Board has determined that appropriate steps should be taken to reinforce and encourage the continued attention and dedication of members of the management of the Company and its subsidiaries (collectively, "Sierra"), including the Executive, to their assigned duties without distraction in the face of potentially disturbing circumstances arising from the possibility of a Change in Control;
NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, the Company and the Executive hereby agree as follows:
5.1 Following a Change in Control or potential Change in Control and during the Term, during any period that the Executive fails to perform the Executive's full-time duties with Sierra as a result of incapacity due to physical or mental illness, the Company shall pay the Executive's full salary to the Executive at the rate in effect at the commencement of any such period, together with all compensation and benefits payable to the Executive under the terms of any compensation or benefit plan, program or arrangement maintained by Sierra during such period, until the Executive's employment is terminated by Sierra for Disability.
5.2 If the Executive's employment shall be terminated for any reason following a Change in Control or potential Change in Control and during the Term, the Company shall pay the Executive's full salary to the Executive through the Date of Termination at the rate in effect immediately prior to the Date of Termination or, if higher, the rate in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, together with all compensation and benefits payable to the Executive through the Date of Termination under the terms of Sierra compensation and benefit plans, programs or arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive,
as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason.
5.3 If the Executive's employment shall be terminated for any reason following a Change in Control or potential Change in Control and during the Term, the Company shall pay to the Executive the Executive's normal post-termination compensation and benefits as such payments become due. Such post-termination compensation and benefits shall be determined under, and paid in accordance with, Sierra's retirement, insurance and other compensation or benefit plans, programs and arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the occurrence of the first event or circumstance constituting Good Reason.
6.1 Subject to Section 6.2 hereof, if the Executive's employment is terminated following a Change in Control and during the Term, other than (A) by Sierra for Cause, (B) by reason of death or Disability, or (C) by the Executive without Good Reason, then Sierra shall pay the Executive the amounts, and provide the Executive the benefits, described in this Section 6.1 ("Severance Payments"), in addition to any payments and benefits to which the Executive is entitled under Section 5 hereof. For purposes of this Agreement, the Executive's employment shall be deemed to have been terminated following a Change in Control by Sierra without Cause or by the Executive with Good Reason, if (i) the Executive's employment is terminated by Sierra without Cause prior to a Change in Control (whether or not a Change in Control ever occurs) and such termination was at the request or direction of a Person who has entered into an agreement with the Company the consummation of which would constitute a Change in Control, (ii) the Executive terminates his employment for Good Reason prior to a Change in Control (whether or not a Change in Control ever occurs) and the circumstance or event which constitutes Good Reason occurs at the request or direction of such Person, or (iii) the Executive's employment is terminated by Sierra without Cause or by the Executive for Good Reason and such termination or the circumstance or event which constitutes Good Reason is otherwise in connection with or in anticipation of a Change in Control (whether or not a Change in Control ever occurs). For purposes of any determination regarding the applicability of the immediately preceding sentence, any position taken by the Executive shall be presumed to be correct unless the Company establishes to the Board by clear and convincing evidence that such position is not correct.
(A) In lieu of any further salary payments to the Executive for periods subsequent to the Date of Termination and in lieu of any severance benefit otherwise payable to the Executive under or pursuant to any contract or plan, except for any severance benefits relating to or resulting from the Supplemental Executive Retirement Plan, whether as a consequence of a Change in Control or otherwise, the Company shall pay to the Executive a
lump sum severance payment, in cash, equal to three times the sum of
(i) the Executive's base salary as in effect immediately prior to the
Date of Termination or, if higher, in effect immediately prior to the
first occurrence of an event or circumstance constituting Good Reason,
and (ii) the target annual incentive award applicable to the Executive
pursuant to any annual bonus or incentive plan maintained by Sierra in
respect of the fiscal year ending immediately prior to the fiscal year
in which occurs the Date of Termination or, if higher, immediately
prior to the fiscal year in which occurs the first event or
circumstance constituting Good Reason.
(C) Notwithstanding any provision of any annual or long-term incentive plan to the contrary, the Company shall pay to the Executive a lump sum amount, in cash, equal to the sum of (i) any unpaid incentive
compensation which has been allocated or awarded to the Executive fora completed fiscal year or other measuring period preceding the Date of Termination under any such plan and which, as of the Date of Termination, is contingent only upon the continued employment of the Executive to a subsequent date, and (ii) a pro rata portion to the Date of Termination of the aggregate value of all contingent incentive compensation awards to the Executive for all then uncompleted periods under any such plan, calculated as to each such award by multiplying the award that the Executive would have earned on the last day of the performance award period, assuming the achievement, at the target level of the individual and corporate performance goals established with respect to such award, by the fraction obtained by dividing the number of full months and any fractional portion of a month during such performance award period through the Date of Termination by the total number of months contained in such performance award period.
(D) In addition to the retirement benefits to which
the Executive is entitled under each Pension Plan or any successor plan
thereto, the Company shall pay the Executive a lump sum amount, in
cash, equal to the excess of (i) the actuarial equivalent of the
aggregate retirement pension (taking into account any early retirement
subsidies associated therewith and determined as a straight life
annuity commencing at the date (but in no event earlier than the third
anniversary of the Date of Termination) as of which the actuarial
equivalent of such annuity is greatest) which the Executive would have
accrued under the terms of all Pension Plans (without regard to any
amendment to any Pension Plan made subsequent to a Change in Control
and on or prior to the Date of Termination, which amendment adversely
affects in any manner the computation of retirement benefits
thereunder), determined as if the Executive were fully vested
thereunder and had accumulated (after the Date of Termination)
thirty-six (36) additional months of service credit thereunder and had
been credited under each Pension Plan during such period with
compensation equal to the Executive's compensation (as defined in such
Pension Plan) during the twelve (12) months immediately preceding the
Date of Termination or, if higher, during the twelve months immediately
prior to the first occurrence of an event or circumstance constituting
Good Reason, over (ii) the actuarial equivalent of the aggregate
retirement pension (taking into account any early retirement subsidies
associated therewith and determined as a straight life annuity
commencing at the date (but in no event earlier than the Date of
Termination) as of which the actuarial equivalent of such annuity is
greatest) which the Executive had accrued pursuant to the provisions of
the Pension Plans as of the Date of Termination. For purposes of this
Section 6.1(D), "actuarial equivalent" shall be determined using the
same assumptions utilized under the Sierra Pacific Power Company
Retirement Plan immediately prior to the Date of Termination. or, if
more favorable to the Executive, immediately prior to the first
occurrence of an event or circumstance constituting Good Reason.
(E) If the Executive would have become entitled to benefits under Sierra's post-retirement health care or life insurance plans, as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, had the Executive's employment terminated at any time during the period of thirty-six (36) months after the Date of Termination, the Company shall provide such post-retirement health care or life insurance benefits to the Executive and the Executive's dependents commencing on the later of (i) the date on which such coverage would have first become available and (ii) the date on which benefits described in subsection (B) of this Section 6.1 terminate.
6.2 (A) Anything in this Agreement to the contrary notwithstanding, if it is determined (as hereafter provided) that any payment or distribution by the Company, any person whose actions result in a Change in Control or any affiliate of the Company or such person, to or for the benefit of the Executive, whether paid or payable or distributed or distributable pursuant to the terms of this Agreement or otherwise pursuant to or by reason of any other Agreement, policy, plan, program or arrangement, including without limitation, any stock option, stock appreciation right, or similar right, or the lapse or termination of any restriction on or the vesting or exercisability of any of the foregoing (a "Payment"), would be subject to the excise tax imposed by Section 4999 of the Code (or any successor provision thereto) by reason of being considered "contingent on a change in ownership or control" of the Company, within the meaning of Section 280G of the Code (or any successor provision thereto) or to any similar tax imposed by state or local law, or any interest or penalties with respect to such tax (such tax or taxes, together with any such interest and penalties, are hereafter collectively referred to as the "Excise Tax"), then the Executive will be entitled to receive an additional payment or payments (collectively, a "Gross-Up Payment") in an amount such that, after payment by the Executive of all taxes (including any interest or penalties imposed with respect to such taxes), including an Excise Tax, imposed upon the Gross-Up Payment, the Executive retains an amount of the Gross-Up Payment equal to the Excise Tax imposed upon the Payments. No Gross-Up Payment will be made with respect to the Excise Tax, if any, attributable to (a) any incentive stock option, as defined by Section 422 of the Code ("ISO") granted prior to the execution of this Agreement (unless a comparable Gross-Up Payment has theretofore been made available with respect to such option), or (b) any stock appreciation or similar right, whether or not limited, granted in tandem with any ISO described in clause (a).
(B) Subject to the provisions of this Section, all determinations required to be made under this Section, including whether an Excise Tax and whether a Gross-Up Payment is required to be paid by the Company to the Executive and the amount of such Gross-Up Payment, will be made by a nationally recognized firm of certified public accountants (the "Accounting Firm") selected by the Executive in his sole discretion. The Executive will direct the Accounting Firm to submit its determination and detailed supporting calculations to both the Company
and the Executive within 15 calendar days after the Executive's termination, if applicable, and any other such time or times as may be requested by the Company or the Executive. If the Accounting Firm determines that any Excise Tax is payable by the Executive, the Company will pay the required Gross-Up Payment to the Executive within five business days after receipt of such determination and calculations with respect to any Payment to the Executive. If the Accounting Firm determines that no Excise Tax is payable by the Executive, it will, at the same time as it makes such determination, furnish the Company and the Executive an opinion that the Executive has substantial authority not to report any Excise Tax on the Executive's federal, state, local income, or other tax return. Any determination by the Accounting Firm as to the amount of the Gross-Up Payment will be binding upon the Company and the Executive. As a result of the uncertainty in the application of Section 4999 of the Code (or any successor provision thereto) and the possibility of similar uncertainty regarding applicable state or local tax law at the time of any determination by the Accounting Firm hereunder, it is possible that Gross-Up Payments that will not have been made by the Company should have been made (an "Underpayment), consistent with the calculations required to be made hereunder. In the event that the Company exhausts or fails to pursue its remedies pursuant to this Section, and the Executive thereafter is required to make a payment of any Excise Tax, the Executive will direct the Accounting Firm to determine the amount of the Underpayment that has occurred and to submit its determination and detailed supporting calculations to both the Company and the Executive as promptly as possible. Any such Underpayment will be promptly paid by the Company to, or for the benefit of, the Executive within five business days after receipt of such determination and calculations.
(C) The Company and the Executive will each provide the Accounting Firm access to and copies of any books, records, and documents in the possession of the Company or the Executive, as the case may be, reasonably requested by the Accounting Firm, and otherwise cooperate with the Accounting Firm in connection with the preparation and issuance of the determinations and calculations contemplated by this Section.
(D) The federal, state, and local income or other tax returns filed by the Executive will be prepared and filed on a consistent basis with the determination of the Accounting Firm with respect to the Excise Tax payable by the Executive. The Executive will make proper payment of the amount of any Excise Tax, and at the request of the Company, provide to the Company true and correct copies (with any amendments) of the Executive's federal income tax return as filed with the Internal Revenue Service and corresponding state and local tax returns, if relevant, as filed with the applicable taxing authority, and such other documents reasonably requested by the Company, evidencing such payment. If prior to the filing of the Executive's federal income tax return, or corresponding state or local tax return, if relevant, the Accounting Firm determines that the amount of the Gross-Up Payment should be reduced, the Executive will, within five business days, pay to the Company the amount of such reduction.
(E) The fees and expenses of the Accounting Firm for its services in connection with the determinations and calculations contemplated by this section will be borne by the Company. If such fees and expenses are initially paid by the Executive, the Company will reimburse the Executive the full amount of such fees and expenses within five business days after receipt from the Executive of a statement therefore and reasonable evidence of his payment thereof.
(F) The Executive will notify the Company in writing of any claim by the Internal Revenue Service or other taxing authority that, if successful, would require the payment by the Company of a Gross-Up Payment. Such notification will be given as promptly as practicable but no later than 10 business days after the Executive actually receives notice of such claim and the Executive will further apprise the Company of the nature of such claim and the date on which such claim is requested to be paid (in each case, to the extent known by the Executive). The Executive will not pay such claim prior to the earlier of (a) the expiration of the 30-calendar-day period following the date on which the Executive gives such notice to the Company, and (b) the date that any payment of amount with respect to such claim is due. If the Company notifies the Executive in writing prior to the expiration of such period that it desires to contest such claim, the Executive will:
(a) provide the Company with any written records or documents in the Executive's possession relating to such claim reasonably requested by the Company;
(b) take such action in connection with contesting such claim as the Company will reasonably request in writing from time to time, including, without limitation, accepting legal representation with respect to such claim by an attorney competent with respect of the subject matter and reasonably selected by the Company;
(c) cooperate with the Company in good faith in order effectively to contest such claim; and
(d) permit the Company to participate in any proceedings relating to such claim;
provided, however, that the Company will bear and pay directly all costs and expenses (including interest and penalties) incurred in connection with such contest and will indemnify and hold harmless the Executive, on an after-tax basis, for and against any Excise Tax or income tax, including interest and penalties with respect thereto, imposed as a result of such representation and payment of costs and expenses. Without limiting the foregoing provisions of this Section, the Company will control all proceedings taken in connection with the contest of any claim contemplated by this Section and, at its sole option, may pursue or forego any and all administrative appeals, proceedings, hearings, and conferences with the taxing
authority in respect of such claim (provided, however, that the Executive may participate therein at the Executive's own cost and expense) and may, at its option, either direct the Executive to pay the tax claimed and sue for a refund or contest the claim in any permissible manner, and the Executive agrees to prosecute such contest to a determination before any administrative tribunal, in a court of initial jurisdiction, and in one or more appellate courts, as the Company will determine; provided, however, that the Company directs the Executive to pay the tax claimed and sue for a refund, the Company will advance the amount of such payment to the Executive on an interest-free basis and will indemnify and hold the Executive harmless, on an after-tax basis, from any Excise Tax or income or other tax, including interest and penalties with respect thereto, imposed with respect to such advance; and provided further, however, that any extension of the statute of limitations relating to payment of taxes for the taxable year of the Executive with respect to which the contested amount is claimed to be due is limited solely to such contested amount. Furthermore, the Company's control of any such contested claim will be limited to issues with respect to which a Gross-Up Payment would be payable hereunder and the Executive will be entitled to settle or contest, as the case may be, any other issue raised by the Internal Revenue Service or any other taxing authority.
(G) If, after the receipt by the Executive of an amount advanced by the Company pursuant to this Section, the Executive receives any refund with respect to such claim, the Executive will (subject to the Company's complying with the requirements of this Section) promptly pay to the Company the amount of such refund (together with any interest paid or credited thereon after any taxes applicable theret0). If, after the receipt by the Executive of an amount advanced by the Company pursuant to this Section, a determination is made that the Executive will not be entitled to any refund with respect to such claim and the Company does not notify the Executive in writing of its intent to contest such denial or refund prior to the expiration of 30 calendar days after such determination, then such advance will be forgiven and will not be required to be repaid and the amount of such advance will offset, to the extent thereof, the amount of the Gross-Up Payment required to be paid by the Company to the Executive pursuant to this Section.
6.3 This section intentionally left blank.
6.4 The Company also shall pay to the Executive all legal fees and expenses incurred by the Executive in disputing in good faith any issue hereunder relating to the termination of the Executive's employment, in seeking in good faith to obtain or enforce any benefit or right provided by this Agreement or in connection with any tax audit or proceeding to the extent attributable to the application of Section 4999 of the Code to any payment or benefit provided hereunder. Such payments shall be made within five (5) business days after delivery of the Executive's written requests for payment accompanied with such evidence of fees and expenses incurred as the Company reasonably may require.
6.5 Notwithstanding any other provision of this agreement, if the executive is entitled to and claims benefits under or pursuant to any other change in control agreement entered into between Company or Sierra and the executive, or any terms or conditions thereunder, the executive shall not be entitled to any of the severance benefits or any other benefits under this agreement or terms or conditions of this agreement.
9.1 In addition to any obligations imposed by law upon any successor to the Company, the Company will require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of the Company to expressly assume and agree to perform this Agreement in the same manner and to the same extent that the Company would be required to perform it if no such succession had taken place. Failure of the Company to obtain such assumption and agreement prior to the effectiveness of any such succession shall be a breach of this Agreement and shall entitle the Executive to compensation from the Company in the same amount and on the same terms as the Executive would be entitled to hereunder if the Executive were to terminate the Executive's employment for Good Reason after a Change in Control, except that, for purposes of implementing the foregoing, the date on which any such succession becomes effective shall be deemed the Date of Termination.
9.2 This Agreement shall inure to the benefit of and be enforceable by the Executive's personal or legal representatives, executors, administrators, successors, heirs, distributees, devisees and legatees. If the Executive shall die while any amount would still be payable to the Executive hereunder (other than amounts which, by their terms, terminate upon the death of the Executive) if the Executive had continued to live, all such amounts, unless otherwise provided herein, shall be paid in accordance with the terms of this Agreement to the executors, personal representatives or administrators of the Executive's estate.
To the Company:
Sierra Power Resources
6100 Neil Road
Reno, Nevada 89520-3150
Attention: General Counsel
under federal, state or local law and any additional withholding to which the Executive has agreed. The obligations of the Company and the Executive under this Agreement which by their nature may require either partial or total performance after the expiration of the Term (including, without limitation, those under Sections 6 and 7 hereof) shall survive such expiration.
12.1 The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which shall remain in full force and effect.
14.1 All claims by the Executive for benefits under this Agreement shall be directed to and determined by the Board and shall be in writing. Any denial by the Board of a claim for benefits under this Agreement shall be delivered to the Executive in writing and shall set forth the specific reasons for the denial and the specific provisions of this Agreement relied upon. The Board shall afford a reasonable opportunity to the Executive for a review of the decision denying a claim and shall further allow the Executive to appeal to the Board a decision of the Board within sixty (60) days after notification by the Board that the Executive's claim has been denied.
15. Definitions. For purposes of this Agreement, the ----------- following terms shall have the meanings inidicated below: (A) "Affiliate" shall have the meaning set forth in Rule 12b-2 |
promulgated under Section 12 of the Exchange Act.
(B) "Auditor" shall have the meaning set forth in Section 6.2 hereof.
(C) "Base Amount" shall have the meaning set forth in Section 280G(b)(3) of the Code.
(D) "Beneficial Owner" shall have the meaning set forth in Rule 13d-3 under the Exchange Act.
(E) "Board" shall mean the Board of Directors of the Company.
(F) "Cause" for termination by Sierra of the Executive's employment shall mean (i) the willful and continued failure by the Executive to substantially perform the Executive's duties with Sierra (other than any such failure resulting from the Executive's incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the Executive pursuant to Section 7.1 hereof) after a written demand for substantial performance is delivered to the Executive by the Board, which demand specifically identifies the manner in which the Board believes that the Executive has not substantially performed the Executive's duties, or (ii) the willful engaging by the Executive in conduct which is demonstrably and materially injurious to Sierra, monetarily or otherwise. For purposes of clauses (i) and (ii) of this definition, (x) no act, or failure to act, on the Executive's part shall be deemed "willful" unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive's act, or failure to act, was in the best interest of Sierra and (y) in the event of a dispute concerning the application of this provision, no claim by Sierra that Cause exists shall be given effect unless Sierra establishes to the Board by clear and convincing evidence that Cause exists.
(G) A "Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) any Person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company (not including in the securities beneficially owned by such Person any securities acquired directly from the Company or its affiliates) representing 30% or more of the combined voting power of the Company's then outstanding securities, excluding any Person who becomes such a Beneficial Owner in connection with a transaction described in clause (i) of paragraph (III) below; or
(II) the following individuals cease for any reason to constitute a majority of the number of directors then serving: individuals who, on the date hereof, constitute the Board and any new director (other than a director whose initial assumption of office is in connection with an actual or threatened election contest, including but not limited to a consent solicitation, relating to the election of directors of the Company) whose appointment or election by the Board or nomination for election by the Company's stockholders was approved or
recommended by a vote of at least two-thirds (2/3) of the directors then still in office who either were directors on the date hereof or whose appointment, election or nomination for election was previously so approved or recommended; or
(III) there is consummated a merger or consolidation of the Company or any direct or indirect subsidiary of the Company with any other corporation, other than (i) a merger or consolidation which would result in the voting securities of the Company outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company or any subsidiary of the Company, at least 66.66% of the combined voting power of the securities of the Company or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or (ii) a merger or consolidation effected to implement a recapitalization of the Company (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company (not including in the securities Beneficially Owned by such Person any securities acquired directly from the Company or its Affiliates other than in connection with the acquisition by the Company or its Affiliates of a business) representing 30% or more of the combined voting power of the Company's then outstanding securities; or
(IV) the stockholders of the Company approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement for the sale or disposition by the Company of all or substantially all of the Company's assets, other than a sale or disposition by the Company of all or substantially all of the Company's assets to an entity, at least 66.66% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale.
Notwithstanding the foregoing, a "Change in Control" shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the common stock of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in an entity which owns all or substantially all of the assets of the Company immediately following such transaction or series of transactions.
(H) "Code" shall mean the Internal Revenue Code of 1986, as amended from time to time.
(I) "Company" shall mean Sierra Pacific Resources and, except in determining under Section 15(G) hereof whether or not any Change in Control of the Company has occurred, shall include any successor to its business and/or assets which assumes and agrees to perform this Agreement by operation of law, or otherwise.
(J) "Date of Termination" shall have the meaning set forth in
Section 7.2 hereof.
(K) "Disability" shall be deemed the reason for the termination by Sierra of the Executive's employment, if, as a result of the Executive's incapacity due to physical or mental illness, the Executive shall have been absent from the full-time performance of the Executive's duties with Sierra for a period of six (6) consecutive months, Sierra shall have given the Executive a Notice of Termination for Disability, and, within thirty (30) days after such Notice of Termination is given, the Executive shall not have returned to the full-time performance of the Executive's duties.
(L) "Exchange Act" shall mean the Securities Exchange Act of 1934, as amended from time to time.
(M) "Executive" shall mean the individual named in the first paragraph of this Agreement.
(N) "Good Reason" for termination by the Executive of the Executive's employment shall mean the occurrence (without the Executive's express written consent) after any Change in Control, or prior to a Change in Control under the circumstances described in clauses (ii) and (iii) of the second sentence of Section 6.1 hereof (treating all references in paragraphs (I) through (VII) below to a "Change in Control" as references to a "Potential Change in Control"), of any one of the following acts by Sierra, or failures by Sierra to act, unless, in the case of any act or failure to act described in paragraphs (I), (IV), (V) or (VI) below, such act or failure to act is corrected prior to the Date of Termination specified in the Notice of Termination given in respect thereof:
(I) Removal of Executive as Chief Executive Officer or Chairman of the Board: the assignment to the Executive of any duties substantially below the Executive's status as the most senior executive officer of Sierra or a substantial adverse reduction in the nature or status of the Executive's responsibilities from those in effect immediately prior to the Change in Control other than any such alteration primarily attributable to the fact that the Company may no longer be a public company;
(II) a reduction by Sierra in the Executive's annual base salary as in effect on the date hereof or as the same may be increased from time to time except for across-the-board salary reductions similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra;
(III) the failure by Sierra to pay to the Executive any portion of the Executive's current compensation except pursuant to an across-the-board compensation deferral similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra, or to pay to the Executive any portion of an installment of deferred compensation under any deferred compensation program of Sierra, within thirty (30) days of the date such compensation is due;
(IV) the failure by Sierra to continue in effect any compensation plan in which the Executive participates immediately prior to the Change in Control which is material to the Executive's total compensation, including but not limited to the Company's Officer and Senior Managers Annual Incentive Plan, Executive Long-Term Incentive Plan, Long-Term Performance Share Program and Stock Option Plan or any substitute plans adopted prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by Sierra to continue the Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount or timing of payment of benefits provided and the level of the Executive's participation relative to other participants, as existed immediately prior to the Change in Control;
(V) the failure by Sierra to continue to provide the Executive with benefits substantially similar to those enjoyed by the Executive under any of Sierra's pension, savings, life insurance, medical, health and accident, or disability plans in which the Executive was participating immediately prior to the Change in Control (except for across the board changes similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra), the taking of any other action by Sierra which would directly or indirectly materially reduce any of such benefits or deprive the Executive of any material fringe benefit enjoyed by the Executive at the time of the Change in Control, or the failure by Sierra to provide the Executive with substantially the same number of paid vacation days to which the Executive is entitled on the basis of years of service with Sierra in accordance with Sierra's normal vacation policy in effect at the time of the Change in Control; or
(VI) any purported termination of the Executive's employment which is not effected pursuant to a Notice of Termination satisfying the requirements of Section 7.1 hereof; for purposes of this Agreement, no such purported termination shall be effective.
The Executive's right to terminate the Executive's employment for Good Reason shall not be affected by the Executive's incapacity due to physical or mental illness. The Executive's continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.
For purposes of any determination regarding the existence of Good Reason, any claim by the Executive that Good Reason exists shall be presumed to be correct unless the Company establishes to the Board by clear and convincing evidence that Good Reason does not exist.
(O) "Notice of Termination" shall have the meaning set forth in Section 7.1 hereof.
(P) "Pension Plan" shall mean any tax-qualified, supplemental or excess benefit pension plan maintained by Sierra and any other plan or agreement entered into between the Executive and Sierra which is designed to provide the Executive with supplemental or additional retirement benefits.
(Q) "Person" shall have the meaning given in Section 3(a)(9)
of the Exchange Act, as modified and used in Sections 13(d) and 14(d) thereof,
except that such term shall not include (i) the Company or any of its
subsidiaries, (ii) a trustee or other fiduciary holding securities under an
employee benefit plan of the Company or any of its Affiliates, (iii) an
underwriter temporarily holding securities pursuant to an offering of such
securities, or (iv) a corporation owned, directly or indirectly, by the
stockholders of the Company in substantially the same proportions as their
ownership of stock of the Company.
(R) "Potential Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) the Company enters into an agreement, the consummation of which would result in the occurrence of a Change in Control;
(II) the Company or any Person publicly announces an intention to take or to consider taking actions which, if consummated, would constitute a Change in Control;
(III) any Person becomes the Beneficial Owner, directly or indirectly, of securities of the Company representing 15% or more of
either the then outstanding shares of common stock of the Company or the combined voting power of the Company's then outstanding securities (not including in the securities beneficially owned by such Person any securities acquired directly from the Company or its affiliates); or
(IV) any of the items in R(I) through (III) occurs which is connected with or arises out of a potential Change in Control, is caused by, or results from another potential Change in Control.
(S) "Retirement" shall be deemed the reason for the termination by the Executive of the Executive's employment if such employment is terminated in accordance with Sierra's retirement policy, including early retirement, generally applicable to its salaried employees.
(T) "Severance Payments" shall have the meaning set forth in
Section 6.1 hereof.
(U) "Tax Counsel" shall have the meaning set forth in Section 6.2 hereof.
(V) "Term" shall mean the period of time described in Section 2 hereof (including any extension, continuation or termination described therein).
(W) "Total Payments" shall mean those payments so described in Section 6.2 hereof.
Sierra Pacific Resources
By:_______________________________
Name:
Title:
Exhibit 10(C)
THIS AGREEMENT, dated May 21, 2001, is made by and between Sierra Pacific Resources, a Nevada corporation (the "Company"), and Dennis D. Schiffel (the "Executive").
WHEREAS, the Company considers it essential to the best interests of its stockholders to foster the continued employment of key management personnel; and
WHEREAS, the Board recognizes that, as is the case with many publicly held corporations, the possibility of a Change in Control exists and that such possibility, and the uncertainty and questions which it may raise among management, may result in the departure or distraction of management personnel to the detriment of the Company and its stockholders; and
WHEREAS, the Board has determined that appropriate steps should be taken to reinforce and encourage the continued attention and dedication of members of the management of the Company and its subsidiaries (collectively, "Sierra"), including the Executive, to their assigned duties without distraction in the face of potentially disturbing circumstances arising from the possibility of a Change in Control;
NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, the Company and the Executive hereby agree as follows:
5.1 Following a Change in Control or potential Change in Control and during the Term, during any period that the Executive fails to perform the Executive's full-time duties with Sierra as a result of incapacity due to physical or mental illness, the Company shall pay the Executive's full salary to the Executive at the rate in effect at the commencement of any such period, together with all compensation and benefits payable to the Executive under the terms of any compensation or benefit plan, program or arrangement maintained by Sierra during such period, until the Executive's employment is terminated by Sierra for Disability.
5.2 If the Executive's employment shall be terminated for any reason following a Change in Control or potential Change in Control and during the Term, the Company shall pay the Executive's full salary to the Executive through the Date of Termination at the rate in effect immediately prior to the Date of Termination or, if higher, the rate in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, together with all compensation and benefits payable to the Executive through the Date of Termination under the terms of Sierra compensation and benefit plans, programs or arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive,
as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason.
5.3 If the Executive's employment shall be terminated for any reason following a Change in Control or potential Change in Control and during the Term, the Company shall pay to the Executive the Executive's normal post-termination compensation and benefits (other than any severance payments forgone under Section 6.1a) as such payments become due, provided that the Executive is eligible or entitled to such compensation and benefits under the terms and conditions of any such plan or program in effect and provided further that the Executive fully complied with all conditions and requirements of any such plan or program, and provided further that such payments or benefits are not otherwise precluded under the terms of this Agreement. Such post-termination compensation and benefits shall be determined under, and paid in accordance with, Sierra's retirement, insurance and other compensation or benefit plans, programs and arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the occurrence of the first event or circumstance constituting Good Reason.
6.1 Subject to Section 6.2 hereof, if the Executive's employment is terminated following a Change in Control or Potential Change in Control and during the Term, other than (A) by Sierra for Cause, (B) by reason of death or Disability, or (C) by the Executive without Good Reason, then Sierra shall pay the Executive the amounts, and provide the Executive the benefits,described in this Section 6.1("Severance Payments"), in addition to any payments and benefits to which theExecutive is entitled under Section 5 hereof. For purposes of this Agreement,the Executive's employment shall be deemed to have been terminated following a Change in Control or Potential Change in Control by Sierra without Cause or by the Executive with Good Reason,if (i) the Executive's employment is terminated by Sierra without Cause prior to a Change in Control (whether or not a Change in Control ever occurs) and suchtermination was at the request or direction of a Person who has entered into agreement with the Company the consummation of which would constitute a Changein Control, (ii) the Executive terminates his employment for Good Reason priorto a Change in Control (whether or not a Change in Control ever occurs) and thecircumstance or event which constitutes Good Reason occurs at the request ordirection of such Person, or (iii) the Executive's employment is terminated by Sierra without Cause or by the Executive for Good Reason and such termination or the circumstance or event which constitutes Good Reason is otherwise in connection with or in anticipation of a Change in Control (whether or not a Change in Control ever occurs). For purposes of any determination regarding the applicability of the immediately preceding sentence, any position taken by the Executive shall be presumed to be correct unless the Company establishes to the Board by clear and convincing evidence that such position is not correct.
(A) In lieu of any further salary payments to the Executive for periods subsequent to the Date of Termination and in lieu of any severance benefit otherwise payable to the Executive under or pursuant to any contract or plan, except for any severance benefits relating to or resulting from the Supplemental Executive Retirement Plan (provided the Executive is a participant in the Plan), whether as a consequence of a Change in Control or otherwise,subject to the provisions of Section 6.2(a), the Company shall pay to the Executive a lump sum severance payment, in cash, equal to three times the sum of (i) the Executive's base salary as in effect immediately prior to the Date of Termination or, if higher, in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, and (ii) the target annual incentive award applicable to the Executive pursuant to any annual bonus or annual cash incentive plan maintained by Sierra in respect of the fiscal year ending immediately prior to the fiscal year in which occurs the Date of Termination or, if higher, immediately prior to the fiscal year in which occurs the first event or circumstance constituting Good Reason.
the decrease made in the Severance Payments pursuant to Section 6.2 hereof, (b) the amount of the subsequent reduction in these Section 6.1 (B) benefits, or (c) the maximum amount which can be paid to the Executive without being, or causing any other payment to be, nondeductible by reason of Section 280G of the Code.
(C) Notwithstanding any provision of any annual or long-term incentive plan to the contrary, the Company shall pay to the Executive a lump sum amount, in cash, equal to the sum of (i) any unpaid incentive compensation which has been allocated or awarded to the Executive for a completed fiscal year or other measuring period preceding the Date of Termination under any such plan and which, as of the Date of Termination, is contingent only upon the continued employment of the Executive to a subsequent date, and (ii) a pro rata portion to the Date of Termination of the aggregate value of all contingent incentive compensation awards to the Executive for all then uncompleted periods under any such plan, calculated as to each such award by multiplying the award that the Executive would have earned on the last day of the performance award period, assuming the achievement, at the target level of the individual and corporate performance goals established with respect to such award, by the fraction obtained by dividing the number of full months and any fractional portion of a month during such performance award period through the Date of Termination by the total number of months contained in such performance award period.
(D) In addition to the retirement benefits to which the Executive is entitled under each Pension Plan or any successor plan thereto, the Company shall pay the Executive a lump sum amount, in cash, equal to the excess of (i) the actuarial equivalent of the aggregate retirement pension (taking into account any early retirement subsidies associated therewith and determined as a straight life annuity commencing at the date (but in no event earlier than the third anniversary of the Date of Termination) as of which the actuarial equivalent of such annuity is greatest) which the Executive would have accrued under the terms of all Pension Plans (without regard to any amendment to any Pension Plan made subsequent to a Change in Control and on or prior to the Date of Termination, which amendment adversely affects in any manner the computation of retirement benefits thereunder), determined as if the Executive were fully vested thereunder and had accumulated (after the Date of Termination) thirty-six (36) additional months of service credit thereunder and had been credited under each Pension Plan during such period with compensation equal to the Executive's compensation (as defined in such Pension Plan) during the twelve (12) months immediately preceding the Date of Termination or, if higher, during the twelve months immediately prior to the first occurrence of an event or circumstance constituting Good Reason, over (ii) the actuarial equivalent of the aggregate retirement pension (taking into account any early retirement subsidies associated therewith and determined as a straight life annuity commencing at
the date (but in no event earlier than the Date of Termination) as of which the actuarial equivalent of such annuity is greatest) which the Executive had accrued pursuant to the provisions of the Pension Plans as of the Date of Termination. For purposes of this Section 6.1(D), "actuarial equivalent" shall be determined using the same assumptions utilized under the Sierra Pacific Power Company Retirement Plan immediately prior to the Date of Termination. or, if more favorable to the Executive, immediately prior to the first occurrence of an event or circumstance constituting Good Reason.
(E) If the Executive would have become entitled to benefits under Sierra's post-retirement health care or life insurance plans, as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, had the Executive's employment terminated at any time during the period of thirty-six (36) months after the Date of Termination, the Company shall provide such post-retirement health care or life insurance benefits to the Executive and the Executive's dependents commencing on the later of (i) the date on which such coverage would have first become available and (ii) the date on which benefits described in subsection (B) of this Section 6.1 terminate.
(B) For purposes of determining whether and the extent to which the Total Payments will be subject to the Excise Tax, (i) no portion of the Total Payments the receipt or enjoyment of which the Executive shall have waived at such
time and in such manner as not to constitute a "payment" within the meaning of
Section 280G(b) of the Code shall be taken into account, (ii) no portion of the
Total Payments shall be taken into account which, in the opinion of tax counsel
("Tax Counsel") reasonably acceptable to the Executive and selected by the
accounting firm (the "Auditor") which was, immediately prior to the Change in
Control, the Company's independent auditor, does not constitute a "parachute
payment" within the meaning of Section 280G(b)(2) of the Code (including by
reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax,
no portion of such Total Payments shall be taken into account which, in the
opinion of Tax Counsel, constitutes reasonable compensation for services
actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in
excess of the Base Amount allocable to such reasonable compensation, and (iii)
the value of any non-cash benefit or any deferred payment or benefit included
in the Total Payments shall be determined by the Auditor in accordance with the
principles of Sections 280G(d)(3) and (4) of the Code.
(C) At the time that payments are made under this Agreement, the Company shall provide the Executive with a written statement setting forth the manner in which such payments were calculated and the basis for such calculations including, without limitation, any opinions or other advice the Company has received from Tax Counsel, the Auditor or other advisors or consultants (and any such opinions or advice which are in writing shall be attached to the statement). If the Executive objects to the Company's calculations, the Company shall pay to the Executive such portion of the Severance Payments (up to 100% thereof) as the Executive with concurrence of tax counsel determine are necessary to result in the proper application of subsection A of this Section 6.2.
6.4 The Company also shall pay to the Executive all legal fees and expenses incurred by the Executive in disputing in good faith any issue hereunder relating to the termination of the Executive's employment, in seeking in good faith to obtain or enforce any benefit or right provided by this Agreement or in connection with any tax audit or proceeding to the extent attributable to the application of Section 4999 of the Code to any payment or benefit provided hereunder. Such payments shall be made within five (5) business days after delivery of the Executive's written requests for payment accompanied with such evidence of fees and expenses incurred as the Company reasonably may require.
6.5 Notwithstanding any other provision of this agreement, except as otherwise permitted by this Agreement, if the executive is entitled to and claims benefits under or pursuant to any other change in control agreement entered into between Company or Sierra and the executive, or any terms or conditions thereunder, the executive shall not be entitled to any of the severance benefits or any other benefits under this agreement or terms or conditions of this agreement.
case of a termination by the Executive, shall not be less than fifteen (15) days nor more than sixty (60) days, respectively, from the date such Notice of Termination is given).
benefits, by offset against any amount claimed to be owed by the Executive to the Company, or otherwise.
9.1 In addition to any obligations imposed by law upon any successor to the Company, the Company will require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of the Company to expressly assume and agree to perform this Agreement in the same manner and to the same extent that the Company would be required to perform it if no such succession had taken place. Failure of the Company to obtain such assumption and agreement prior to the effectiveness of any such succession shall be a breach of this Agreement and shall entitle the Executive to compensation from the Company in the same amount and on the same terms as the Executive would be entitled to hereunder if the Executive were to terminate the Executive's employment for Good Reason after a Change in Control, except that, for purposes of implementing the foregoing, the date on which any such succession becomes effective shall be deemed the Date of Termination.
9.2 This Agreement shall inure to the benefit of and be enforceable by the Executive's personal or legal representatives, executors, administrators, successors, heirs, distributees, devisees and legatees. If the Executive shall die while any amount would still be payable to the Executive hereunder (other than amounts which, by their terms, terminate upon the death of the Executive) if the Executive had continued to live, all such amounts, unless otherwise provided herein, shall be paid in accordance with the terms of this Agreement to the executors, personal representatives or administrators of the Executive's estate.
To the Company:
Sierra Power Resources
6226 West Sahara Avenue
Las Vegas, Nevada 89146
Attention: General Counsel
12.1 The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which shall remain in full force and effect.
14.1 All claims by the Executive for benefits under this Agreement shall be directed to and determined by the Board and shall be in writing. Any denial by the Board of a claim for benefits under this Agreement shall be delivered to the Executive in writing and shall set forth the specific reasons for the denial and the specific provisions of this Agreement relied upon. The Board shall afford a reasonable opportunity to the Executive for a review of the decision denying a claim and shall further allow the Executive to appeal to the Board a decision of the Board
within sixty (60) days after notification by the Board that the Executive's claim has been denied.
(A) "Affiliate" shall have the meaning set forth in Rule 12b-2 promulgated under Section 12 of the Exchange Act or any successor replacement rule.
(B) "Auditor" shall have the meaning set forth in Section 6.2 hereof.
(C) "Base Amount" shall have the meaning set forth in Section 280G(b)(3) of the Code.
(D) "Beneficial Owner" shall have the meaning set forth in Rule 13d-3 under the Exchange Act.
(E) "Board" shall mean the Board of Directors of the Company.
(F) "Cause" for termination by Sierra of the Executive's employment shall mean (i) the willful and continued failure by the Executive to substantially perform the Executive's duties with Sierra (other than any such failure resulting from the Executive's incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the Executive pursuant to Section 7.1 hereof) after a written demand for substantial performance is delivered to the Executive by the Board, which demand specifically identifies the manner in which the Board believes that the Executive has not substantially performed the Executive's duties, or (ii) the willful engaging by the Executive in conduct which is demonstrably and materially injurious to Sierra, monetarily or otherwise. For purposes of clauses (i) and (ii) of this definition, (x) no act, or failure to act, on the Executive's part shall be deemed "willful" unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive's act, or failure to act, was in the best interest of Sierra and (y) in the event of a dispute concerning the application of this provision, no claim by Sierra
that Cause exists shall be given effect unless Sierra establishes to the Board by clear and convincing evidence that Cause exists.
(G) A "Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) any Person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company (not including in the securities beneficially owned by such Person any securities acquired directly from the Company or its affiliates) representing 30% or more of the combined voting power of the Company's then outstanding securities, excluding any Person who becomes such a Beneficial Owner in connection with a transaction described in clause (i) of paragraph (III) below; or
(II) the following individuals cease for any reason to constitute a majority of the number of directors then serving: individuals who, on the date hereof, constitute the Board and any new director (other than a director whose initial assumption of office is in connection with an actual or threatened election contest, including but not limited to a consent solicitation, relating to the election of directors of the Company) whose appointment or election by the Board or nomination for election by the Company's stockholders was approved or recommended by a vote of at least two-thirds (2/3) of the directors then still in office who either were directors on the date hereof or whose appointment, election or nomination for election was previously so approved or recommended; or
(III) there is consummated a merger or consolidation of the Company or any direct or indirect subsidiary of the Company with any other corporation, other than (i) a merger or consolidation which would result in the voting securities of the Company outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company or any subsidiary of the Company, at least 66.66% of the combined voting power of the securities of the Company or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or (ii) a merger or consolidation effected to implement a recapitalization of the Company (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company (not including in the securities Beneficially Owned by such Person any securities acquired directly from the Company or its Affiliates other than in connection with the acquisition by the Company
or its Affiliates of a business) representing 30% or more of the combined voting power of the Company's then outstanding securities; or
(IV) the stockholders of the Company or a court or regulatory agency having juridiction over the matter approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement for or regulatory agency having juridiction over the matter approve a plan approves the sale or disposition by the Company of all or substantially all of the Company's assets, other than a sale or disposition by the Company of all or substantially all of the Company's assets to an entity, at least 66.66% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale.
Notwithstanding the foregoing, except for Sections G(IV) or (V) described above, a "Change in Control" shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the common stock of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in an entity which owns all or substantially all of the assets of the Company immediately following such transaction or series of transactions.
(H) "Code" shall mean the Internal Revenue Code of 1986, as amended from time to time.
(I) "Company" shall mean Sierra Pacific Resources and, except in determining under Section 15(G) hereof whether or not any Change in Control of the Company has occurred, shall include any successor to its business and/or assets which assumes and agrees to perform this Agreement by operation of law, or otherwise.
(J) "Date of Termination" shall have the meaning set forth in
Section 7.2 hereof.
(K) "Disability" shall be deemed the reason for the termination by Sierra of the Executive's employment, if, as a result of the Executive's incapacity due to physical or mental illness, the Executive shall have been absent from the full-time performance of the Executive's duties with Sierra for a period of six (6) consecutive months, Sierra shall have given the Executive a Notice of Termination for Disability, and, within thirty (30) days after such Notice of Termination is given, the Executive shall not have returned to the full-time performance of the Executive's duties.
(L) "Exchange Act" shall mean the Securities Exchange Act of 1934, as amended from time to time.
(M) "Executive" shall mean the individual named in the first paragraph of this Agreement.
(N) "Good Reason" for termination by the Executive of the Executive's employment shall mean the occurrence (without the Executive's express written consent) after any Change in Control, or prior to a Change in Control under the circumstances described in clauses (ii) and (iii) of the second sentence of Section 6.1 hereof (treating all references in paragraphs (I) through (VII) below to a "Change in Control" as references to a "Potential Change in Control"), of any one of the following acts by Sierra, or failures by Sierra to act, unless, in the case of any act or failure to act described in paragraphs (I), (IV), (V) or (VI) below, such act or failure to act is corrected prior to the Date of Termination specified in the Notice of Termination given in respect thereof:
(I) the assignment to the Executive of any duties substantially below the Executive's status as the most senior executive officer of Sierra or a substantial adverse reduction in the nature or status of the Executive's responsibilities from those in effect immediately prior to the Change in Control other than any such alteration primarily attributable to the fact that the Company may no longer be a public company;
(II) a reduction by Sierra in the Executive's annual base salary as in effect on the date hereof or as the same may be increased from time to time except for across-the-board salary reductions similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra;
(III) the failure by Sierra to pay to the Executive any portion of the Executive's current compensation except pursuant to an across-the-board compensation deferral or good faith reduction in compensation necessitated by unfavorable exigent business
conditions or circumstances similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra, or to pay to the Executive any portion of an installment of deferred compensation under any deferred compensation program of Sierra, within thirty (30) days of the date such compensation is due;
(IV) the failure by Sierra to continue in effect any compensation plan in which the Executive participates immediately prior to the Change in Control which is material to the Executive's total compensation, including but not limited to the Company's Officer and Senior Managers Annual Incentive Plan, Executive Long-Term Incentive Plan, Long-Term Performance Share Program and Stock Option Plan or any substitute plans adopted prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by Sierra to continue the Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount or timing of payment of benefits provided and the level of the Executive's participation relative to other participants, as existed immediately prior to the Change in Control;
(V) the failure by Sierra to continue to provide the Executive with benefits substantially similar to those enjoyed by the Executive under any of Sierra's pension, savings, life insurance, medical, health and accident, or disability plans in which the Executive was participating immediately prior to the Change in Control (except for across the board changes similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra), the taking of any other action by Sierra which would directly or indirectly materially reduce any of such benefits or deprive the Executive of any material fringe benefit enjoyed by the Executive at the time of the Change in Control, or the failure by Sierra to provide the Executive with substantially the same number of paid vacation days to which the Executive is entitled on the basis of years of service with Sierra in accordance with Sierra's normal vacation policy in effect at the time of the Change in Control; or
(VI) any purported termination of the Executive's employment which is not effected pursuant to a Notice of Termination satisfying the requirements of Section 7.1 hereof; for purposes of this Agreement, no such purported termination shall be effective.
The Executive's right to terminate the Executive's employment for Good Reason shall not be affected by the Executive's incapacity due to physical or mental illness. The Executive's continued employment shall not constitute consent
to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.
For purposes of any determination regarding the existence of Good Reason, any claim by the Executive that Good Reason exists shall be presumed to be correct unless the Company establishes to the Board by clear and convincing evidence that Good Reason does not exist.
(O) "Notice of Termination" shall have the meaning set forth in Section 7.1 hereof.
(P) "Pension Plan" shall mean any tax-qualified, supplemental or excess benefit pension plan maintained by Sierra and any other plan or agreement entered into between the Executive and Sierra which is designed to provide the Executive with supplemental or additional retirement benefits or credits.
(Q) "Person" shall have the meaning given in Section 3(a)(9)
of the Exchange Act, as modified and used in Sections 13(d) and 14(d) thereof,
except that such term shall not include (i) the Company or any of its
subsidiaries, (ii) a trustee or other fiduciary holding securities under an
employee benefit plan of the Company or any of its Affiliates, (iii) an
underwriter temporarily holding securities pursuant to an offering of such
securities, or (iv) a corporation owned, directly or indirectly, by the
stockholders of the Company in substantially the same proportions as their
ownership of stock of the Company.
(R) "Potential Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) the Company enters into an agreement, the consummation of which would result in the occurrence of a Change in Control;
(II) the Company or any Person publicly announces an intention to take or to consider taking actions which, if consummated, would constitute a Change in Control;
(III) any Person becomes the Beneficial Owner, directly or indirectly, of securities of the Company representing 15% or more of either the then outstanding shares of common stock of the Company or the combined voting power of the Company's then outstanding securities (not including in the securities beneficially owned by such Person any securities acquired directly from the Company or its affiliates); or
(IV) the Board adopts a resolution to the effect that, for purposes of this Agreement, a Potential Change in Control has occurred.
(S) "Retirement" shall be deemed the reason for the termination by the Executive of the Executive's employment if such employment is terminated in accordance with Sierra's retirement policy, including early retirement, generally applicable to its salaried employees.
(T) "Severance Payments" shall have the meaning set forth in
Section 6.1 hereof.
(U) "Tax Counsel" shall have the meaning set forth in Section 6.2 hereof.
(V) "Term" shall mean the period of time described in Section 2 hereof (including any extension, continuation or termination described therein).
(W) "Total Payments" shall mean those payments so described in
Section 6.2 hereof.
Sierra Pacific Resources
By:____________________________________
Name:
Title:
Exhibit 10(D)
THIS AGREEMENT, dated May 21, 2001, is made by and between Sierra Pacific Resources, a Nevada corporation (the "Company"), and John E. Brown (the "Executive").
WHEREAS, the Company considers it essential to the best interests of its stockholders to foster the continued employment of key management personnel; and
WHEREAS, the Board recognizes that, as is the case with many publicly held corporations, the possibility of a Change in Control exists and that such possibility, and the uncertainty and questions which it may raise among management, may result in the departure or distraction of management personnel to the detriment of the Company and its stockholders; and
WHEREAS, the Board has determined that appropriate steps should be taken to reinforce and encourage the continued attention and dedication of members of the management of the Company and its subsidiaries (collectively, "Sierra"), including the Executive, to their assigned duties without distraction in the face of potentially dasturbing circumstances arising from the possibility of a Change in Control;
NOW, THEREFORE, in consideration of the premises and the mutual covenants herein contained, the Company and the Executive hereby agree as follows:
date on which such potential Change in Control shall have resulted in a Change of Control.
5.1 Following a Change in Control or potential Change in Control and during the Term, during any period that the Executive fails to perform the Executive's full-time duties with Sierra as a result of incapacity due to physical or mental illness, the Company shall pay the Executive's full salary to the Executive at the rate in effect at the commencement of any such period, together with all compensation and benefits payable to the Executive under the terms of any compensation or benefit plan, program or arrangement maintained by Sierra during such period, until the Executive's employment is terminated by Sierra for Disabilitq.
5.2 If the Executive's employment shall be terminated for any reason following a Change in Control or potential Change in Control and during the Term, the Company shall pay the Executive's full salary to the Executive through the Date of Termination at the rate in effect immediately prior to the Date of Termination or, if higher, the rate in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, together with all compensation and benefits
payable to the Executive through the Date of Termination under the terms of Sierra compensation and benefit plans, programs or arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason.
5.3 If the Executive's employment shall be terminated for any reason following a Change in Control or Potential Change in Control and during the Term, the Company shall pay to the Executive the Executive's normal post-termination compensation and benefits (other than any severance payments forgone under Section 6.1a) as such payments become due, provided that the Executive is eligible or entitled to such compensation and benefits under the terms and conditions of any such plan or program in effect and provided further that the Executive fully complied with all conditions and requirements of any such plan or program, and provided further that such payments or benefits are not otherwise precluded under the terms of this Agreement. Such post-termination compensation and benefits shall be determined under, and paid in accordance with, Sierra's retirement, insurance and other compensation or benefit plans, programs and arrangements as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the occurrence of the first event or circumstance constituting Good Reason.
Change in Control (whether or not a Change in Control ever occurs). For purposes of any determination regarding the applicability of the immediately preceding sentence, any position taken by the Executive shall be presumed to be correct undess the Company establishes to the Board by clear and convincing evidence that such position is not correct.
(A) In lieu of any further salary payments to the Executive for periods subsequent to the Date of Termination and in lieu of any severance benefit otherwise payable to the Executive under or pursuant to any contract or plan, except for any severance benefits relating to or resulting from the Supplemental Executive Retirement Plan (provided the Executive is a participant in the Plan), whether as a consequence of a Change in Control or otherwise, and subject to the provisions of Section 6.2(a), the Company shall pay to the Executive a lump sum severance payment, in cash, equal to two times the sum of (i) the Executive's base salary as in effect immediately prior to the Date of Termination or, if higher, in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, and (ii) the target annual cash incentive award applicable to the Executive pursuant to any annual cash bonus or annual cash incentive plan maintained by Sierra in respect of the fiscal year ending immediately prior to the fiscal year in which occurs the Date of Termination or, if higher, immediately prior to the fiscal year in which occurs the first event or circumstance constituting Good Reason.
shall be decreased pursuant to Section 6.2 hereof, and the Section 6.1(B)
benefits which remain payable after the application of Section 6.2 hereof
are thereafter reduced pursuant to the immediately preceding sentence, the
Company shall, no later than five (5) business days following such
reduction, pay to the Executive the least of (a) the amount of the
decrease made in the Severance Payments pursuant to Section 6.2 hereof,
(b) the amount of the subsequent reduction in these Section 6.1(B)
benefits, or (c) the maximum amount which can be paid to the Executive
without being, or causing any other payment to be, nondeductible by reason
of Section 280G of the Code.
(C) Notwithstanding any provision of any annual or long-term incentive plan to the contrary, the Company shall pay to the Executive a lump sum amount, in cash, equal to the sum of (i) any unpaid incentive compensation which has been allocated or awarded to the Executive for a completed fiscal year or other measuring period preceding the Date of Termination under any such plan and which, as of the Date of Termination, is contingent only upon the continued employment of the Executive to a subsequent date, and (ii) a pro rata portion to the Date of Termination of the aggregate value of all contingent incentive compensation awards to the Executive for all then uncompleted periods under any such plan, calculated as to each such award by multiplying the award that the Executive would have earned on the last day of the performance award period, assuming the achievement, at the target level of the individual and corporate performance goals established with respect to such award, by the fraction obtained by dividing the number of full months and any fractional portion of a month during such performance award period through the Date of Termination by the total number of months contained in such performance award period.
(D) In addition to the retirement benefits to which the Executive is entitled under each Pension Plan or any successor plan thereto, the Company shall pay the Executive a lump sum amount, in cash, equal to the excess of (i) the actuarial equivalent of the aggregate retirement pension (taking into account any early retirement subsidies associated therewith and determined as a straight life annuity commencing at the date (but in no event earlier than the third anniversary of the Date of Termination) as of which the actuarial equivalent of such annuity is greatest) which the Executive would have accrued under the terms of all Pension Plans (without regard to any amendment to any Pension Plan made subsequent to a Change in Control and on or prior to the Date of Termination, which amendment adversely affects in any manner the computation of retirement benefits thereunder), determined as if the Executive were fully vested thereunder and had accumulated (after the Date of Termination) twenty-four (24) additional months of service credit thereunder and had been credited under each Pension Plan during such period with compensation equal to the Executive's compensation (as defined in such Pension Plan) during the twelve (12) months immediately preceding the Date of Termination gr, if higher, during
the twelve months immediately prior to the first occurrence of an event or
circumstance constituting Good Reason, over (ii) the actuarial equivalent
of the aggregate retirement pension (taking into account any early
retirement subsidies associated therewith and determined as a straight
life annuity commencing at the date (but in no event earlier than the Date
of Termination) as of which the actuarial equivalent of such annuity is
greatest) which the Executive had accrued pursuant to the provisions of
the Pension Plans as of the Date of Termination. For purposes of this
Section 6.1(D), "actuarial equivalent" shall be determined using the same
assumptions utilized under the Sierra Pacific Power Company Retirement
Plan immediately prior to the Date of Termination. or, if more favorable
to the Executive, immediately prior to the first occurrence of an event or
circumstance constituting Good Reason.
(E) If the Executive would have become entitled to benefits under Sierra's post-retirement health care or life insurance plans, as in effect immediately prior to the Date of Termination or, if more favorable to the Executive, as in effect immediately prior to the first occurrence of an event or circumstance constituting Good Reason, had the Executive's employment terminated at any time during the period of twenty-four (24) months after the Date of Termination, the Company shall provide such post-retirement health care or life insurance benefits to the Executive and the Executive's dependents commencing on the later of (i) the date on which such coverage would have first become available and (ii) the date on which benefits described in subsection (B) of this Section 6.1 terminate.
(B) For purposes of determining whether and the extent to which the Total Payments will be subject to the Excise Tax, (i) no portion of the Total Payments the receipt or enjoyment of which the Executive shall have waived at such time and in such manner as not to constitute a "payment" within the meaning of Section 280G(b) gf the Code shall be taken into account, (ii) no portion of the Total Payments shall be taken into account which, in the opinion of tax counsel ("Tax Counsel") reasonably acceptable to the Executive and selected by the accounting firm (the "Auditor") which was, immediately prior to the Change in Control, the Company's independent auditor, does not constitute a "parachute payment" within the meaning of Section 280G(b)(2) of the Code (including by reason of Section 280G(b)(4)(A) of the Code) and, in calculating the Excise Tax, no portion of such Total Payments shall be taken into account which, in the opinion of Tax Counsel, constitutes reasonable compensation for services actually rendered, within the meaning of Section 280G(b)(4)(B) of the Code, in excess of the Base Amount allocable to such reasonable compensation, and (iii) the value of any non-cash benefit or any deferred payment or benefit included in the Total Payments shall be determined by the Auditor in accordance with the principles of Sections 280G(d)(3) and (4) of the Code.
(C) At the time that payments are made under this Agreement, the Company shall provide the Executive with a written statement setting forth the manner in which such payments were calculated and the basis for such calculations including, without limitation, any opinions or other advice the Company has received from Tax Counsel, the Auditor or other advisors or consultants (and any such opinions or advice which are in writing shall be attached to the statement). If the Executive objects to the Company's calculations, the Company shall pay to the Executive such portion of the Severance Payments (up to 100% thereof) as the Executive with concurrence of tax counsel determine are necessary to result in the proper application of subsection A of this Section 6.2.
on the fifth (5th) business day after demand by the Company (together with interest at 120% of the rate provided in Section 1274(b)(2)(B) of the Code).
6.4 The Company also shall pay to the Executive all legal fees and expenses incurred by the Executive in disputing in good faith any issue hereunder relating to the termination of the Executive's employment, in seeking in good faith to obtain or enforce any benefit or right provided by this Agreement or in connection with any tax audit or proceeding to the extent attributable to the application of Section 4999 of the Code to any payment or benefit provided hereunder. Such payments shall be made within five (5) business days after delivery of the Executive's written requests for payment accompanied with such evidence of fees and expenses incurred as the Company reasonably may require.
6.5 Notwithstanding any other provision of this agreement, except as otherwise permitted by this Agreement, if the Executive is entitled to and claims benefits under or pursuant to any other change in control agreement entered into between Company or Sierra and the executive, or any terms or conditions thereunder, the executive shall not be entitled to any of the severance benefits or any other benefits under this agreement or terms or conditions of this agreement.
the Executive's employment is terminated for any other reason, the date specified in the Notice of Termination (which, in the case of a termination by Sierra, shall not be less than thirty (30) days (except in the case of a termination for Cause) and, in the case of a termination by the Executive, shall not be less than fifteen (15) days nor more than sixty (60) days, respectively, from the date such Notice of Termination is given).
than Section 6.1(B) hereof) shall not be reduced by any compensation earned by the Executive as the result of employment by another employer, by retirement benefits, by offset against any amount claimed to be owed by the Executive to the Company, or otherwise.
9.1 In addition to any obligations imposed by law upon any successor to the Company, the Company will require any successor (whether direct or indirect, by purchase, merger, consolidation or otherwise) to all or substantially all of the business and/or assets of the Company to expressly assume and agree to perform this Agreement in the same manner and to the same extent that the Company would be required to perform it if no such succession had taken place. Failure of the Company to obtain such assumption and agreement prior to the effectiveness of any such succession shall be a breach of this Agreement and shall entitle the Executive to compensation from the Company in the same amount and on the same terms as the Executive would be entitled to hereunder if the Executive were to terminate the Executive's employment for Good Reason after a Change in Control, except that, for purposes of implementing the foregoing, the date on which any such succession becomes effective shall be deemed the Date of Termination.
9.2 This Agreement shall inure to the benefit of and be enforceable by the Executive's personal or legal representatives, executors, administrators, successors, heirs, distributees, devisees and legatees. If the Executive shall die while any amount would still be payable to the Executive hereunder (other than amounts which, by their terms, terminate upon the death of the Executive) if the Executive had continued to live, all such amounts, unless otherwise provided herein, shall be paid in accordance with the terms of this Agreement to the executors, personal representatives or administrators of the Executive's estate.
To the Company:
Sierra Power Resources
6226 West Sahara Avenue
Las Vegas, Nevada 89146
Attention: General Counsel
12.1 The invalidity or unenforceability of any provision of this Agreement shall not affect the validity or enforceability of any other provision of this Agreement, which shall remain in full force and effect.
14.1 All claims by the Executive for benefits under this Agreement shall be directed to and determined by the Board and shall be in writing. Any denial by the Board of a claim for benefits under this Agreement shall be delivered to the Executive in writing and shall set forth the specific reasons for the denial and the specific provisions of this Agreement relied upon. The Board shall afford a reasonable opportunity to the Executive for a review of the decision denying a claim and shall further allow the Executive to appeal to the Board a decision of the Board
within sixty (60) days after notification by the Board that the Executive's claim has been denied.
(A) "Affiliate" shall have the meaning set forth in Rule 12b-2 promulgated under Section 12 of the Exchange Act or any successor replacement rule.
(B) "Auditor" shall have the meaning set forth in Section 6.2 hereof.
(C) "Base Amount" shall have the meaning set forth in Section 280G(b)(3) of the Code.
(D) "Beneficial Owner" shall have the meaning set forth in Rule 13d-3 under the Exchange Act.
(E) "Board" shall mean the Board of Directors of the Company.
(F) "Cause" for termination by Sierra of the Executive's employment shall mean (i) the willful and continued failure by the Executive to substantially perform the Executive's duties with Sierra (other than any such failure resulting from the Executive's incapacity due to physical or mental illness or any such actual or anticipated failure after the issuance of a Notice of Termination for Good Reason by the Executive pursuant to Section 7.1 hereof) after a written demand for substantial performance is delivered to the Executive by the Board, which demand specifically identifies the manner in which the Board believes that the Executive has not substantially performed the Executive's duties, or (ii) the willful engaging by the Executive in conduct which is demonstrably and materially injurious to Sierra, monetarily or otherwise. For purposes of clauses (i) and (ii) of this definition, (x) no act, or failure to act, on the Executive's part shall be deemed "willful" unless done, or omitted to be done, by the Executive not in good faith and without reasonable belief that the Executive's act, or failure to act, was in the best interest of Sierra and (y) in the event of a dispute concerning the application of this provision, no claim by Sierra
that Cause exists shall be given effect unless Sierra establishes to the Board by clear and convincing evidence that Cause exists.
(G) A "Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) any Person is or becomes the Beneficial Owner, directly or
indirectly, of securities of the Company (not including in the
securities beneficially owned by such Person any securities acquired
directly from the Company or its affiliates) representing 30% or more
of the combined voting power of the Company's then outstanding
securities, excluding any Person who becomes such a Beneficial Owner
in connection with a transaction described in clause (i) of paragraph
(III) below; or
(II) the following individuals cease for any reason to
constitute a majority of the number of directors then serving:
individuals who, on the date hereof, constitute the Board and any new
director (other than a director whose initial assumption of office is
in connection with an actual or threatened election coftest,
including but not limited to a consent solicitation, relating to the
election of directors of the Company) whose appointment or election
by the Board or nomination for election by the Company's stockholders
was approved or recommended by a vote of at least two-thirds (2/3) of
the directors then still in office who either were directors on the
date hereof or whose appointment, election or nomination for election
was previously so approved or recommended; or
(III) there is consummated a merger or consolidation of the Company or any direct or indirect subsidiary of the Company with any other corporation, other than (i) a merger or consolidation which would result in the voting securities of the Company outstanding immediately prior to such merger or consolidation continuing to represent (either by remaining outstanding or by being converted into voting securities of the surviving entity or any parent thereof), in combination with the ownership of any trustee or other fiduciary holding securities under an employee benefit plan of the Company or any subsidiary of the Company, at least 66.66% of the combined voting power of the securities of the Company or such surviving entity or any parent thereof outstanding immediately after such merger or consolidation, or (ii) a merger or consolidation effected to implement a recapitalization of the Company (or similar transaction) in which no Person is or becomes the Beneficial Owner, directly or indirectly, of securities of the Company (not including in the securities Beneficially Owned by such Person any securities acquired directly from the Company or its Affiliates other than in connection with the acquisition by the Company
or its Affiliates of a business) representing 30% or more of the combined voting power of the Company's then outstanding securities; or
(IV) the stockholders of the Company or a court or regulatory agency having jurisdiction over the matter approve a plan of complete liquidation or dissolution of the Company or there is consummated an agreement for or a court or regulatory agency having jurisdiction over the matter approves the sale or disposition by the Company of all or substantially all of the Company's assets, other than a sale or disposition by the Company of all or substantially all of the Company's assets to an entity, at least 66.66% of the combined voting power of the voting securities of which are owned by stockholders of the Company in substantially the same proportions as their ownership of the Company immediately prior to such sale.
(V) As to and with respect only to Impacted Executives as defined in Section 15.O, there is (a) consummated a sale of a majority of the issued and outstanding stock of Sierra Pacific Power Company or Nevada Power Company, and/or there is consummated an agreement for the sale or disposition by Sierra Pacific Power Company or Nevada Power Company of all or substantially all of either of their assets, or a plan of complete liquidation or dissolution or sale or disposition of all or substantially all of the assets of either Sierra Pacific Power Company or Nevada Power Company is approved or adopted by the stockholders or any court or agency having jurisdiction over the matter, and (b) in addition the event is not an event which is also described in or otherwise satisfies the requirements of Sections G(I) through (IV).
Notwithstanding the foregoing, except for Section G(IV) or (V) described above, a "Change in Control" shall not be deemed to have occurred by virtue of the consummation of any transaction or series of integrated transactions immediately following which the record holders of the common stock of the Company immediately prior to such transaction or series of transactions continue to have substantially the same proportionate ownership in an entity which owns all or substantially all of the assets of the Company immediately following such transaction or series of transactions.
(H) "Code" shall mean the Internal Revenue Code of 1986, as amended from time to time.
(I) "Company" shall mean Sierra Pacific Resources and, except in determining under Section 15(G) hereof whether or not any Change in Control of the Company has occurred, shall include any successor to its business and/or assets
which assumes and agrees to perform this Agreement by operation of law, or otherwise.
(J) "Date of Termination" shall have the meaning set forth in Section 7.2 hereof.
(K) "Disability" shall be deemed the reason for the termination by Sierra of the Executive's employment, if, as a result of the Executive's incapacity due to physical or mental illness, the Executive shall have been absent from the full-time performance of the Executive's duties with Sierra for a period of six (6) consecutive months, Sierra shall have given the Executive a Notice of Termination for Disability, and, within thirty (30) days after such Notice of Termination is given, the Executive shall not have returned to the full-time performance of the Executive's duties.
(L) "Exchange Act" shall mean the Securities Exchange Act of 1934, as amended from time to time.
(M) "Executive" shall mean the individual named in the first paragraph of this Agreement.
(N) "Good Reason" for termination by the Executive of the Executive's
employment shall mean the occurrence (without the Executive's express written
consent) after any Change in Control, or prior to a Change in Control under the
circumstances described in clauses (ii) and (iii) of the second sentence of
Section 6.1 hereof (treating all references in paragraphs (I) through (VII)
below to a "Change in Control" as references to a "Potential Change in
Control"), of any one of the following acts by Sierra, or failures by Sierra to
act, unless, in the case of any act or failure to act described in paragraphs
(I), (IV), (V) or (VI) below, such act or failure to act is corrected prior to
the Date of Termination specified in the Notice of Termination given in respect
thereof:
(I) the assignment to the Executive of any duties substantially below the Executive's status as a senior executive officer of Sierra or a substantial adverse reduction in the nature or status of the Executive's responsibilities from those in effect immediately prior to the Change in Control other than any such alteration primarily attributable to the fact that the Company may no longer be a public company;
(II) a reduction by Sierra in the Executive's annual base salary as in effect on the date hereof or as the same may be increased from time to time except for across-the-board salary reductions similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra;
(III) the failure by Sierra to pay to the Executive any portion of the Executive's current compensation except pursuant to an
across-the-board compensation deferral or good faith reduction in compensation necessitated by unfavorable exigent business conditions or circumstances similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra, or to pay to the Executive any portion of an installment of deferred compensation under any deferred compensation program of Sierra, within thirty (30) days of the date such compensation as due;
(IV) the failure by Sierra to continue in effect any compensation plan in which the Executive participates immediately prior to the Change in Control which is material to the Executive's total compensation, including but not limited to the Company's Officer and Senior Managers Annual Incentive Plan, Executive Long-Term Incentive Plan, Long-Term Performance Share Program and Stock Option Plan or any substitute plans adopted prior to the Change in Control, unless an equitable arrangement (embodied in an ongoing substitute or alternative plan) has been made with respect to such plan, or the failure by Sierra to continue the Executive's participation therein (or in such substitute or alternative plan) on a basis not materially less favorable, both in terms of the amount or timing of payment of benefits provided and the level of the Executive's participation relative to other participants, as existed immediately prior to the Change in Control;
(V) the failure by Sierra to continue to provide the Executive with benefits substantially similar tg those enjoyed by the Executive under any of Sierra's pension, savings, life insurance, medical, health and accident, or disability plans in which the Executive was participating immediately prior to the Change in Control (except for across the board changes similarly affecting all senior executives of Sierra and all senior executives of any Person in control of Sierra), the taking of any other action by Sierra which would directly or indirectly materially reduce any of such benefits or deprive the Executive of any material fringe benefit enjoyed by the Executive at the time of the Change in Control, or the failure by Sierra to provide the Executive with substantially the same number of paid vacation days to which the Executive is entitled on the basis of years of service with Sierra in accordance with Sierra's normal vacation policy in effect at the time of the Change in Control; or
(VI) any purported termination of the Executive's employment which is not effected pursuant to a Notice of Termination satisfying the requirements of Section 7.1 hereof; for purposes of this Agreement, no such purported termination shall be effective.
The Executive's right to terminate the Executive's employment for Good Reason shall not be affected by the Executive's incapacity due to physical or mental illness. The Executive's continued employment shall not constitute consent to, or a waiver of rights with respect to, any act or failure to act constituting Good Reason hereunder.
For purposes of any determination regarding the existence of Good Reason, any claim by the Executive that Good Reason exists shall be presumed to be correct unless the Company establishes to the Board by clear and convincing evidence that Good Reason does not exist.
(O) "Impacted Executive" shall mean (1) an Executive other than an Executive defined in Section O(2) whose employment is terminated within the term for reasons other than cause, following an Event described in Section 15.G.(V), or (2) an Executive who following an Event described in Section 15.G(V) accepts or refuses to accept offered employment with the successor to the entity, business, or assets of Sierra Pacific Power Company or Nevada Power Company. An Impacted Executive is entitled to receive Impacted Executive Compensation.
(P) "Impacted Executive Compensation." If the Executive is an
Impacted Executive as defined in Section O(1), he shall receive the
compensation specified in Sections 5 and 6 in strict accordance with their
terms and conditions. If the Executive is an Impacted Executive as defined in
Section (2), then the lump sum severance payment specified in Section 6.1(a)
shall be limited to two times the difference between (a) the sum of the
Executive's base salary as in effect immediately prior to the date the
Executive became an Impacted Executive and the target annual tax bonus or
incentive applicable to the Executive in respect of the fiscal year immediately
prior to the fiscal year in which the Executive became an Impacted Executive,
and (b) the sum of the Executive's base salary and target annual cash incentive
offered by the successor.
(Q) "Notice of Termination" shall have the meaning set forth in
Section 7.1 hereof.
(R) "Pension Plan" shall mean any tax-qualified, supplemental or excess benefit pension plan maintained by Sierra and any other plan or agreement entered into between the Executive and Sierra which is designed to provide the Executive with supplemental or additional retirement benefits or credits.
(S) "Person" shall have the meaning given in Section 3(a)(9) of the Exchange Act, as modified and used in Sections 13(d) and 14(d) thereof, except that such term shall not include (i) the Company or any of its subsidiaries, (ii) a trustee or other fiduciary holding securities under an employee benefit plan of the Company or any of its Affilaates, (iii) an underwriter temporarily holding securities pursuant to an offering of such securities, or (iv) a corporation owned, directly or indirectly, by the
stockholders of the Company in substantially the same proportions as their ownership of stock of the Company.
(T) "Potential Change in Control" shall be deemed to have occurred if the event set forth in any one of the following paragraphs shall have occurred:
(I) the Company enters into an agreement, the consummation of which would result in the occurrence of a Change in Control;
(II) the Company or any Person publicly announces an intention to take or to consider taking actions which, if consummated, would constitute a Change in Control;
(III) any Person becomes the Beneficial Owner, directly or indirectly, of securities of the Company representing 15% or more of either the then outstanding shares of common stock of the Company or the combined voting power of the Company's then outstanding securities (not including in the securities beneficially owned by such Person any securities acquired directly from the Company or its affiliates); or
(IV) any of the items in R(I) through (III) occurs which is connected with, arises out of, is caused by, or results from another Potential Change in Control.
(U) "Retirement" shall be deemed the reason for the termination by the Executive of the Executive's employment if such employment is terminated in accordance with Sierra's retirement policy, including early retirement, generally applicable to its salaried employees.
(V) "Severance Payments" shall have the meaning set forth in Section 6.1 hereof.
(W) "Tax Counsel" shall have the meaning set forth in Section 6.2 hereof.
(X) "Term" shall mean the period of time described in Section 2 hereof (including any extension, continuation or termination described therein).
(Y) "Total Payments" shall mean those payments so described in
Section 6.2 hereof.
Sierra Pacific Resources
By:__________________________________
Walter M. Higgins
Chairman, President & CEO
EXHIBIT 10(E)
[EXECUTION COPY]
$200,000,000
CREDIT AGREEMENT
dated as of
November 30, 2001
among
NEVADA POWER COMPANY,
UNION BANK OF CALIFORNIA, N.A.,
as Sole Bookrunner and Administrative Agent,
WELLS FARGO BANK, N.A.,
as Syndication Agent,
and
BANK ONE, NA,
BNP PARIBAS and
MELLON BANK, N.A.,
as Co-Documentation Agents,
and
the LENDERS party hereto from time to time
Co-Arranged By
UNION BANK OF CALIFORNIA, N.A. and
WELLS FARGO BANK, N.A.
TABLE OF CONTENTS
Page ---- ARTICLE I DEFINITIONS; CONSTRUCTION.........................................1 SECTION 1.01 Defined Terms...............................................1 SECTION 1.02 Classification of Loans and Borrowings.....................16 SECTION 1.03 Terms Generally............................................16 SECTION 1.04 Accounting Terms; GAAP.....................................16 ARTICLE II THE CREDITS......................................................17 SECTION 2.01 The Commitments............................................17 SECTION 2.02 Loans and Borrowings.......................................17 SECTION 2.03 Requests for Revolving Borrowings..........................18 SECTION 2.04 Funding of Borrowings......................................18 SECTION 2.05 Interest Elections.........................................19 SECTION 2.06 Termination, Reduction and Extension of Commitments....... 20 SECTION 2.07 Repayment of Loans; Evidence of Debt.......................23 SECTION 2.08 Prepayment of Loans........................................24 SECTION 2.09 Fees.......................................................24 SECTION 2.10 Interest...................................................25 SECTION 2.11 Alternate Rate of Interest.................................26 SECTION 2.12 Increased Costs............................................26 SECTION 2.13 Break Funding Payments.....................................27 SECTION 2.14 Taxes......................................................27 SECTION 2.15 Payments Generally; Pro Rata Treatment; Sharing of Set-offs...................................................28 SECTION 2.16 Mitigation Obligations; Replacement of Lenders.............30 ARTICLE III REPRESENTATIONS AND WARRANTIES...................................31 SECTION 3.01 Corporate Status...........................................31 SECTION 3.02 Corporate Power and Authorization..........................31 SECTION 3.03 Execution and Binding Effect...............................31 SECTION 3.04 Governmental Approvals and Filings.........................32 SECTION 3.05 Absence of Conflicts.......................................32 SECTION 3.06 Audited Financial Statements...............................32 SECTION 3.07 Interim Financial Statements...............................33 SECTION 3.08 Absence of Undisclosed Liabilities.........................33 SECTION 3.09 Absence of Material Adverse Change.........................33 SECTION 3.10 Accurate and Complete Disclosure...........................33 SECTION 3.11 Margin Regulations.........................................33 SECTION 3.12 Litigation.................................................34 SECTION 3.13 Absence of Events of Default...............................34 SECTION 3.14 Absence of Other Conflicts.................................34 SECTION 3.15 Insurance..................................................34 SECTION 3.16 Title to Property; No Liens................................35 SECTION 3.17 Taxes......................................................35 |
Page ---- |
TABLE OF CONTENTS
(Continued)
SECTION 3.18 Borrower Not An Investment Company.........................35 SECTION 3.19 Environmental Matters......................................35 SECTION 3.20 ERISA......................................................36 SECTION 3.21 Pari Passu Status..........................................37 SECTION 3.22 Indebtedness...............................................37 SECTION 3.23 Collateral Bonds...........................................37 |
ARTICLE IV CONDITIONS.......................................................38
SECTION 4.01 Effective Date.............................................38
SECTION 4.02 Conditions to All Loans....................................41
ARTICLE V AFFIRMATIVE COVENANTS............................................41
SECTION 5.01 Basic Reporting Requirements...............................42
SECTION 5.02 Insurance..................................................45
SECTION 5.03 Payment of Taxes and Other Potential Charges and Priority
Claims.....................................................45 SECTION 5.04 Preservation of Corporate Status and Franchises............45 SECTION 5.05 Governmental Approvals and Filings.........................46 SECTION 5.06 Maintenance of Properties..................................46 SECTION 5.07 Avoidance of Other Conflicts...............................46 SECTION 5.08 Financial Accounting Practices.............................46 SECTION 5.09 Use of Proceeds............................................47 SECTION 5.10 End of Fiscal Periods......................................47 |
ARTICLE VI NEGATIVE COVENANTS...............................................47
SECTION 6.01 Financial Covenants........................................47 SECTION 6.02 Liens......................................................47 SECTION 6.03 Mergers....................................................49 SECTION 6.04 Dispositions of Properties.................................49 SECTION 6.05 Investments and Acquisitions...............................50 SECTION 6.06 Dividends and Stock Repurchases............................50 SECTION 6.07 Transactions with Affiliates...............................50 SECTION 6.08 Change of Business.........................................50 SECTION 6.09 Equal and Ratable Lien; Grant of Security Interest in Certain Events.............................................51 SECTION 6.10 Restrictive Agreements.....................................52 ARTICLE VII DEFAULTS.........................................................52 SECTION 7.01 Events of Default..........................................52 SECTION 7.02 Consequences of an Event of Default........................54 ARTICLE VIII THE AGENTS......................................................55 SECTION 8.01 Appointment................................................55 SECTION 8.02 General Nature of Administrative Agent's Duties............56 SECTION 8.03 Exercise of Powers.........................................56 |
SECTION 8.04 General Exculpatory Provisions.............................57 SECTION 8.05 Administration by the Administrative Agent.................57 SECTION 8.06 Lenders Not Relying on Administrative Agent or Other Lenders....................................................58 SECTION 8.07 Indemnification............................................59 SECTION 8.08 Administrative Agent in its Individual Capacity............59 SECTION 8.09 Holders of Notes...........................................59 SECTION 8.10 Successor Administrative Agent.............................60 SECTION 8.11 Additional Administrative Agents...........................60 SECTION 8.12 Calculations...............................................61 SECTION 8.13 Syndication Agent..........................................61 SECTION 8.14 Sole Bookrunner............................................61 SECTION 8.15 Co-Documentation Agents....................................61 |
ARTICLE IX MISCELLANEOUS....................................................61
SECTION 9.01 Amendments and Waivers.....................................61 SECTION 9.02 No Implied Waiver; Cumulative Remedies.....................62 SECTION 9.03 Notices....................................................63 SECTION 9.04 Expenses; Taxes; Indemnity.................................63 SECTION 9.05 Severability...............................................64 SECTION 9.06 Prior Understandings.......................................65 SECTION 9.07 Duration; Survival.........................................65 SECTION 9.08 Counterparts...............................................65 SECTION 9.09 Limitation on Payments.....................................65 SECTION 9.10 Set-Off....................................................65 SECTION 9.11 Sharing of Collections.....................................66 SECTION 9.12 Successors and Assigns; Participations; Assignments........67 |
SECTION 9.13 Governing Law; Submission to Jurisdiction Waiver of Jury Trial; Limitation of Liability.............................70
Schedule I COMMITMENTS Schedule II JURISDICTIONS Schedule III LITIGATION Schedule IV LIENS Schedule V ENVIRONMENTAL CLAIMS Schedule VI EXISTING INDEBTEDNESS EXHIBITS -------- Exhibit A FORM OF ASSIGNMENT AND ACCEPTANCE Exhibit B FORM OF BORROWING REQUEST Exhibit C FORM OF PROMISSORY NOTE Exhibit D FORM OF QUARTERLY COMPLIANCE CERTIFICATE |
CREDIT AGREEMENT, dated as of November 30, 2001, among NEVADA POWER COMPANY, a Nevada corporation, UNION BANK OF CALIFORNIA, N.A., as Sole Bookrunner and Administrative Agent, WELLS FARGO BANK, N.A., as Syndication Agent, BANK ONE, NA, BNP PARIBAS and MELLON BANK, N.A., as Co- Documentation Agents, the LENDERS party hereto from time to time, and UNION BANK OF CALIFORNIA, N.A. and WELLS FARGO BANK, N.A., as Co-Lead Arrangers.
WHEREAS, the Borrower (as defined below) has requested, and the Lenders (as defined below) have agreed to make available, the credit facilities described below upon the terms and conditions contained herein.
NOW, THEREFORE, in consideration of the premises and of the mutual covenants herein contained and intending to be legally bound hereby, the parties hereto agree as follows:
ARTICLE I
DEFINITIONS; CONSTRUCTION
As used in this Agreement, the following terms have the following meanings:
A. Prior to the Occurrence of an Acceptable Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ----------- ----------- ----------- ---------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- 0.65% 0.875% 0.975% 1.05% 1.25% Eurodollar Spread -------------------------------------------------------------------------------------------------------------------- 0% 0% 0% 0.05% 0.25% ABR Spread -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 3, 0.10% per annum, (B) in the case of Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum.
B. Upon and After the Occurrence of an Acceptable Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ----------- ----------- ----------- ----------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- Eurodollar Spread 0.525% 0.75% 0.85% 0.925% 1.125% -------------------------------------------------------------------------------------------------------------------- ABR Spread 0% 0% 0% 0% 0.125% -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 4, 0.05% per annum, and (B) in the case of Category 5, 0.25% per annum.
For purposes of the foregoing pricing tables, (1) if either Moody's or S&P shall not have in effect a rating for the Index Debt of Borrower (other than by reason of the circumstances referred
to in the last sentence of this definition), then such rating agency shall be deemed to have established a rating in Category 5, (2) if the ratings established or deemed to have been established by Moody's and S&P for the Index Debt of Borrower shall be changed (other than as a result of a change in the rating system of Moody's or S&P), such change shall be effective as of two Business Days after it is first announced by the applicable rating agency, (3) if more than one Category is applicable at any one time, the Applicable Rate shall be based on the applicable Category having the lowest number (i.e., Category 1 is lower than Category 2), and (4) upon the occurrence of an Acceptable Rate Case and at all times thereafter, the pricing table set forth above under the caption "Upon and After the Occurrence of an Acceptable Rate Case" shall be effective. Each change in the Applicable Rate (including any change based on the occurrence of an Acceptable Rate Case) shall apply during the period commencing on the effective date of such change and ending on the date immediately preceding the effective date of the next such change. If the rating system of Moody's or S&P shall change, or if either such rating agency shall cease to be in the business of rating corporate debt obligations, the Borrower and the Lenders shall negotiate in good faith to amend this definition to reflect such changed rating system or the unavailability of ratings from such rating agency and, pending the effectiveness of any such amendment, the Applicable Rate shall be determined by reference to the rating most recently in effect prior to such change or cessation.
may be (a) terminated or reduced from time to time pursuant to Section 2.06 or 7.02 and (b) reduced or increased from time to time pursuant to assignments by or to such Lender pursuant to Section 9.12. The initial amount of each Lender's Commitment is set forth on Schedule I or in the Assignment and Acceptance pursuant to which such Lender shall have assumed its Commitment, as applicable. The aggregate amount of the Lenders' Commitments shall in no event exceed $150,000,000.
-- ---- Community Right-to-Know Act of 1986, 42 U.S.C.[sect.] 11001 et seq.; the -- ---- Hazardous Material Transportation Act, 49 U.S.C.[sect.]1801 et seq.; and the -- ---- Occupational Safety and Health Act, 29 U.S.C.[sect.] 651 et seq.; and any state -- ---- |
and local or foreign counterparts or equivalents, in each case as amended from time to time.
necessary, to the next 1/100 of 1%) of the quotations for such day for such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by it.
transformers or other equipment that contain dielectric fluid containing levels of polychlorinated biphenyls, and radon gas; (b) any chemicals, materials or substances defined as or included in the definition of "hazardous substances," "hazardous waste," "hazardous materials," "extremely hazardous substances," "restricted hazardous waste," "toxic substances," "toxic pollutants," "contaminants," or "pollutants," or words of similar import, under any applicable Environmental Law; and (c) any other chemical, material or substance, the Release of which is prohibited, limited or regulated by any Governmental Authority.
before its due date a required installment under Section 412(m) of the Code or
Section 302(e) of ERISA, shall be a reportable event regardless of the issuance
of any waivers in accordance with Section 412(d) of the Code).
allocable to such liabilities under Title IV of ERISA (excluding any accrued but unpaid contributions).
For purposes of this Agreement, Loans may be classified and referred to by Class (e.g., a "Revolving Loan") or by Type (e.g., a "Eurodollar Loan" or an "ABR Loan") or by Class and Type (e.g., a "Eurodollar Revolving Loan"). Borrowings also may be classified and referred to by Class (e.g., a "Revolving Borrowing") or by Type (e.g., a "Eurodollar Borrowing") or by Class and Type (e.g., a "Eurodollar Revolving Borrowing").
The definitions of terms herein shall apply equally to the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words "include", "includes" and "including" shall be deemed to be followed by the phrase "without limitation". The word "will" shall be construed to have the same meaning and effect as the word "shall". Unless the context requires otherwise (a) any definition of or reference to any agreement, instrument or other document herein shall be construed as referring to such agreement, instrument or other document as from time to time amended, supplemented or otherwise modified (subject to any restrictions on such amendments, supplements or modifications set forth herein), (b) any reference herein to any Person shall be construed to include such Person's successors and assigns, (c) the words "herein", "hereof" and "hereunder", and words of similar import, shall be construed to refer to this Agreement in its entirety and not to any particular provision hereof and (d) all references herein to Articles, Sections, Exhibits and Schedules shall be construed to refer to Articles and Sections of, and Exhibits and Schedules to, this Agreement.
Except as otherwise expressly provided herein, all terms of an accounting or financial nature shall be construed in accordance with GAAP, as in effect from time to time.
ARTICLE II
THE CREDITS
To request a Revolving Borrowing, the Borrower shall notify the Administrative Agent of such request by telephone (a) in the case of a Eurodollar Revolving Borrowing, not later than 12:00 noon, New York, New York time, three Business Days before the date of the proposed Borrowing, or (b) in the case of an ABR Borrowing, not later than 12:00 noon, New York, New York time, one Business Day before the date of the proposed Borrowing. Each such telephonic Borrowing Request shall be irrevocable and shall be confirmed promptly by hand delivery or telecopy to the Administrative Agent of a written Borrowing Request in the form attached hereto as Exhibit B and signed by the Borrower. Each such telephonic and written Borrowing Request shall specify the following information in compliance with Section 2.02:
(i) the aggregate amount of the requested Borrowing;
(ii) the date of such Borrowing, which shall be a Business Day;
(iii) whether such Borrowing is to be an ABR Borrowing or a Eurodollar Borrowing;
(iv) in the case of a Eurodollar Borrowing, the initial Interest Period to be applicable thereto, which shall be a period contemplated by the definition of the term "Interest Period"; and
(v) the location and number of the Borrower's account to which funds are to be disbursed, which shall comply with the requirements of Section 2.04.
If no election as to the Type of Revolving Borrowing is specified, then the requested Revolving Borrowing shall be an ABR Borrowing. If no Interest Period is specified with respect to any Eurodollar Revolving Borrowing, then the Borrower shall be deemed to have selected an Interest Period of one month's duration. Promptly following receipt of a Borrowing Request in accordance with this Section, the Administrative Agent shall advise each Lender of the details thereof and of the amount of such Lender's Loan to be made as part of the requested Borrowing.
in like funds, to an account of the Borrower maintained with Union Bank of California, N.A. at the Principal Office and designated by the Borrower in the applicable Borrowing Request.
(i) the Borrowing to which such Interest Election Request applies and, if different options are being elected with respect to different portions thereof, the portions thereof to be allocated to each resulting Borrowing (in which case the
information to be specified pursuant to clauses (iii) and (iv) of this paragraph shall be specified for each resulting Borrowing);
(ii) the effective date of the election made pursuant to such Interest Election Request, which shall be a Business Day;
(iii) whether the resulting Borrowing is to be an ABR Borrowing or a Eurodollar Borrowing; and
(iv) if the resulting Borrowing is a Eurodollar Borrowing, the Interest Period to be applicable thereto after giving effect to such election, which shall be a period contemplated by the definition of the term "Interest Period".
If any such Interest Election Request requests a Eurodollar Borrowing but does not specify an Interest Period, then the Borrower shall be deemed to have selected an Interest Period of one month's duration.
(x) if Lenders having Commitments totaling an amount
equal to at least 51% of the aggregate amount of the
Commitments then in effect do not agree as contemplated by
Section 2.06(e)(i), then the Revolving Termination Date shall
not be extended pursuant to this Section 2.06(e) and the
Commitments of all of the Lenders shall remain in effect until
the Revolving Termination Date except as otherwise provided in
this Agreement; and
(y) the Borrower may not request any extension of the Revolving Termination Date pursuant to this Section 2.06(e)(i) more frequently than once in any calendar year.
(ii) Any Loan by any Lender the Commitment of which is to terminate pursuant to Section 2.06(e)(i) hereof that would otherwise be made or converted by such Lender as a Eurodollar Loan having an Interest Period ending after the date such Commitment is to terminate shall be made or continued as an ABR Loan and all ABR Loans of such Lender that would otherwise be converted into Eurodollar Loans having such Interest Periods shall remain as ABR Loans.
(iii) It shall be a condition precedent to any
extension of the Revolving Termination Date that: (a) on the date of such
extension no Default or Event of Default shall have occurred and be continuing;
(b) the representations and warranties made by the Borrower in Article III
shall be true and correct on and as of the date of such extension (or if any
such representation or warranty is expressly stated to have been made as of a
specific date, as of such specific date); and (c) on the date of such extension
there shall have been no material adverse change in the consolidated financial
condition, operations, business or prospects taken as a whole of the Borrower
and its Subsidiaries from that set forth in its financial statements as of
September 30, 2001 referred to in Section 3.06 hereof or, if the Borrower has
delivered its financial statements for any fiscal year to the Lenders and the
Administrative Agent pursuant to Section 5.01(a) hereof, as of the date of the
most recent such financial statements. Each request for an extension of the
Revolving Termination Date pursuant to Section 2.06(e) shall constitute a
certification by the Borrower to the effect set forth in the preceding sentence
(both as of the date of such request and, unless the Borrower notifies the
Administrative Agent prior to the date of such extension, as of the date of
such extension).
(a) the Administrative Agent determines (which determination shall be conclusive, absent manifest error) that adequate and reasonable means do not exist for ascertaining the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period; or
(b) the Administrative Agent is advised by the Required Lenders that the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period will not adequately and fairly reflect the cost to such Lenders (or Lender) of making or maintaining their Loans (or its Loan) included in such Borrowing for such Interest Period;
then the Administrative Agent shall give notice thereof to the Borrower and the Lenders by telephone or telecopy as promptly as practicable thereafter and, until the Administrative Agent notifies the Borrower and the Lenders that the circumstances giving rise to such notice no longer exist, (i) any Interest Election Request that requests the conversion of any Borrowing to, or continuation of any Borrowing as, a Eurodollar Borrowing shall be ineffective, and (ii) if any Borrowing Request requests a Eurodollar Revolving Borrowing, such Borrowing shall be made as an ABR Revolving Borrowing.
(i) impose, modify or deem applicable any reserve, special deposit or similar requirement against assets of, deposits with or for the account of, or credit extended by, any Lender or its Parent (except any such reserve requirement reflected in the Adjusted LIBO Rate); or
(ii) impose on any Lender or its Parent or the London interbank market any other condition affecting this Agreement or Eurodollar Loans made by such Lender;
and the result of any of the foregoing shall be to increase the cost to such Lender or its Parent of making or maintaining any Eurodollar Loan (or of maintaining its obligation to make any such Loan) or to reduce the amount of any sum received or receivable by such Lender hereunder (whether of principal, interest or otherwise), then the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or its Parent, as the case may be, for such additional costs incurred or reduction suffered.
shall make such deductions and (iii) the Borrower shall pay the full amount deducted to the relevant Governmental Authority in accordance with applicable Law.
next succeeding Business Day and, in the case of any payment accruing interest, interest thereon shall be payable for the period of such extension. All payments hereunder shall be made in Dollars.
such assignment will result in a reduction in such compensation or payments. A Lender shall not be required to make any such assignment and delegation if, prior thereto, as a result of a waiver by such Lender or otherwise, the circumstances entitling the Borrower to require such assignment and delegation cease to apply.
ARTICLE III
REPRESENTATIONS AND WARRANTIES
The Borrower hereby represents and warrants to the Administrative Agent and each Lender as follows:
The Borrower and each Subsidiary of the Borrower is a corporation, trust or limited liability company duly organized, validly existing and in good standing under the Laws of its jurisdiction of organization. The Borrower and each Subsidiary of the Borrower has the power (corporate or otherwise) and authority to own its Property and to transact the business in which it is engaged or presently proposes to engage. The Borrower and each Subsidiary of the Borrower is duly qualified to do business as a foreign corporation, trust or limited liability company and is in good standing in all jurisdictions in which the ownership of its Properties or the nature of its activities or both makes such qualification necessary or advisable. Schedule II states as of the date hereof the jurisdiction of organization of the Borrower and each Subsidiary of the Borrower, and the jurisdictions in which the Borrower and each Subsidiary of the Borrower is qualified to do business as a foreign corporation, trust or limited liability company.
The Borrower has the corporate power and authority to execute, deliver, perform, and take all actions contemplated by this Agreement and each of the other Loan Documents to which it is a party, and all such actions have been duly and validly authorized by all necessary corporate proceedings on its part. Without limiting the foregoing, the Borrower has the corporate power and authority to borrow pursuant to the Loan Documents to the fullest extent permitted hereby and thereby from time to time, and has taken all necessary corporate action to authorize such borrowings.
This Agreement and each of the other Loan Documents to which the Borrower is a party and which is required to be delivered on or before the Effective Date pursuant to Section 4.01 has been duly and validly executed and delivered by the Borrower. This Agreement and each such other Loan Document constitutes, and when executed and delivered by the Borrower will constitute, the legal, valid and binding obligation of the Borrower, enforceable against the Borrower in accordance with its terms, except as the enforceability hereof or thereof may be limited by bankruptcy, insolvency or other similar laws of general application affecting the enforcement of creditors' rights or by general principles of equity limiting the availability of equitable remedies.
The Public Utilities Commission of Nevada has duly and validly issued orders authorizing the Borrower to enter into this Agreement and the other Loan Documents to which it is a party and to take all actions contemplated hereby or thereby or in connection herewith or therewith, and such orders remain in full force and effect in the form issued. No other Governmental Action is required for the due execution, delivery and performance by the Borrower of this Agreement or any of the other Loan Documents to which it is a party.
Neither the execution and delivery of any of the Loan Documents by the Borrower, nor the consummation of the transactions herein or therein contemplated by the Borrower, nor the performance of or the compliance with the terms and conditions hereof or thereof by the Borrower, does or will:
(a) violate or conflict with any Law; or
(i) the articles of incorporation or by-laws (or other constituent documents) of the Borrower or any Subsidiary of the Borrower;
(ii) any agreement or instrument creating, evidencing or securing any Indebtedness to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound; or
(iii) any other material agreement or instrument to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders consolidated balance sheets of the Borrower and its consolidated Subsidiaries as of December 31, 1998, 1999 and 2000 and the related consolidated statements of income, retained earnings and changes in cash flows for the fiscal years then ended, as examined and reported on by independent certified public accountants for the Borrower, who delivered an unqualified opinion in respect thereof. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of each
such fiscal year and the results of their operations and their retained earnings and changes in cash flows for the fiscal years then ended, all in conformity with GAAP.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders an interim consolidated balance sheet of the Borrower and its consolidated Subsidiaries as of the end of the third fiscal quarter of the fiscal year beginning January 1, 2001, together with the related consolidated statements of income, retained earnings and changes in cash flows for the applicable fiscal period ending on such date. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of such fiscal quarter and the results of their operations and their retained earnings and changes in cash flows for the fiscal periods then ended, all in conformity with GAAP, subject to normal and recurring year-end audit adjustments.
Neither the Borrower nor any Subsidiary of the Borrower has
any liability or obligation of any nature whatever (whether absolute, accrued,
contingent or otherwise, whether or not due), forward or long-term commitments
or unrealized or anticipated losses from unfavorable commitments, except (a) as
disclosed in the financial statements referred to in Sections 3.06 and 3.07, and
(b) liabilities, obligations, commitments and losses incurred after September
30, 2001, in the ordinary course of business and consistent with past practices.
Since September 30, 2001, there has been no material adverse change in the business, operations, condition (financial or otherwise), or prospects of the Borrower and its Subsidiaries taken as a whole.
All information heretofore, contemporaneously or hereafter provided by or on behalf of the Borrower to any Agent or any Lender pursuant to or in connection with any Loan Document or any transaction contemplated hereby or thereby is or will be (as the case may be) true and accurate in all material respects on the date as of which such information is dated (or, if not dated, when received by such Agent or such Lender) and does not or will not (as the case may be) omit to state any material fact necessary to make such information not misleading at such time in light of the circumstances in which it was provided. The Borrower has disclosed to each Agent and each Lender in writing every fact or circumstance which has, or which so far as the Borrower can reasonably foresee is reasonably likely and is reasonably likely to have, a Material Adverse Effect.
No part of the proceeds of any Loan hereunder will be used for the purpose of buying or carrying any "margin stock", as such term is used in Regulation U of the Board, as amended from time to time, or to extend credit to others for the purpose of buying or carrying
any "margin stock". Neither the Borrower nor any Subsidiary of the Borrower is engaged in the business of extending credit to others for the purpose of buying or carrying "margin stock". Neither the Borrower nor any Subsidiary of the Borrower owns any "margin stock". Neither the making of any Loan nor any use of proceeds of any such Loan will violate or conflict with the provisions of Regulation T, U or X of the Board, as amended from time to time.
There is no pending or (to the Borrower's knowledge after due inquiry) threatened action, suit, proceeding or investigation (including any Environmental Claim) by or before any Governmental Authority against or affecting the Borrower or any Subsidiary of the Borrower which, if adversely decided, individually or in the aggregate, would reasonably be expected to have a Material Adverse Effect, except for (a) matters described in the financial statements referred to in Section 3.06 and (b) matters set forth in Schedule III.
No event has occurred and is continuing and no condition exists which constitutes a Default or an Event of Default.
Neither the Borrower nor any Subsidiary of the Borrower is in violation of or conflict with, or is subject to any contingent liability on account of any violation of or conflict with:
(a) any Law (including ERISA, the Code, any applicable occupational health, safety or welfare Law or any applicable Environmental Law);
(b) its articles of incorporation or by-laws (or other constituent documents); or
(c) any agreement or instrument to which it is party or by which it or any of its properties (now owned or hereafter acquired) may be subject or bound;
except for matters which, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.
The Borrower and each Subsidiary of the Borrower maintains with financially sound and reputable insurers insurance with respect to its properties and business and against at least such liabilities, casualties and contingencies and in at least such types and amounts as is customary in the case of corporations engaged in the same or a similar business or having similar properties similarly situated.
The Borrower and each Subsidiary of the Borrower has good and
marketable title in fee simple to all real Property owned or purported to be
owned by it and good title to all other Property of whatever nature owned or
purported to be owned by it, including but not limited to all Property reflected
in the most recent audited balance sheet referred to in Section 3.06 or
submitted pursuant to Section 5.01(b), as the case may be (except as sold or
otherwise disposed of in the ordinary course of business after the date of such
balance sheet), subject to no Liens except for (i) Liens reflected in the most
recent audited balance sheet referred to in Section 3.06 or submitted pursuant
to Section 5.01(b), as the case may be, (ii) Liens consisting of zoning or
planning restrictions, easements, permits and other restrictions or limitations
on the use of real Property or irregularities in title thereto which do not
materially detract from the value of, or impair the use of, such Property by the
Borrower or any Subsidiary of the Borrower in the operation of its business,
(iii) Liens for current Taxes not yet due and delinquent and (iv) Liens set
forth on Schedule IV.
All tax and information returns required to be filed by or on behalf of the Borrower or any Subsidiary of the Borrower have been properly prepared, executed and filed. All Taxes upon the Borrower or any Subsidiary of the Borrower or upon any of their respective Properties, incomes, sales or franchises which are due and payable have been paid, other than those not yet delinquent and payable without premium or penalty, and except for those being diligently contested in good faith by appropriate proceedings, and in each case for which adequate reserves and provisions for Taxes have been made on the books of the Borrower and each Subsidiary of the Borrower. The reserves and provisions for Taxes on the books of the Borrower and each Subsidiary of the Borrower are adequate for all open years and for its current fiscal period. Neither the Borrower nor any Subsidiary of the Borrower knows of any proposed additional assessment or basis for any material assessment for additional Taxes (whether or not reserved against).
Neither the Borrower nor any Subsidiary of the Borrower is an "investment company" or a company controlled by an "investment company" within the meaning of the Investment Company Act of 1940.
(a) The Borrower and each of its Subsidiaries have complied with and are in compliance with all applicable Environmental Laws and the requirements of any permits issued under such Environmental Laws. Except as disclosed on Schedule V, there are no pending or threatened Environmental Claims against the Borrower or any of its Subsidiaries (including any such claim arising out of the ownership, lease or operation by the Borrower or any of its Subsidiaries of any real Property no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries. Except as disclosed on Schedule V, there are no facts, circumstances, conditions or
occurrences with respect to the business or operations of the Borrower or any of its Subsidiaries, or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries (including any real Property formerly owned, leased or operated by the Borrower or any of its Subsidiaries but no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any Property adjoining or adjacent to any such real Property that could be expected (i) to form the basis of an Environmental Claim against the Borrower or any of its Subsidiaries or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries or (ii) to cause any real Property owned, leased or operated by the Borrower or any of its Subsidiaries to be subject to any restrictions on the ownership, occupancy or transferability of such real Property by the Borrower or any of its Subsidiaries under any applicable Environmental Law.
(b) Hazardous Materials have not at any time been generated, used, treated or stored on, or transported to or from, any real Property owned, leased or operated by the Borrower or any of its Subsidiaries where such generation, use, treatment or storage has violated or could be expected to violate any Environmental Law. Hazardous Materials have not at any time been Released on or from any real Property owned, leased or operated by the Borrower or any of its Subsidiaries where such Release has violated or would be expected to violate any applicable Environmental Law.
(c) Notwithstanding anything to the contrary in this Section, the representations made in this Section shall not be untrue unless the effect of all violations, claims, restrictions, failures and noncompliances of the types described in this Section would reasonably be expected to, individually or in the aggregate, have a Material Adverse Effect.
(a) Each Plan (and each related trust, insurance contract or fund) is in substantial compliance with its terms and with all applicable Laws, including without limitation ERISA and the Code; each Plan (and each related trust, if any) which is intended to be qualified under Section 401(a) of the Code has received a determination letter from the Internal Revenue Service to the effect that it meets the requirements of Sections 401(a) and 501(a) of the Code; no Reportable Event has occurred; no Multiemployer Plan is insolvent or in reorganization; no Plan has an Unfunded Current Liability; no Plan which is subject to Section 412 of the Code or Section 302 of ERISA has an accumulated funding deficiency within the meaning of such sections of the Code or ERISA or has applied for or received a waiver of an accumulated funding deficiency or an extension of any amortization period within the meaning of Section 412 of the Code or Section 303 or 304 of ERISA; all contributions required to be made with respect to a Plan have been timely made; neither the Borrower nor any Subsidiary of the Borrower nor any ERISA Affiliate has incurred any material liability (including any indirect, contingent or secondary liability) to or on account of a Plan pursuant to Section 409, 502(i), 502(l), 515, 4062, 4063, 4064, 4069, 4201, 4204 or 4212 of ERISA or Section 401(a)(29), 4971 or 4975 of the Code or expects to incur any such liability under any of the foregoing sections with respect to any Plan; no condition exists which presents a material risk to the Borrower or any Subsidiary of the Borrower or any ERISA Affiliate of incurring a liability to or on account of a Plan pursuant to the foregoing provisions of ERISA and the Code; no proceedings have been instituted to terminate or appoint a trustee to administer any Plan; no action, suit, proceeding, hearing, audit or investigation with respect to the administration, operation or the investment of assets of any
Plan (other than routine claims for benefits) is pending, expected or threatened; using actuarial assumptions and computation methods consistent with Part 1 of subtitle E of Title IV of ERISA, the aggregate liabilities of the Borrower and its Subsidiaries and its ERISA Affiliates to all Multiemployer Plans in the event of a complete withdrawal therefrom, as of the close of the most recent fiscal year of each such Plan ended prior to the date of the most recent Borrowing, would not have a Material Adverse Effect; each group health plan (as defined in Section 607(1) of ERISA or Section 4980B(g)(2) of the Code) which covers or has covered employees or former employees of the Borrower, any Subsidiary of the Borrower, or any ERISA Affiliate has at all times been operated in compliance with the provisions of Part 6 of subtitle B of Title I of ERISA and Section 4980B of the Code; no Lien imposed under the Code or ERISA on the assets of the Borrower or any Subsidiary of the Borrower or any ERISA Affiliate exists or is likely to arise on account of any Plan; and the Borrower and its Subsidiaries may cease contributions to or terminate any Plan maintained by any of them without incurring any material liability.
(b) Each Foreign Pension Plan, if any, has been maintained in substantial compliance with its terms and with the requirements of any and all applicable Laws, statutes, rules, regulations and orders and has been maintained, where required, in good standing with applicable regulatory authorities. All contributions required to be made with respect to a Foreign Pension Plan have been timely made. Neither the Borrower nor any of its Subsidiaries has incurred any obligation in connection with the termination of or withdrawal from any Foreign Pension Plan. The present value of the accrued benefit liabilities (whether or not vested) under each Foreign Pension Plan, determined as of the end of the Borrower's most recently ended fiscal year on the basis of actuarial assumptions, each of which is reasonable, did not exceed the current value of the assets of such Foreign Pension Plan allocable to such benefit liabilities.
The claims and rights of the Lenders against the Borrower hereunder are not subordinated to, but rank at least pari passu with, the claims and rights of other holders of its unsecured indebtedness except to the extent otherwise provided by Law (including, without limitation, the Bankruptcy Code and the provisions of 31 U.S.C. [sect.] 3713).
Upon any issuance of General and Refunding Mortgage Bonds pursuant to Section 6.09(b) and at all times thereafter, such General and Refunding Mortgage Bonds will have been duly and validly issued and will be entitled to the security and benefits of the General and Refunding Mortgage Indenture; will be secured equally and ratably with and only with all other bonds issued and outstanding under the General and Refunding Mortgage Indenture; will be secured by direct and valid, duly perfected Liens on and security interests in the collateral purported to secure such bonds in the General and Refunding Mortgage Indenture, subject only
to the prior Lien of the First Mortgage Indenture and to Permitted Liens (as such term is defined in the General and Refunding Mortgage Indenture); and will constitute collateral security for the obligations of the Borrower as purported to be provided in the General and Refunding Mortgage Indenture and herein.
ARTICLE IV
CONDITIONS
This Agreement and the other Loan Documents shall become effective as against the Lenders and the Agents on the first date on which all of the following conditions shall be satisfied or waived:
& Stewart, special counsel to the Borrower, and (ii) Woodburn & Wedge, Nevada counsel to the Borrower, in each case as to such matters as may be requested by the Administrative Agent and in form and substance satisfactory to the Lenders.
(i) Each of the representations and warranties made by the Borrower herein and in each other Loan Document shall be true and correct in all material respects on and as of the Effective Date as if made on and as of such date, both before and after giving effect to the Loans requested to be made on such date.
(ii) No Default or Event of Default shall have occurred and be continuing on the Effective Date.
The obligation of each Lender to make, convert or continue any Loan on the occasion of any Borrowing is subject to satisfaction of the conditions precedent set forth in Section 4.01 and satisfaction of the following further conditions precedent:
Each request by the Borrower for any Loan or conversion or continuation thereof shall constitute a representation and warranty by the Borrower that the conditions set forth in this Section 4.02 have been satisfied as of the date of such request. Failure of the Administrative Agent to receive notice from the Borrower to the contrary before such Loan is made shall constitute a further representation and warranty by the Borrower that the conditions referred to in this Section 4.02 have been satisfied as of the date such Loan is made.
ARTICLE V
AFFIRMATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender:
with the Securities and Exchange Commission (or any successor thereto) or any securities exchange and (B) all reports, proxy statements, financial statements and other information distributed by the Borrower to its stockbrokers, bondholders or the financial community generally, and (ii) if requested by the Administrative Agent, deliver or otherwise make available to the Administrative Agent a copy of each application and other document filed by the Borrower with the Public Utilities Commission of Nevada with respect to the Borrower's deferred energy rate case.
(i) Any Default or Event of Default.
(ii) The occurrence or existence of any event or condition (including (A) the violation or alleged violation of any Environmental Law by the Borrower or any Subsidiary of the Borrower or the assertion of any Environmental Claim against the Borrower or any Subsidiary of the Borrower, (B) the commencement of any other action, suit, proceeding or investigation by or before any Governmental Authority against or affecting the Borrower or any Subsidiary of the Borrower, or (C) the violation, breach or default or alleged violation, breach or default by the Borrower or any Subsidiary of the Borrower or any other Person under any agreement or instrument material to the business, operations, condition (financial or otherwise) or prospects of the Borrower and its Subsidiaries taken as a whole) which event or condition, either individually or in the aggregate, has, or would reasonably be expected to have, a Material Adverse Effect.
(iii) Any change in the rating of the Index Debt of Borrower.
exists, a statement signed by a Responsible Officer of the Borrower setting forth details respecting such event or condition and the action, if any, that the Borrower or its ERISA Affiliate proposes to take with respect thereto (and a copy of any report or notice required to be filed with or given to the PBGC by the Borrower or an ERISA Affiliate with respect to such event or condition):
(i) any Reportable Event and any request for a waiver under Section 412(d) of the Code for any Plan;
(ii) the distribution under Section 4041 of ERISA of a notice of intent to terminate any Plan or any action taken by the Borrower or an ERISA Affiliate to terminate any Plan, in each case with respect to which there are insufficient assets to pay benefits as they become due;
(iii) the institution by the PBGC of proceedings under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan, or the receipt by the Borrower or any ERISA Affiliate of a notice from a Multiemployer Plan that such action has been taken by the PBGC with respect to such Multiemployer Plan;
(iv) the complete or partial withdrawal from a Multiemployer Plan by the Borrower or any ERISA Affiliate that results in liability under Section 4201 or 4204 of ERISA (including the obligation to satisfy secondary liability as a result of a purchaser default) or the receipt by the Borrower or any ERISA Affiliate of notice from a Multiemployer Plan that it is in reorganization or insolvency pursuant to Section 4241 or 4245 of ERISA or that it intends to terminate or has terminated under Section 4041A of ERISA; and
(v) the adoption of an amendment to any Plan that, pursuant to Section 401(a)(29) of the Code or Section 307 of ERISA, would result in the loss of tax-exempt status of the trust of which such Plan is a part if the Borrower or an ERISA Affiliate fails to timely provide security to the Plan in accordance with the provisions of said Sections.
The Borrower shall, and shall cause each of its Subsidiaries to, maintain with financially sound and reputable insurers insurance with respect to its properties and business and against such liabilities, casualties and contingencies and of such types and in such amounts as is customary in the case of corporations engaged in the same or similar businesses or having similar properties similarly situated and as is satisfactory from time to time to the Required Lenders in their reasonable discretion.
The Borrower shall, and shall cause each of its Subsidiaries to, pay or discharge
(a) on or prior to the date on which penalties or Liens attach thereto, all Taxes imposed upon it or any of its Properties;
(b) on or prior to the date when due, all lawful claims of materialmen, mechanics, carriers, warehousemen, landlords and other like Persons which, if unpaid, might result in the creation of a Lien upon any such Property; and
(c) on or prior to the date when due, all other lawful claims which, if unpaid, might result in the creation of a Lien upon any such Property or which, if unpaid, might give rise to a claim entitled to priority over general creditors of the Borrower or such Subsidiary in a case under the Bankruptcy Code;
The Borrower shall keep and maintain in full force and effect all Governmental Actions necessary or advisable in connection with execution and delivery of any Loan Document, consummation of the transactions herein or therein contemplated, performance of or compliance with the terms and conditions hereof or thereof or to ensure the legality, validity, binding effect or enforceability hereof or thereof.
The Borrower shall, and shall cause each of its Subsidiaries to, maintain or cause to be maintained in good repair, working order and condition the properties now or hereafter owned, leased or otherwise possessed by it and shall make or cause to be made all needful and proper repairs, renewals, replacements and improvements thereto so that the business carried on in connection therewith may be properly and advantageously conducted at all times.
The Borrower shall not, and shall not permit any of its Subsidiaries to, violate or conflict with, be in violation of or in conflict with, or be or remain subject to any liability (contingent or otherwise) on account of any violation or conflict with:
(a) any Law;
(b) its articles of incorporation or by-laws; or
(c) any agreement or instrument to which it or any of its Subsidiaries is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound,
except for matters which would not reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
The Borrower shall, and shall cause each of its Subsidiaries to, make and keep books, records and accounts which, in reasonable detail, accurately and fairly reflect its transactions and dispositions of its assets and maintain a system of internal accounting controls sufficient to provide reasonable assurances that (a) transactions are executed in accordance with management's general or specific authorization, (b) transactions are recorded as necessary (i) to permit preparation of financial statements in conformity with GAAP and (ii) to maintain accountability for assets, (c) access to assets is permitted only in accordance with management's general or specific authorization and (d) the recorded accountability for assets is compared with the existing assets at reasonable intervals and appropriate action is taken with respect to any differences.
The Borrower shall apply the proceeds of all Loans hereunder only for working capital and general corporate purposes of the Borrower, including commercial paper backup. The Borrower shall not use the proceeds of any Loans hereunder directly or indirectly for any unlawful purpose, in any manner inconsistent with Section 3.11, or inconsistent with any other provision of any Loan Document.
The Borrower shall cause (a) each of its, and each of its Subsidiary's, fiscal years to end on December 31 and (b) each of its, and each of its Subsidiary's, fiscal quarters to end on March 31, June 30, September 30 and December 31.
ARTICLE VI
NEGATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender as follows:
Fiscal Quarter Ended Period -------------------- ------ December 31, 2001 the three consecutive fiscal quarters ended as of the last day of such fiscal quarter March 31, 2002 and each the four consecutive fiscal fiscal quarter ended thereafter quarters ended as of the last day of such fiscal quarter |
(a) Liens existing on the date hereof and securing obligations existing on the date hereof, as such Liens and obligations are listed on Schedule IV;
(d) Liens arising from taxes, assessments, charges or claims described in Section 5.03 that are not yet due or that remain payable without penalty or to the extent permitted to remain unpaid under the proviso to such Section 5.03;
(e) Deposits or pledges of cash or securities in the ordinary course of business to secure (i) worker's compensation, unemployment insurance or other social security obligations, (ii) performance of bids, tenders, trade contracts (other than for payment of money) or leases, (iii) stay, surety or appeal bonds, or (iv) other obligations of a like nature incurred in the ordinary course of business;
(f) Zoning restrictions, easements, minor restrictions on the use of real Property, minor irregularities in title thereto and other minor Liens that do not secure the payment of money or the performance of an obligation and that do not in the aggregate materially detract from the value of an asset to, or materially impair its use in the business of, the Borrower or such Subsidiary; and
"Permitted Liens" shall in no event include any Lien imposed by, or required to be granted pursuant to, ERISA or any Environmental Law.
The Borrower shall not, and shall not permit any of its
Subsidiaries to, (a) merge with or into or consolidate with any other Person,
(b) liquidate, wind-up, dissolve or divide, or (c) agree, become or remain
liable (contingently or otherwise) to do any of the foregoing, except that:
Prior to the making of any Investment or the consummation of any Acquisition by the Borrower or any of its Subsidiaries, the amount or purchase price of which, as the case may be, when aggregated with the amounts and purchase prices of other Investments and Acquisitions made by the Borrower and its Subsidiaries, would exceed $10,000,000 in the aggregate at any time, the Borrower shall deliver to the Administrative Agent (i) a certificate, in a form reasonably satisfactory to the Administrative Agent, certifying that no Default or Event of Default exists or will result from such Acquisition and (ii) pro forma financial statements in support of such certification.
The Borrower shall not enter into any transaction of any kind with any Person that Controls the Borrower or is Controlled by the Borrower or is under common Control with the Borrower other than (a) salary, bonus, employee stock option and other compensation arrangements with directors or officers in the ordinary course of business, (b) transactions that are fully disclosed to the board of directors (or executive committee thereof) of the Borrower and expressly authorized by a resolution of the board of directors (or executive committee) of the Borrower which is approved by a majority of the directors (or executive committee) not having an interest in the transaction, (c) transactions between or among the Borrower and its Wholly-Owned Subsidiaries, (d) transactions between the Borrower and its Subsidiaries, on the one hand, and SPPC and its Subsidiaries, on the other hand, and (e) transactions on overall terms at least as favorable to the Borrower as would be the case in an arm's- length transaction between unrelated parties of equal bargaining power.
The Borrower shall not engage in any business other than the businesses of (a) the generation or purchase of electrical power and (b) the purchase of natural gas, and in each case the transmission and distribution thereof to industrial, commercial and residential customers. In
addition to, and not by way of limitation of, the previous sentence, the
Borrower shall maintain ongoing business segments (as defined in FASB Statement
131 - Disclosure about Segments of an Enterprise and Related Information)
consisting of electricity and gas assets (exclusive of cash and readily
marketable securities) and operating income reflected in the financial
statements of the Borrower as being directly attributable to the generation,
transmission and/or distribution of electricity or gas, which segments and
operating income shall, in the aggregate, comprise not less than 80% of the
consolidated assets (exclusive of cash and readily marketable securities) of
the Borrower and its Subsidiaries.
(a) If, notwithstanding the prohibition contained in Section 6.02, the Borrower or any of its Subsidiaries is subjected to any Lien upon any of its Property, other than those permitted by the provisions of Section 6.02, the Borrower will, and will cause its Subsidiaries to, make or cause to be made effective provisions whereby the Borrowings will be secured equally and ratably with any and all other obligations thereby secured, such security to be pursuant to agreements reasonably satisfactory to the Administrative Agent and, in any such case, the Borrowings shall have the benefit, to the fullest extent that, and with such priority as, the Lenders may be entitled under applicable law, of an equitable Lien on such Property. Such violation of Section 6.02 will constitute an Event of Default, whether or not provision is made for an equal and ratable Lien pursuant to this Section 6.09, and no such Lien or agreements with respect thereto shall be deemed to be a waiver of or consent to such Event of Default by the Administrative Agent or any Lender.
(x) Moody's shall rate the Index Debt of Borrower as Baa3 or lower; or
(y) S&P shall rate the Index Debt of Borrower as BB+ or lower;
then the Borrower shall issue or cause to be issued, not later than five (5) Business Days after the date on which the Triggering Event first occurs, for the ratable benefit of the Lenders, General and Refunding Mortgage Bonds, to the full extent permitted under applicable orders of the Public Utilities Commission of Nevada and the General and Refunding Mortgage Indenture, in an aggregate face amount equal to the aggregate amount of the Commitments (but with an aggregate outstanding principal amount equal to the amount of principal of the Loans outstanding from time to time), with interest and other terms and conditions substantially similar to the Loans, and the Borrower shall perform or cause to be performed all acts, and execute or cause to be executed all resolutions, orders, instruments, certificates, agreements and other documents required under the General and Refunding Mortgage Indenture (including the documents referred to in Section 4.01(p)) to give effect to the foregoing within such five-Business Day period.
Except for agreements referenced in or permitted under this Article VI, the Borrower will not, and will not permit any of its Subsidiaries to, directly or indirectly, enter into, incur or permit to exist any agreement or other arrangement that prohibits, restricts or imposes any condition upon (a) the ability of the Borrower or any of its Subsidiaries to create, incur or permit to exist any Lien upon any of its Property or assets, or (b) the ability of any Subsidiary of the Borrower to pay dividends or other distributions with respect to any shares of its capital stock or to make or repay loans or advances to the Borrower or any other Subsidiary of the Borrower or to guarantee Indebtedness of the Borrower or any other Subsidiary of the Borrower.
ARTICLE VII
DEFAULTS
(a) The Borrower shall fail to pay when due principal of any Loan.
(b) The Borrower shall fail to pay when due interest on any Loan, any fees, indemnity or expenses, or any other amount due hereunder or under any other Loan Document and such failure shall have continued for a period of three (3) Business Days.
(c) Any representation or warranty made or deemed made by the Borrower in or pursuant to or in connection with any Loan Document, or any statement made by the Borrower in any financial statement, certificate, report, exhibit or document furnished by the Borrower to the Administrative Agent or any Lender pursuant to or in connection with any Loan Document, shall prove to have been false or misleading in any material respect as of the time when made or deemed made (including by omission of material information necessary to make such representation, warranty or statement not misleading).
(d) The Borrower shall default in the performance or observance of any covenant contained in Article VI or any of the covenants contained in Section 5.01(f)(i), 5.09 or 5.10.
(e) The Borrower shall default in the performance or observance of any other covenant, agreement or duty under this Agreement or any other Loan Document and (i) in the case of a default under Section 5.01 (other than as referred to in subsection (f)(i) thereof) such default shall have continued for a period of ten (10) Business Days and (ii) in the case of any other default such default shall have continued for a period of 30 days after notice from the Administrative Agent to the Borrower.
(f) The Borrower or any Subsidiary of the Borrower shall (i) fail to make any payment (x) on account of any Indebtedness aggregating $10,000,000 or more in
principal amount or (y) aggregating $10,000,000 or more on any Indebtedness, or any interest or premium thereon, in each case, when due (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and, in each case, such failure shall have continued beyond any applicable grace period specified in any agreement or instrument relating to such Indebtedness, or (ii) fail to perform or observe any other term, covenant or condition on its part to be performed or observed under any agreement or instrument relating to any Indebtedness when required to be performed or observed, and such failure shall have continued beyond any applicable grace period specified in any agreement or instrument relating to such Indebtedness, if the effect of such failure to perform or observe is to accelerate, or to permit the acceleration of, the maturity of such Indebtedness, the unpaid principal amount of which then aggregates $10,000,000 or more.
(g) One or more final judgments or orders for the payment of money shall have been entered against the Borrower or any Subsidiary of the Borrower, which judgments or orders exceed $10,000,000 in the aggregate, and such judgments or orders shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(h) One or more writs or warrants of attachment, garnishment, execution, distraint or similar process exceeding in value the aggregate amount of $10,000,000 shall have been issued against the Borrower or any Subsidiary of the Borrower or any of their respective properties and shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(i) Any Governmental Action now or hereafter made by or with any Governmental Authority in connection with any Loan Document is not obtained or shall have ceased to be in full force and effect or shall have been modified or amended or shall have been held to be illegal or invalid, and the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that the consequence of any of the foregoing events would reasonably be expected to have, individually or in the aggregate, a Material Adverse Effect.
(j) Any Loan Document or any material term or provision thereof shall have ceased to be in full force and effect, or the Borrower or any Governmental Authority with jurisdiction over the Borrower shall, or shall purport to, terminate, repudiate, declare voidable or void or otherwise contest, any Loan Document or any material term or provision thereof or any obligation or liability of the Borrower thereunder.
(k) An event or condition specified in Section 5.01(h) hereof shall occur or exist with respect to any Plan or Multiemployer Plan or any Lien arises pursuant to ERISA and, as a result of such event or condition or Lien, together with all other such events or conditions or Liens, the Borrower or any ERISA Affiliate shall incur or shall be reasonably likely to incur a liability to a Plan, a Multiemployer Plan or the PBGC or suffer an encumbrance to exist in favor of any thereof (or any combination of the foregoing) which would constitute a Material Adverse Effect.
(l) The Borrower or any Subsidiary of the Borrower shall have violated any Environmental Law or become subject to any Environmental Claim and, in either case, the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that such event would reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
(m) A proceeding shall have been instituted in respect of the Borrower or any Subsidiary of the Borrower:
(i) seeking to have an order for relief entered in respect of such Person, or seeking a declaration or entailing a finding that such Person is insolvent or a similar declaration or finding, or seeking dissolution, winding-up, charter revocation or forfeiture, liquidation, reorganization, arrangement, adjustment, composition or other similar relief with respect to such Person, its assets or its debts under any Law relating to bankruptcy, insolvency, relief of debtors or protection of creditors, termination of legal entities or any other similar Law now or hereafter in effect, or
(ii) seeking appointment of a receiver, trustee, liquidator, assignee, sequestrator or other custodian for such Person or for all or any substantial part of its Property,
and such proceeding shall result in the entry, making or grant of any such order for relief, declaration, finding, relief or appointment, or such proceeding shall remain undismissed and unstayed for a period of thirty (30) consecutive days.
(n) The Borrower or any Subsidiary of the Borrower shall become insolvent; shall fail to pay, become unable to pay, or state that it is or will be unable to pay, its debts as they become due; shall voluntarily suspend transaction of its business; shall make a general assignment for the benefit of creditors; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(i), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such order for relief, declaration, finding or relief described therein; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(ii), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such appointment or to the taking of possession by any such custodian of all or any substantial part of its Property; shall dissolve, wind-up, revoke or forfeit its charter (or other constituent documents) or liquidate itself or any substantial part of its Property; or shall take any action in furtherance of any of the foregoing.
(o) A Change in Control shall occur.
(a) If an Event of Default specified in Section 7.01 (other than subsections (m) and (n) thereof) shall occur and be continuing or shall exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder
or under any other Loan Document, at law, in equity or otherwise, the Lenders shall be under no further obligation to make Loans hereunder, and the Administrative Agent may, and, upon the written request of the Required Lenders shall, by notice to the Borrower, from time to time do any or all of the following:
(i) Declare the Commitments terminated, whereupon the Commitments will terminate and any fees hereunder shall be immediately due and payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(ii) Declare the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations to be immediately due and payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(b) If an Event of Default specified in subsection (m) or (n) of Section 7.01 shall occur or exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder or under any other Loan Document, at law, in equity or otherwise, the Commitments shall automatically terminate and the Lenders shall be under no further obligation to make Loans, and the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations shall become immediately due and payable without presentment, demand, protest or notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
ARTICLE VIII
THE AGENTS
Each Lender hereby irrevocably appoints Union Bank of California, N.A. to act as Administrative Agent for such Lender under this Agreement and the other Loan Documents. Each Lender hereby irrevocably authorizes the Administrative Agent to take such action on behalf of such Lender under the provisions of this Agreement and the other Loan Documents, and to exercise such powers and to perform such duties, as are expressly delegated to or required of the Administrative Agent by the terms hereof or thereof, together with such powers as are reasonably incidental thereto. Union Bank of California, N.A. hereby agrees to act as Administrative Agent on behalf of the Lenders on the terms and conditions set forth in this Agreement and the other Loan Documents, subject to its right to resign as provided in Section 8.10. Each Lender hereby irrevocably authorizes the Administrative Agent to execute and deliver each of the Loan Documents executed after the date hereof and to accept delivery of such of the other Loan Documents delivered after the date hereof as may not require execution by the Administrative Agent (with such consents of the Lenders as required pursuant to Section 9.01). Each Lender agrees that the rights and remedies granted to the Administrative Agent under the Loan Documents shall be exercised exclusively by the Administrative Agent, and that no Lender shall have any right individually to exercise any such right or remedy, except to the extent expressly provided herein or therein.
Notwithstanding anything to the contrary elsewhere in this Agreement or in any other Loan Document:
(a) The Administrative Agent shall have no duties or responsibilities except those expressly set forth in this Agreement and the other Loan Documents, and no implied duties or responsibilities on the part of the Administrative Agent shall be read into this Agreement or any other Loan Document or shall otherwise exist.
(b) The duties and responsibilities of the Administrative Agent under this Agreement and the other Loan Documents shall be mechanical and administrative in nature, and the Administrative Agent shall not have a fiduciary relationship in respect of any Lender.
(c) The Administrative Agent is and shall be solely the agent of the Lenders. The Administrative Agent does not assume, and shall not at any time be deemed to have, any relationship of agency or trust with or for, or any other duty or responsibility to, the Borrower or any other Person (except only for its relationship as agent for, and its express duties and responsibilities to, the Lenders as provided in this Agreement and the other Loan Documents).
(d) The Administrative Agent shall be under no obligation to take any action hereunder or under any other Loan Document if the Administrative Agent believes in good faith that taking such action may conflict with any Law or any provision of this Agreement or any other Loan Document, or may require the Administrative Agent to qualify to do business in any jurisdiction where it is not then so qualified.
The Administrative Agent shall take any action of the type
specified in this Agreement or any other Loan Document as being within the
Administrative Agent's rights, powers or discretion in accordance with
directions from the Required Lenders (or, to the extent this Agreement or such
other Loan Document expressly requires the direction or consent of some other
Person or set of Persons, then instead in accordance with the directions of such
other Person or set of Persons). In the absence of such directions, the
Administrative Agent shall have the authority (but under no circumstances shall
be obligated), in its sole discretion, to take any such action, except to the
extent that this Agreement or such other Loan Document expressly requires the
direction or consent of the Required Lenders (or some other Person or set of
Persons), in which case the Administrative Agent shall not take such action
absent such direction or consent. Any action or inaction pursuant to such
direction, discretion or consent shall be binding on all the Lenders. The
Administrative Agent shall not have any liability to any Person as a result of
(a) the Administrative Agent acting or refraining from acting in accordance with
the directions of the Required Lenders (or other applicable Person or set of
Persons), (b) the Administrative Agent refraining from acting in the absence of
instructions to act from the Required Lenders (or other applicable Person or set
of Persons), whether or not the Administrative Agent has discretionary power to
take such action, or (c) the Administrative
Agent taking discretionary action it is authorized to take under this Section (subject, in the case of clauses (b) and (c), to the provisions of Section 8.04(a)).
Notwithstanding anything to the contrary elsewhere in this Agreement or any other Loan Document:
(a) The Administrative Agent shall not be liable for any action taken or omitted to be taken by it under or in connection with this Agreement or any other Loan Document, unless caused by its own gross negligence or willful misconduct.
(b) The Administrative Agent shall not be responsible for (i) the execution, delivery, effectiveness, enforceability, genuineness, validity or adequacy of this Agreement or any other Loan Document, (ii) any recital, representation, warranty, document, certificate, report or statement in, provided for in, or received under or in connection with, this Agreement or any other Loan Document, (iii) any failure of the Borrower or any Lender to perform any of their respective obligations under this Agreement or any other Loan Document, or (iv) the existence, validity, enforceability, perfection, recordation, priority, adequacy or value, now or hereafter, of any Lien or other direct or indirect security afforded or purported to be afforded by any of the Loan Documents or otherwise from time to time.
(c) The Administrative Agent shall not be under any obligation to ascertain, inquire or give any notice relating to (i) the performance or observance of any of the terms or conditions of this Agreement or any other Loan Document on the part of the Borrower, (ii) the business, operations, condition (financial or otherwise) or prospects of the Borrower or any other Person, or (iii) except to the extent set forth in Section 8.05(f), the existence of any Default or Event of Default.
(d) The Administrative Agent shall not be under any obligation, either initially or on a continuing basis, to provide any Lender with any notices, reports or information of any nature, whether in its possession presently or hereafter, except for such notices, reports and other information expressly required by this Agreement or any other Loan Document to be furnished by the Administrative Agent to such Lender.
(a) The Administrative Agent may rely upon any notice or other communication of any nature (written or oral, including but not limited to telephone conversations, whether or not such notice or other communication is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the proper party or parties, and the Administrative Agent shall not have any duty to verify the identity or authority of any Person giving such notice or other communication.
(b) The Administrative Agent may consult with legal counsel (including, without limitation, in-house counsel for the Administrative Agent or in-house or other counsel for the Borrower), independent public accountants and any other experts selected by it from time
to time, and the Administrative Agent shall not be liable for any action taken or omitted to be taken in good faith by it in accordance with the advice of such counsel, accountants or experts.
(c) The Administrative Agent may conclusively rely upon the truth of the statements and the correctness of the opinions expressed in any certificates or opinions furnished to the Administrative Agent in accordance with the requirements of this Agreement or any other Loan Document. Whenever the Administrative Agent shall deem it necessary or desirable that a matter be proved or established with respect to the Borrower or any Lender, such matter may be established by a certificate of the Borrower or such Lender, as the case may be, and the Administrative Agent may conclusively rely upon such certificate (unless other evidence with respect to such matter is specifically prescribed in this Agreement or another Loan Document).
(d) The Administrative Agent may fail or refuse to take any action unless it shall be indemnified to its satisfaction from time to time against any and all amounts, liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs, expenses or disbursements of any kind or nature which may be imposed on, incurred by or asserted against the Administrative Agent by reason of taking or continuing to take any such action.
(e) The Administrative Agent may perform any of its duties under this Agreement or any other Loan Document by or through agents or attorneys-in-fact. The Administrative Agent shall not be responsible for the negligence or misconduct of any agents or attorneys-in-fact selected by it with reasonable care.
(f) The Administrative Agent shall not be deemed to have any knowledge or notice of the occurrence of any Default or Event of Default unless the Administrative Agent has received notice from a Lender or the Borrower referring to this Agreement, describing such Default or Event of Default, and stating that such notice is a "notice of default". If the Administrative Agent receives such a notice, the Administrative Agent shall give prompt notice thereof to each Lender.
Each Lender acknowledges as follows:
(a) Neither the Administrative Agent nor any other Lender has made any representations or warranties to it, and no act taken hereafter by the Administrative Agent or any other Lender shall be deemed to constitute any representation or warranty by the Administrative Agent or such other Lender to it.
(b) It has, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it has deemed appropriate, made its own credit and legal analysis and decision to enter into this Agreement and the other Loan Documents.
(c) It will, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it shall deem appropriate at the time, make its own decisions to take or not take action under or in connection with this Agreement and the other Loan Documents.
With respect to its Commitment and the Obligations owing to it, the Administrative Agent shall have the same rights and powers under this Agreement and each other Loan Document as any other Lender and may exercise the same as though it were not the Administrative Agent, and the terms "Lenders," "holders of Notes" and like terms shall include the Administrative Agent in its individual capacity as such. The Administrative Agent and its affiliates may, without liability to account, make loans to, accept deposits from, acquire debt or equity interests in, act as trustee under indentures of, and engage in any other business with, the Borrower and any stockholder, subsidiary or affiliate of the Borrower, as though the Administrative Agent were not the Administrative Agent hereunder.
The Administrative Agent may deem and treat the Lender which is payee of a Note as the owner and holder of such Note for all purposes hereof unless and until an Assignment and Acceptance with respect to the assignment or transfer thereof shall have been filed with the Administrative Agent in accordance with Section 9.12. Any authority, direction or consent of any Person who at the time of giving such authority, direction or consent is shown in the Register as being a Lender shall be conclusive and binding on each present and subsequent holder, transferee or assignee of any Note or Notes payable to such Lender or of any Note or Notes issued in exchange therefor.
The Administrative Agent shall not be liable for any calculation, apportionment or distribution of payments made by it in good faith, in the absence of its own gross negligence or willful misconduct. If such calculation, apportionment or distribution is subsequently determined to have been made in error, the sole recourse of any Lender to whom payment was due but not made (except as provided in the preceding sentence) shall be to recover from the other Lenders any payment in excess of the amount to which they are determined to be entitled or, if the amount due was not paid by the Borrower, to recover such amount from the Borrower.
As Syndication Agent, Wells Fargo Bank, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Wells Fargo Bank, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Wells Fargo Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Sole Bookrunner, Union Bank of California, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Union Bank of California, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Union Bank of California, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Co-Documentation Agents, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Bank One, NA, BNP Paribas or Mellon Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
ARTICLE IX
MISCELLANEOUS
Neither this Agreement nor any other Loan Document may be amended, modified or supplemented except in accordance with the provisions of this Section 9.01. The
(a) Increase the Commitment of any Lender over the amount thereof then in effect, without the written consent of each Lender affected thereby;
(b) Extend the Revolving Termination Date, without the written consent of all the Lenders;
(c) Reduce the principal amount of or extend the time for any payment of principal of any Loan, or reduce the rate of interest or extend the time for payment of any interest borne by any Loan, or extend the time for payment of or reduce the amount of any fees, or reduce the amount of or postpone the date for payment of any other obligation, without the written consent of each Lender affected thereby;
(d) Change the definition of "Required Lenders" or amend this
Section 9.01 or Section 9.12(a) or any other provision of this
Agreement that requires the consent of all of the Lenders to the taking
or failure to take action hereunder, without the written consent of all
the Lenders;
(e) Amend or waive any of the provisions of Article VIII, or impose additional duties upon the Administrative Agent or otherwise adversely affect the rights, interests or obligations of the Administrative Agent, without the written consent of the Administrative Agent; or
(f) Release any General and Refunding Bonds issued to the Administrative Agent pursuant to Section 6.09(b), without the written consent of all the Lenders;
No course of dealing and no delay or failure of the Administrative Agent or any Lender in exercising any right, power or privilege under this Agreement or any other Loan Document shall affect any other or future exercise thereof or the exercise of any other right,
power or privilege; nor shall any single or partial exercise of any such right, power or privilege or any abandonment or discontinuance of steps to enforce such a right, power or privilege preclude any further exercise thereof or of any other right, power or privilege. The rights and remedies of the Administrative Agent and the Lenders under this Agreement and any other Loan Document are cumulative and not exclusive of any rights or remedies which the Administrative Agent or any Lender would otherwise have hereunder or thereunder, at law, in equity or otherwise.
(b) Any Lender giving any notice to the Borrower or any other party to a Loan Document shall simultaneously send a copy thereof to the Administrative Agent, and the Administrative Agent shall promptly notify the other Lenders of the receipt by it of any such notice.
(c) The Administrative Agent and each Lender may rely on any notice (whether or not such notice is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the Borrower, and neither the Administrative Agent nor any Lender shall have any duty to verify the identity or authority of any Person giving such notice.
(a) The Borrower agrees to pay or cause to be paid and to save
the Administrative Agent and each of the Lenders harmless against liability for
the payment of all reasonable out-of-pocket costs and expenses (including but
not limited to reasonable fees and expenses of counsel) incurred by the
Administrative Agent or any Lender from time to time arising from or relating to
(i) in the case of the Administrative Agent, the negotiation, syndication,
preparation, execution, delivery, administration and performance of this
Agreement and the other Loan Documents, (ii) in the case of the Syndication
Agent, the syndication of this Agreement and the other Loan Documents, (iii) in
the case of the Administrative Agent, any amendments, modifications,
supplements, waivers or consents to this Agreement or any other Loan Document
(whether or not ultimately entered into or granted), and (iv) in the case of the
Administrative Agent or any Lender, the enforcement or preservation of rights
under this
Agreement or any other Loan Document (including but not limited to any such costs or expenses arising from or relating to (A) collection or enforcement of an outstanding Loan or any other amount owing hereunder or thereunder by the Administrative Agent or such Lender, and (B) any litigation, proceeding, dispute, work-out, restructuring or rescheduling related in any way to this Agreement or the Loan Documents).
(b) The Borrower hereby agrees to pay all stamp, document, transfer, recording, filing, registration, search, sales and excise fees and taxes and all similar impositions now or hereafter determined by the Administrative Agent or any Lender to be payable in connection with this Agreement or any other Loan Documents or any other documents, instruments or transactions pursuant to or in connection herewith or therewith (which determination shall be conclusive provided it is reached in good faith), and the Borrower agrees to save the Administrative Agent and each Lender harmless from and against any and all present or future claims, liabilities or losses with respect to or resulting from any omission to pay or delay in paying any such fees, taxes or impositions.
(c) The Borrower hereby agrees to reimburse and indemnify each of the Indemnified Parties from and against any and all losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements of any kind or nature whatsoever (including, without limitation, the reasonable fees and disbursements of counsel for such Indemnified Party in connection with any investigative, administrative or judicial proceeding commenced or threatened, whether or not such Indemnified Party shall be designated a party thereto) that may at any time be imposed on, asserted against or incurred by such Indemnified Party as a result of, or arising out of, or in any way related to or by reason of, this Agreement or any other Loan Document, any transaction from time to time contemplated hereby or thereby, or any transaction financed in whole or in part or directly or indirectly with the proceeds of any Loan (and without in any way limiting the generality of the foregoing, including any violation or breach of any Environmental Law or any other Law by the Borrower or any Subsidiary of the Borrower; any Environmental Claim arising out of the management, use, control, ownership or operation of Property by any of such Persons, including all onsite and off-site activities involving Hazardous Materials; or any exercise by the Administrative Agent or any Lender of any of its rights or remedies under this Agreement or any other Loan Document); but excluding any such losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements resulting solely from the gross negligence or willful misconduct of such Indemnified Party, as finally determined by a court of competent jurisdiction. If and to the extent that the foregoing obligations of the Borrower under this subsection (c), or any other indemnification obligation of the Borrower hereunder or under any other Loan Document, are unenforceable for any reason, the Borrower hereby agrees to make the maximum contribution to the payment and satisfaction of such obligations which is permissible under applicable Law.
The provisions of this Agreement are intended to be severable. If any provision of this Agreement shall be held invalid or unenforceable in whole or in part in any jurisdiction such provision shall, as to such jurisdiction, be ineffective to the extent of such invalidity or
unenforceability without in any manner affecting the validity or enforceability thereof in any other jurisdiction or the remaining provisions hereof in any jurisdiction.
This Agreement and the other Loan Documents, as such agreements shall be amended from time to time, supersede all prior and contemporaneous understandings and agreements, whether written or oral, among the parties hereto relating to the transactions provided for herein and therein.
All representations and warranties of the Borrower contained herein or in any other Loan Document or made in connection herewith or therewith shall survive the making, and shall not be waived by the execution and delivery, of this Agreement or any other Loan Document, any investigation by or knowledge of the Administrative Agent or any Lender, the making of any Loan, or any other event or condition whatever. All covenants and agreements of the Borrower contained herein or in any other Loan Document shall continue in full force and effect from and after the date hereof so long as the Borrower may borrow hereunder and until payment in full of all Obligations. Without limitation, all obligations of the Borrower hereunder or under any other Loan Document to make payments to or indemnify the Administrative Agent or any Lender shall survive the payment in full of all other Obligations, termination of the Borrower's right to borrow hereunder, and all other events and conditions whatever. In addition, all obligations of each Lender to make payments to or indemnify the Administrative Agent shall survive the payment in full by the Borrower of all Obligations, termination of the Borrower's right to borrow hereunder, and all other events or conditions whatever.
This Agreement may be executed in any number of counterparts and by the different parties hereto on separate counterparts each of which, when so executed, shall be deemed an original, but all such counterparts shall constitute but one and the same instrument.
The parties hereto intend to conform to all applicable Laws in effect from time to time limiting the maximum rate of interest that may be charged or collected. Accordingly, notwithstanding any other provision hereof or of any other Loan Document, the Borrower shall not be required to make any payment to or for the account of any Lender, and each Lender shall refund any payment made by the Borrower, to the extent that such requirement or such failure to refund would violate or conflict with nonwaivable provisions of applicable Laws limiting the maximum amount of interest which may be charged or collected by such Lender.
The Borrower hereby agrees that, to the fullest extent permitted by Law, if any Obligation of the Borrower shall be due and payable (by acceleration or otherwise), each Lender shall have the right, without notice to the Borrower, to set-off against and to appropriate and
apply to such Obligation any indebtedness, liability or obligation of any nature owing to the Borrower by such Lender, including but not limited to all deposits (whether time or demand, general or special, provisionally credited or finally credited, whether or not evidenced by a certificate of deposit) now or hereafter maintained by the Borrower with such Lender. Such right shall be absolute and unconditional in all circumstances and, without limitation shall exist whether or not such Lender or any other Person shall have given notice or made a demand to the Borrower or any other Person, whether such indebtedness, obligation or liability owed to the Borrower is contingent, absolute, matured or unmatured (it being agreed that such Lender may deem such indebtedness, obligation or liability to be then due and payable at the time of such setoff), and regardless of the existence or adequacy of any collateral, guaranty or any other security, right or remedy available to any Lender or any other Person. The Borrower hereby agrees that, to the fullest extent permitted by Law, any Participant and any branch, subsidiary or affiliate of any Lender or any Participant shall have the same rights of set-off as a Lender as provided in this Section (regardless of whether such Participant, branch, subsidiary or affiliate would otherwise be deemed in privity with or a direct creditor of the Borrower). The rights provided by this Section are in addition to all other rights of set-off and banker's lien and all other rights and remedies which any Lender (or any such Participant, branch, subsidiary or affiliate) may otherwise have under this Agreement, any other Loan Document, at law or in equity, or otherwise, and nothing in this Agreement or any other Loan Document shall be deemed a waiver or prohibition of or restriction on the rights of set-off or bankers' lien of any such Person.
The Lenders hereby agree among themselves that if any Lender
shall receive (by voluntary payment, realization upon security, set-off or from
any other source) any amount on account of the Loans, interest thereon, or any
other Obligation contemplated by this Agreement or the other Loan Documents to
be made by the Borrower pro rata to all Lenders (or pro rata to holders of
Notes) in greater proportion than any such amount received by any other
applicable Lender, then the Lender receiving such proportionately greater
payment shall notify each other Lender and the Administrative Agent of such
receipt, and equitable adjustment will be made in the manner stated in this
Section 9.11 so that, in effect, all such excess amounts will be shared ratably
among all of the applicable Lenders. The Lender receiving such excess amount
shall purchase (which it shall be deemed to have done simultaneously upon the
receipt of such excess amount) for cash from the other applicable Lenders a
participation in the applicable Obligations owed to such other Lenders in such
amount as shall result in a ratable sharing by all applicable Lenders of such
excess amount (and to such extent the receiving Lender shall be a Participant).
If all or any portion of such excess amount is thereafter recovered from the
Lender making such purchase, such purchase shall be rescinded and the purchase
price restored to the extent of such recovery, together with interest or other
amounts, if any, required by Law to be paid by the Lender making such purchase.
The Borrower hereby consents to and confirms the foregoing arrangements. Each
Participant shall be bound by this Section as fully as if it were a Lender
hereunder.
(ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations,
(iii) the parties hereto shall continue to deal solely and directly with such Lender in connection with such Lender's rights and obligations under this Agreement and each of the other Loan Documents,
(iv) such Participant shall be bound by the provisions of
Section 9.11, and
(v) no Participant (unless such Participant is an Affiliate of such Lender, or is itself a Lender) shall be entitled to require such Lender to take or refrain from taking action under this Agreement or under any other Loan Document, except that such Lender may agree with such Participant that such Lender will not, without such Participant's consent, take any action, or consent to the taking of any action, of the type described in Section 9.01(a), (b) or (c).
(i) any such assignment to a Purchasing Lender which is not a Lender or an affiliate of a Lender shall be made only with the consent (which in each case shall not be unreasonably withheld) of the Borrower (so long as no Default or Event of Default shall have occurred and be continuing) and the Administrative Agent;
(ii) if a Lender makes such an assignment of less than all of its then remaining rights and obligations under this Agreement and the other Loan Documents, such transferor Lender shall retain, after such assignment, a minimum principal amount of $10,000,000 of the Commitments and Loans then outstanding, and such assignment, unless made to an assignee who is a Lender hereunder prior to such assignment, shall be in a minimum principal amount of $10,000,000 of the Commitments and Loans then outstanding;
(iii) each such assignment shall be of a constant, and not a varying, percentage of the Commitment of the transferor Lender and of all of the transferor Lender's rights and obligations under this Agreement and the other Loan Documents; and
(iv) each such assignment shall be made pursuant to an Assignment and Acceptance.
In order to effect any such assignment, the transferor Lender and the Purchasing Lender shall execute and deliver to the Administrative Agent a duly completed Assignment and Acceptance (including the consents required by clause (i) of the preceding sentence) with respect to such assignment, together with any Note or Notes subject to such assignment and a processing and recording fee of $3,500; and, upon receipt thereof, the Administrative Agent shall accept such Assignment and Acceptance. Upon receipt of notice from the transferor Lender that it has received the consideration described in the Assignment and Acceptance, the Administrative Agent shall record such acceptance in the Register. Upon such execution, delivery, acceptance and recording, from and after the close of business at the Administrative Agent's Principal Office on the settlement date specified in such Assignment and Acceptance:
(x) the Purchasing Lender shall be a party hereto and, to the extent provided in such Assignment and Acceptance, shall have the rights and obligations of a Lender hereunder, and
(y) the transferor Lender thereunder shall be released from its obligations under this Agreement to the extent so transferred (and, in the case of an Assignment and Acceptance covering all or the remaining portion of a transferor Lender's rights and obligations under this Agreement, such transferor Lender shall cease to be a party to this Agreement) from and after the settlement date.
On or prior to the settlement date specified in an Assignment and Acceptance, the Borrower, at its expense, shall execute and deliver to the Administrative Agent (for delivery to the Purchasing Lender) new Notes evidencing such Purchasing Lender's assigned Commitment or Loans and (for delivery to the transferor Lender) replacement Notes in the principal amount of the Loans or Commitment retained by the transferor Lender (such Notes to be in exchange for, but not in payment of, those Notes then held by such transferor Lender). Each such Note shall be dated the
date and be substantially in the form of the predecessor Note. The Administrative Agent shall mark the predecessor Notes "exchanged" and deliver them to the Borrower. Accrued interest and accrued fees shall be paid to the Purchasing Lender at the same time or times provided in the predecessor Notes and this Agreement.
(ii) WAIVES ANY OBJECTION WHICH IT MAY HAVE AT ANY TIME TO THE LAYING OF VENUE OF ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, WAIVES ANY CLAIM THAT ANY SUCH RELATED LITIGATION HAS BEEN BROUGHT IN AN INCONVENIENT FORUM, AND WAIVES ANY RIGHT TO OBJECT, WITH RESPECT TO ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, THAT SUCH COURT DOES NOT HAVE JURISDICTION OVER IT;
(iii) CONSENTS AND AGREES TO SERVICE OF ANY SUMMONS, COMPLAINT OR OTHER LEGAL PROCESS IN ANY RELATED LITIGATION BY REGISTERED OR CERTIFIED U.S. MAIL, POSTAGE PREPAID, TO IT AT THE ADDRESS FOR NOTICES DESCRIBED IN SECTION 9.03, AND CONSENTS AND AGREES THAT SUCH SERVICE SHALL CONSTITUTE IN EVERY RESPECT VALID AND EFFECTIVE SERVICE (BUT NOTHING HEREIN SHALL AFFECT THE VALIDITY OR EFFECTIVENESS OF PROCESS SERVED IN ANY OTHER MANNER PERMITTED BY LAW); AND
(iv) WAIVES THE RIGHT TO TRIAL BY JURY IN ANY RELATED LITIGATION.
* * *
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed and delivered as of the day and year first above written.
Address NEVADA POWER COMPANY ------- c/o Sierra Pacific Resources 6100 Neil Road P.O. Box 30150 By___________________________ Reno, Nevada 89520 Name: |
Attn: Richard K. Atkinson Title:
Signature Page to Nevada Power Company Credit Agreement
Address UNION BANK OF CALIFORNIA, N.A., as ------- Administrative Agent, as Co-Lead Arranger, as Sole Bookrunner and Union Bank of California, N.A. as a Lender 445 South Figueroa Street, 15th Floor Los Angeles, CA 90071 Attn: Robert Olson By_______________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address WELLS FARGO BANK, N.A., as ------- Syndication Agent,as Co-Lead Arranger and as a Lender Wells Fargo Bank, N.A. 555 Montgomery Street, 17th Floor San Francisco, CA 94111 Attn: Dennis Bloch By_______________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address BANK ONE, NA, as Co-Documentation Agent ------- and as a Lender Bank One, NA 1 Bank One Plaza, Suite IL1-0363 Chicago, IL 60670 Attn: Dawn M. Lawler By_______________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address BNP PARIBAS, as Co-Documentation Agent ------- and as a Lender BNP Paribas 787 Seventh Avenue New York, NY 10019 Attn: Sean Finnegan By_______________________________ Name: Title: By_______________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address MELLON BANK, N.A., as Co-Documentation ------- Agent and as a lender Mellon Bank, N.A. One Mellon Center 500 Grant Street, Room 4530 Pittsburgh, PA 15258-0001 By_______________________________ Attn: Mark W. Rogers Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address BAYERISCHE LANDESBANK ------- GIROZENTRALE Bayerische Landesbank Girozentrale 560 Lexington Avenue New York, NY 10022 Attn: Jim Monaghan By_______________________________ Name: Title: By_______________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address THE INDUSTRIAL BANK OF JAPAN, ------- LIMITED The Industrial Bank of Japan, Limited 350 S. Grand Avenue, Suite 1500 Los Angeles, CA 09971 Attn: A1 Torres By__________________________ Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address LEHMAN COMMERCIAL PAPER INC. ------- Lehman Commercial Paper Inc. 101 Hudson Street Jersey City, NJ 07302 By__________________________ Attn: Michele Swanson Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address FIRST UNION NATIONAL BANK ------- First Union National Bank 301 South College Street Charlotte, NC 38388-0251 By____________________________ Attn: Joe Dancy Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
Address MERRILL LYNCH BANK USA ------- Merrill Lynch Bank USA 15 W. South Temple, Suite 300 Salt Lake City, UT 84101 By_______________________________ Attn: Butch Alder Name: |
Title:
Signature Page to Nevada Power Company Credit Agreement
[See definitions of "Commitment" in Section 1.01]
LENDER COMMITMENT AMOUNT ------ ----------------- Union Bank of California, N.A. $31,428,571.43 Wells Fargo Bank, N.A. $31,428,571.43 Bank One, N.A. $28,235,294.12 BNP Paribas $28,235,294.12 Mellon Bank, N.A. $24,537,815.13 Bayerische Landesbank Girozentrale $21,176,470.59 Lehman Commercial Paper Inc. $12,268,907.55 The Industrial Bank of Japan, Limited $8,571,428.57 First Union National Bank $7,058,823.53 Merrill Lynch Bank USA $7,058,823.53 Total: $200,000,000.00 |
Exhibit 10(F)
Western Systems Power Pool.
Rate Schedule FERC No. 6
Western Systems Power Pool Agreement
Issued by: Michael E.Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 1 Rate Schedule FERC No. 6 |
TABLE OF CONTENTS
PAGE 1. PARTIES..................................................................................................4 2. RECITALS.................................................................................................4 3. AGREEMENT................................................................................................5 4. DEFINITIONS..............................................................................................5 5. TERM AND TERMINATION....................................................................................11 6. SERVICE SCHEDULES AND WSPP DEFAULT TRANSMISSION TARIFF..................................................12 7. HUB AND OPERATING AGENT.................................................................................13 8. ORGANIZATION AND ADMINISTRATION.........................................................................16 9. PAYMENTS................................................................................................20 10. UNCONTROLLABLE FORCES...................................................................................22 11. WAIVERS.................................................................................................24 12. NOTICES.................................................................................................24 13. APPROVALS...............................................................................................25 14. TRANSFER OF INTEREST IN AGREEMENT.......................................................................27 15. SEVERABILITY............................................................................................28 16. MEMBERSHIP..............................................................................................28 17. RELATIONSHIP OF PARTIES.................................................................................29 18. NO DEDICATION OF FACILITIES.............................................................................30 |
Western Systems Power Pool First Revised Sheet No. 2 Rate Schedule FERC No. 6 Superseding Original Sheet No. 2
TABLE OF CONTENTS
PAGE 19. NO RETAIL SERVICES......................................................................................30 20. THIRD PARTY BENEFICIARIES...............................................................................30 21. LIABILITY AND DAMAGES...................................................................................30 22. DEFAULT OF TRANSACTIONS UNDER THIS AGREEMENT AND CONFIRMATION AGREEMENTS.................................................................................34 23. OTHER AGREEMENTS........................................................................................43 24. GOVERNING LAW...........................................................................................43 25. JUDGMENTS AND DETERMINATIONS............................................................................43 26. COMPLETE AGREEMENT......................................................................................44 27. CREDITWORTHINESS........................................................................................44 28. NETTING AND SET-OFF.....................................................................................46 29. TAXES..................................................................................................47A 30. CONFIDENTIALITY.........................................................................................48 31. TRANSMISSION TARIFF.....................................................................................49 32. TRANSACTION SPECIFIC TERMS AND ORAL AGREEMENTS..........................................................49 33. PERFORMANCE, TITLE, AND WARRANTIES FOR TRANSACTIONS UNDER SERVICE SCHEDULES................................................................................52A 34. DISPUTE RESOLUTION......................................................................................53 35. FORWARD CONTRACTS.......................................................................................56 |
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Third Revised Sheet No. 3 |
Rate Schedule FERC No. 6 Superseding Second Revised Sheet No. 3
TABLE OF CONTENTS
PAGE 36. TRADE OPTION EXCEPTION..................................................................................56 37. ADDITIONAL REPRESENTATIONS AND WARRANTIES...............................................................57 38. FLOATING PRICES.........................................................................................58 39. AMENDMENT..............................................................................................58B 40. EXECUTION BY COUNTERPARTS..............................................................................58B 41. WITNESS.................................................................................................59 |
EXHIBIT A: NETTING EXHIBIT B: FORM OF COUNTERPARTY GUARANTEE AGREEMENT EXHIBIT C: SAMPLE FORM FOR CONFIRMATION EXHIBIT D: WSPP MEDIATION AND ARBITRATION PROCEDURES SERVICE SCHEDULES A. ECONOMY ENERGY SERVICE B. UNIT COMMITMENT SERVICE C. FIRM CAPACITY/ENERGY SALE OR EXCHANGE SERVICE |
LIST OF MEMBERS
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 4 Rate Schedule FERC No. 6 |
1. PARTIES:
The Parties to this Western Systems Power Pool Agreement
(hereinafter referred to as "Agreement") are those entities
that have executed this Agreement, hereinafter sometimes
referred to individually as "Party" and collectively as
"Parties," but excluding any such entity that withdraws its
participation in the Agreement.
2. RECITALS:
2.1 The WSPP experiment has been successfully concluded. Its main
purpose was to determine the feasibility of a marketing
arrangement which would increase the efficiency of
interconnected power system operations above that already
being accomplished with existing agreements through increased
market knowledge and market pricing of commodities.
2.2 The Parties now desire to proceed with a similar marketing
arrangement on a long term basis for prescheduled and
real-time coordinated power transactions, such as economy
energy transactions, unit commitment service, firm system
capacity/energy sales or exchanges. Accordingly, this
Agreement, together with any applicable Confirmation
Agreement, sets forth the terms and conditions to implement
these services within any applicable rate ceilings set forth
in the Service Schedules in conformance with FERC orders where
applicable.
Western Systems Power Pool First Revised Sheet No. 5 Rate Schedule FERC No. 6 Superseding Original Sheet No. 5
apply. Similarly, where both the Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Second Revised Sheet No. 6 |
Rate Schedule FERC No. 6 Superseding First Revised Sheet No. 6
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 6A |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 6A
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 7 Rate Schedule FERC No. 6 Superseding Original Sheet No. 7 |
Western Systems Power Pool First Revised Sheet No. 8 Rate Schedule FERC No. 6 Superseding Original Sheet No. 8 4.8 Hub: An electronic communication center that functions as a --- central point to electronically receive and assemble data for offers to buy or sell power or transmission service from each Party and make that data electronically available concurrently to all Parties. 4.9 Incremental Cost: The forecasted expense incurred by the ----------------- Seller in providing an additional increment of energy or capacity during a given hour. 4.10 Independent Power Producer: An entity which is a --------------------------- non-traditional public utility that produces and sells electricity but which does not have a retail service franchise. 4.11 Interconnected Transmission System: The total of all ------------------------------------ transmission facilities owned or operated by the Parties, including transmission facilities over which Parties have scheduling rights. 4.11a Letter of Credit: An irrevocable, transferable, standby letter of credit, issued by an issuer acceptable to the Party requiring the Letter of Credit. 4.11b NERC. North American Electric Reliability Council or any successor organization. 4.12 Operating Agent: Arizona Public Service Company, or its ---------------- successor as may be designated by the Executive Committee. 4.13 Operating Committee: That committee established pursuant to ------------------- Section 8 of this Agreement. Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 9 Rate Schedule FERC No. 6 4.14 Power Marketer: An entity which buys, sells, and takes title -------------- to electric energy, transmission and/or other services from traditional utilities and other suppliers. 4.14a Physically-Settled Option: Includes (i) a call option which is the right, but not the obligation, to buy an underlying power product as defined under Service Schedules B or C according to the price and exercise terms set forth in the Confirmation Agreement; and (ii) a put option which is the right, but not the obligation, to sell an underlying power product as defined under Service Schedules B or C according to the price and exercise terms set forth in the Confirmation Agreement. 4.14b Premium: The amount paid by the Purchaser of a Physically-Settled Option to the Seller of such Option by the date agreed to by the Parties in the Confirmation Agreement. 4.15 Purchaser: Any Party which agrees to buy or receive from one --------- or more of the other Parties any service pursuant to the Agreement under any Service Schedule and any applicable Confirmation Agreement. 4.16 Qualifying Facility: A facility which is a qualifying small ------------------- power production facility or a qualifying cogeneration facility as these terms are defined in Federal Power Act Sections 3(17)(A), 3(17)(C), 3(18)(A), and 3(18)(B); which meets the requirements set forth in 18 C.F.R. [sect.][sect.] 292.203-292.209; or a facility in Canada or Mexico that complies with similar requirements. |
Western Systems Power Pool First Revised Sheet No. 10 Rate Schedule FERC No. 6 Superseding Original Sheet No. 10 4.16a Replacement Price: The price at which the Purchaser, acting in ----------------- a commercially reasonable manner, effects a purchase of substitute electric energy in place of the electric energy not delivered by the Seller or, absent such a purchase, the market price for such quantity of electric energy, as determined by the Purchaser in a commercially reasonable manner, at the delivery point (agreed upon by the Seller and the Purchaser for the transaction). 4.16b Retail Entity: A retail aggregator or supplier or retail ------------- customer; provided, however, only those Retail Entities eligible for transmission service under the FERC's pro forma --- ----- open access transmission tariff are eligible to become members of the WSPP. 4.16c Sales Price: The price at which the Seller, acting in a ----------- commercially reasonable manner, effects a resale of the electric energy not received by the Purchaser or, absent such a resale, the market price for such quantity of electric energy at the delivery point (agreed upon by the Seller and the Purchaser), as determined by the Seller in a commercially reasonable manner. 4.17 Seller: Any Party which agrees to sell or provide to one or ------ more of the other Parties any service pursuant to the Agreement under any Service Schedule and any applicable Confirmation Agreement. 4.18 Service Schedule: A schedule of services established pursuant ---------------- to Section 6 of this Agreement. 4.19 Uncontrollable Forces: As defined in Section 10 of this ---------------------- Agreement or in a Confirmation Agreement. Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 10A Rate Schedule FERC No. 6 |
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 11 Rate Schedule FERC No. 6 accordance with the Agreement, including Service Schedule B, and any applicable Confirmation Agreement. 4.20a WSPP: The Western Systems Power Pool. ---- 4.20b WSPP Default Transmission Tariff: The transmission tariff -------------------------------- filed on behalf of WSPP Members with FERC as it may be amended from time to time. |
5. TERM AND TERMINATION:
5.1 This Agreement shall become effective as of July 27, 1991 when
acceptance or approvals required under Section 13.2 of this
Agreement with respect to those Parties that are subject to
FERC jurisdiction have been obtained; provided, however, that
this Agreement shall not become effective as to any Party in
the event the pre-grant of termination requested under Section
13.3 is not allowed by FERC, absent that Party's consent; and
provided, further, that this Agreement shall not become
effective as to any Party if any terms, conditions or
requirements imposed by FERC are found unacceptable by that
Party. This Agreement shall continue in effect for a period of
ten (10) years from said effective date and thereafter on a
year to year basis until terminated by the Parties; provided,
however, that any Party may withdraw its participation at any
time after the effective date of this Agreement on thirty (30)
days prior written notice to all other Parties.
5.2 As of the effective date of any withdrawal, the withdrawing
Party shall have no further rights or obligations under this
Agreement except the right to collect
Western Systems Power Pool Original Sheet No. 12 Rate Schedule FERC No. 6
money or receive service owed to it for transactions under any
Service Schedule and the obligation to pay such amounts due to
another Party and to complete any transactions agreed to under
any Service Schedule as of said date. No Party shall oppose,
before any court or regulatory agencies having jurisdiction,
any other Party's withdrawal as provided in this Section.
5.3 Except as provided for in Section 5.2, after termination, or
withdrawal with respect to the withdrawing Party, all rights
to services provided under this Agreement or any tariff or
rate schedule which results from or incorporates this
Agreement shall cease, and no Party shall claim or assert any
continuing right to such services under this Agreement. Except
as provided for in Section 5.2, no Party shall be required to
provide services based in whole or in part on the existence of
this Agreement or on the provision of services under this
Agreement beyond the termination date, or date of withdrawal
with respect to the withdrawing Party.
6. SERVICE SCHEDULES AND WSPP DEFAULT TRANSMISSION TARIFF:
6.1 The Parties contemplate that they may, from time to time, add or remove Service Schedules under this Agreement. The attached Service Schedules A through C for Economy Energy Service, Unit Commitment Service, and Firm System Capacity/Energy Sale or Exchange Service are hereby approved and made a part of this Agreement. Nothing contained herein shall be construed as affecting in any way the right of the Parties to jointly make application to FERC for a change
Western Systems Power Pool Original Sheet No. 13 Rate Schedule FERC No. 6
in the rates and charges, classification, service, terms, or
conditions affecting WSPP transactions under Section 205 of
the Federal Power Act and pursuant to FERC rules and
regulations promulgated thereunder. Subject to the provisions
of Section 13, future Service Schedules, if any, shall be
adopted only by amendment of this Agreement and shall be
attached hereto and become a part of this Agreement.
6.2 [RESERVED]
6.3 When the WSPP Default Transmission Tariff applies as specified
in the preamble to such Default Transmission Tariff,
Transmission Service under it shall be available both to
Parties and nonParties under this Agreement; provided,
however, each Party or nonParty must be an eligible customer
under the WSPP Default Transmission Tariff in order to receive
service.
7. HUB AND OPERATING AGENT:
7.1 The Operating Agent shall act for itself and as agent for the
Parties to carry out its designated responsibilities under
this Agreement.
7.2 The Operating Agent shall, as directed by the Operating
Committee pursuant to Section 8.2.4, and on behalf of the
Parties, either (i) purchase or lease, and install or have
installed, operate and maintain the necessary equipment to
operate the Hub or (ii) contract for Hub services.
Western Systems Power Pool Original Sheet No. 14 Rate Schedule FERC No. 6
7.3 The Operating Agent's estimated total costs to be incurred
under Section 7.2 shall be subject to review by the Operating
Committee and approval by the Executive Committee.
7.4 At least sixty (60) days prior to each calendar year that this
Agreement is in effect, the Operating Agent shall prepare a
budget for said year of operation under this Agreement and
shall submit same to the Operating Committee for review, and
to the Executive Committee for approval. Subsequent budget
revisions shall be submitted to the Operating Committee for
review and to the Executive Committee for approval.
7.5 The Operating Agent shall perform other administrative tasks
necessary to implement this Agreement as directed by the
Executive Committee.
7.6 Except as provided in Section 7.7, all Parties shall share
equally in all costs of the Operating Agent incurred under
this Agreement, including but not limited to initial FERC
filing fees and any reasonable legal fees.
7.7 Each Party, in coordination with the Operating Agent, shall at
its own expense acquire, install, operate, and maintain all
necessary software and hardware on its system and the
necessary communications link to the Hub to conduct
transactions under this Agreement.
7.8 The Operating Agent shall bill the Parties for costs incurred
under this Agreement on an estimated basis reasonably in
advance of when due, and such billings shall be paid by the
Parties when due. Such billings shall be adjusted in the
following
Western Systems Power Pool Original Sheet No. 15 Rate Schedule FERC No. 6
month(s) to reflect recorded costs. Billing and payment of the
Operating Agent's costs shall otherwise be implemented in
accordance with the provisions of Section 9.
7.9 The Operating Agent, at reasonable times and places, shall
make available its records and documentation supporting costs
for bills rendered under this Agreement for the inspection of
any Party for a period of time not to exceed two (2) years
from the time such bills were rendered.
7.9.1 A Party requesting review of the Operating Agent's records shall give the Operating Agent sufficient notice of its intent, but in no event less than thirty (30) days. 7.9.2 The requesting Party may perform this review using personnel from its own staff or designate a certified public accounting firm for the purpose of this review. 7.9.3 All costs incurred to perform this review shall be at the requesting Party's own expense. 7.9.4 The Party performing the review shall not voluntarily release the Operating Agent's records or disclose any information contained therein to any third party unless the written consent of the Operating Agent and the Executive Committee has been obtained. |
7.10 Upon the termination of this Agreement, unless otherwise directed by the Executive Committee, the Operating Agent shall either dispose of any Hub
Western Systems Power Pool Original Sheet No. 16 Rate Schedule FERC No. 6
equipment which it has purchased, or have the right of first
refusal to purchase such equipment at original cost less
depreciation, and shall apply any net proceeds from the sale
of the Hub equipment against its costs incurred under this
Agreement. The Operating Agent shall refund any excess
proceeds equally to the Parties.
8. ORGANIZATION AND ADMINISTRATION:
As a means of securing effective and timely cooperation within
the activities hereunder and as a means of dealing on a prompt and
orderly basis with various problems which may arise in connection with
system coordination and operation under changing conditions, the
Parties hereby establish an Executive Committee and an Operating
Committee.
8.1 Executive Committee:
The Executive Committee shall consist of one
representative and an alternate from each Party designated
pursuant to Section 8.5 herein. The responsibilities of the
Executive Committee are as follows:
8.1.1 To establish sub-committees as it may from time to time deem necessary. 8.1.2 To review at least annually the service activities hereunder to ensure that such activities are consistent with the spirit and intent of this Agreement. 8.1.3 To review any unresolved issues which may arise hereunder and endeavor to resolve the issues. |
Western Systems Power Pool Original Sheet No. 17 Rate Schedule FERC No. 6 8.1.4 To review and approve the Operating Agent's annual budget under this Agreement, and any revision thereto, within thirty (30) days of recommendation by the Operating Committee. 8.1.5 To establish and approve any additional budgets under this Agreement as may be deemed necessary. 8.1.6 To review and recommend to the Parties for approval any additions or amendments to this Agreement, including Service Schedules. 8.1.7 To review and act on the application of an entity to become a Party to this Agreement. 8.1.8 To designate a successor to the Operating Agent, if necessary. 8.1.9 To do such other things and carry out such duties as specifically required or authorized by this Agreement; provided, however, that the Executive Committee shall have no authority to amend this Agreement. 8.1.10 To notify any Party of the rescission of its interest in this Agreement due to its failure to continue to meet the requirements of Section 16.1. 8.1.11 To arrange for legal representation for filing this Agreement (and any subsequent amendments) with FERC and supporting the Agreement (or amendments) in any FERC proceeding, and for other purposes as required. |
8.2 Operating Committee:
Western Systems Power Pool Original Sheet No. 18 Rate Schedule FERC No. 6 The Operating Committee shall consist of one |
representative and an alternate from each Party designated pursuant to Section 8.5. The responsibilities of the Operating Committee are as follows:
8.2.1 To establish, review, approve, or modify procedures and standard practices, consistent with the provisions hereof, for the guidance of load dispatchers and other operating employees in the Parties' electric systems as to matters affecting transactions under this Agreement. 8.2.2 To submit to the Executive Committee any proposed new or revised Service Schedules. 8.2.3 To establish, review, approve, or modify any scheduling or operating procedures required in connection with transactions under this Agreement. 8.2.4 To direct the Operating Agent in matters governed by this Agreement. 8.2.5 To review and make recommendations to the Executive Committee for approval of the Operating Agent's annual budget under this Agreement, including any proposed revisions thereto, within thirty (30) days of receipt from the Operating Agent. 8.2.6 To review and recommend as necessary the types and arrangement of equipment for intersystem communication facilities to enhance transactions and benefits under this Agreement. 8.2.7 To review the Operating Agent's estimated total costs of providing, having provided or contracting for a Hub. |
Western Systems Power Pool Original Sheet No. 19 Rate Schedule FERC No. 6 8.2.8 To review new member applications for membership to this Agreement and make recommendations on said applications to the Executive Committee. 8.2.9 To do such other things and carry out such duties as specifically required or authorized by this Agreement or as directed by the Executive Committee; provided, however, that the Operating Committee shall have no authority to amend this Agreement. |
8.3 All matters which require Operating Committee or Executive
Committee approval as provided in this Agreement shall be by
no less than ninety percent (90%) affirmative agreement of the
committee members present.
8.4 Unless otherwise agreed by all committee members, the
chairperson of each committee shall provide the other Parties
at least ten (10) Business Days advance notification of all
committee meetings, including an agenda of matters to be
discussed and voted on at the meeting. All material issues to
be submitted to a vote of the committee shall appear on the
agenda. Prior to the selection of a chairperson the Operating
Agent shall provide such advance notice for the initial
meeting of each committee.
8.5 Each Party shall give written notice to the other Parties of
the name of its designated representative and alternate
representative (to act in the absence of the designated
representative) on each committee within thirty (30) days
after the execution of this Agreement. Notice of any change of
representative or alternate
Western Systems Power Pool First Revised Sheet No. 20 Rate Schedule FERC No. 6 Superseding Original Sheet No. 20
representative shall be given by written notice to the other
Parties. Each Party's designated representative shall be
authorized to act on its behalf with respect to those
committee responsibilities provided herein.
8.6 Each committee shall meet as necessary or at the request of
any Party.
8.7 Each committee shall elect a chairperson and other officers at
its first meeting.
9. PAYMENTS:
9.1 The accounting and billing period for transactions under
Service Schedules to this Agreement shall be one (1) calendar
month, unless otherwise specified in a Service Schedule agreed
to through a Confirmation Agreement. Bills sent to any Party
shall be sent to the appropriate billing address as set forth
on the WSPP homepage or as otherwise specified by such Party.
9.2 Payments for amounts billed under Service Schedules hereto
shall be paid so that such payments are received by the Party
to be paid on the 20th day of the invoicing month or the tenth
(10) day after receipt of the bill, whichever is later.
Notwithstanding the foregoing, Premiums shall be paid within
three (3) Business Days of receipt of the invoice therefor.
Payment shall be made at the location designated by the Party
to which payment is due. Payment shall be considered received
when payment is received by the Party to which Payment is due
at the location designated by that Party. If the due date
falls on a non-Business Day of either Party, then the payment
shall be due on the next following Business Day.
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 20A Rate Schedule FERC No. 6 |
9.3 Amounts not paid on or before the due date shall be payable with interest accrued at the rate of one percent (1%) per month, or the maximum interest rate permitted
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool First Revised Sheet No. 21 |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 21
by law, if any, whichever is less, prorated by days from the
due date to the date of payment unless and until the Executive
Committee shall determine another rate.
9.4 In case any portion of any bill is in dispute, the entire bill
shall be paid when due. Any excess amount of bills which,
through inadvertent errors or as a result of a dispute, may
have been overpaid shall be returned by the owing Party upon
determination of the correct amount, with interest accrued at
the rate of one percent (1%) per month, or the maximum
interest rate permitted by law, if any, whichever is less,
prorated by days from the date of overpayment to the date of
refund unless and until the Executive Committee shall
determine another rate. The Parties shall have no rights to
dispute the accuracy of any bill or payment after a period of
two (2) years from the date on which the first bill was
delivered for a specific transaction.
9.5 If a Party's records reveal that a bill was not delivered for
a specific transaction, then the Party may deliver to the
appropriate Party a bill within two (2) years from the date on
which the bill would have been delivered under Section 9.1 of
this Agreement. The right to payment is waived with respect to
transactions, or portions thereof, not billed within such two
(2) year period.
9.6 Each Party, or any third party representative of a Party,
shall keep complete and accurate records, and shall maintain
such data as may be necessary for the purpose of ascertaining
the accuracy of all relevant data, estimates, or statements
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 21A Rate Schedule FERC No. 6 |
of charges submitted hereunder for a period of two (2) years from the date the first bill was delivered for a specific transaction completed under this Agreement.
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool First Revised Sheet No. 22 |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 22
Within a two (2) year period from the date the first bill was
delivered under this Agreement, any Party to that transaction
may request in writing copies of the records of the other
Party for that transaction to the extent reasonably necessary
to verify the accuracy of any statement or charge. The Party
from which documents or data has been requested shall
cooperate in providing the documents and data within a
reasonable time period.
10. UNCONTROLLABLE FORCES:
No Party shall be considered to be in breach of this Agreement
or any applicable Confirmation Agreement to the extent that a failure
to perform its obligations under this Agreement or any such
Confirmation Agreement shall be due to an Uncontrollable Force. The
term "Uncontrollable Force" means an event or circumstance which
prevents one Party from performing its obligations under one or more
transactions, which event or circumstance is not within the reasonable
control of, or the result of the negligence of the claiming Party, and
which by the exercise of due diligence, the claiming Party is unable to
avoid, cause to be avoided, or overcome. "Uncontrollable Forces" may
include and are not restricted to flood, drought, earthquake, storm,
fire, lightning, epidemic, war, riot, civil disturbance or
disobedience, labor dispute, labor or material shortage, sabotage,
restraint by court order or public authority, and action or nonaction
by, or failure to obtain the necessary authorizations or approvals
from, any governmental agency or authority
Western Systems Power Pool Original Sheet No. 22A Rate Schedule FERC No. 6
The following shall not be considered "Uncontrollable Forces": (i) the price of electricity faced by Seller; or (ii) Purchaser's inability due to price to use or resell the power purchased hereunder. No Party shall, however, be relieved of liability for failure of performance to the extent that such failure is due to causes arising out of its own negligence or due to removable or remediable causes which it fails to remove or remedy within a reasonable time period. Nothing contained herein shall be construed to require a
Western Systems Power Pool First Revised Sheet No. 23 Rate Schedule FERC No. 6 Superseding Original Sheet No. 23
Party to settle any strike or labor dispute in which it may be
involved. Any Party rendered unable to fulfill any of its obligations
by reason of an Uncontrollable Force shall give prompt notice of such
fact and shall exercise due diligence, as provided above, to remove
such inability within a reasonable time period. If oral notice is
provided, it shall be promptly followed by written notice.
Notwithstanding the "due diligence" obligations or obligations
to remove or remedy the causes set forth in the foregoing paragraph
(which do not apply to this paragraph except as specified below), where
the entity providing transmission services for transactions under any
Service Schedule interrupts such transmission service, the interruption
in transmission service shall be considered an Uncontrollable Force
under this Section 10 only in the following two sets of circumstances:
(1) An interruption in transmission service shall be considered an
Uncontrollable Force if (a) the Parties agreed on a
transmission path for that transaction at the time the
transaction under this Agreement was entered into by the
Parties' thereto, (b) firm transmission involving that
transmission path was obtained pursuant to a transmission
tariff or contract to effectuate the transaction under the
applicable Service Schedule, and (c) the entity providing
transmission service curtailed or interrupted such firm
transmission pursuant to the applicable transmission tariff
or contract;
(2) if the Parties did not agree on the transmission path for a transaction at the time the transaction was entered into, an interruption in transmission service shall be
Western Systems Power Pool Original Sheet No. 24 Rate Schedule FERC No. 6
considered an Uncontrollable Force only if (a) the Party
contracting for transmission services shall have made
arrangements with the entity providing transmission service
for firm transmission to effectuate the transaction under the
applicable Service Schedule, (b) the entity providing
transmission service curtailed or interrupted such
transmission service due to an event of Uncontrollable Forces
or provision of like effect, and (c) the Party which
contracted for such firm transmission services could not
obtain alternate energy at the delivery point, alternate
transmission services, or alternate means of delivering energy
after exercising due diligence.
No Party shall be relieved by operation of this Section 10 of
any liability to pay for power delivered to the Purchaser or to make
payments then due or which the Party is obligated to make with respect
to performance which occurred prior to the Uncontrollable Force.
11. WAIVERS:
Any waiver at any time by any Party of its rights with respect
to a default under this Agreement or any Confirmation Agreements, or
any other matter under this Agreement, shall not be deemed a waiver
with respect to any subsequent default of the same or any other matter.
12. NOTICES:
12.1 Except for the oral notice provided for in Section 10 of this
Agreement, any formal notice, demand or request provided for
in this Agreement shall be in
Western Systems Power Pool Original Sheet No. 25 Rate Schedule FERC No. 6
writing and shall be deemed properly served, given or made if
delivered in person, or sent by either registered or certified
mail, postage prepaid, or prepaid telegram or fax or other
means agreed to by the Parties.
12.2 RESERVED
12.3 Notices and requests of a routine nature applicable to
delivery or receipt of power or energy or operation of
facilities shall be given in such manner as the committees
from time to time or the Parties to a transaction shall
prescribe.
13. APPROVALS:
13.1 This Agreement is subject to valid laws, orders, rules and
regulations of duly constituted authorities having
jurisdiction. Nothing contained in this Agreement shall give
FERC jurisdiction over those Parties not otherwise subject to
such jurisdiction or be construed as a grant of jurisdiction
over any Party by any state or federal agency not otherwise
having jurisdiction by law.
13.2 This Agreement, including any Service Schedule hereto, shall
become effective as to any Party when it is accepted for
filing by FERC, without changes or conditions unacceptable to
such Party, for application to the Parties subject to FERC
jurisdiction under the Federal Power Act; provided, however,
that nothing in this Agreement is intended to restrict the
authority of the Bonneville Power Administration (BPA)
pursuant to applicable statutory authority to use its existing
wholesale power and transmission rates or to adopt new rates,
rate schedules, or general rate schedule provisions for
application under this Agreement and obtain
Western Systems Power Pool Original Sheet No. 26 Rate Schedule FERC No. 6
interim or final approval of those rates from FERC pursuant to
Section 7 of the Pacific Northwest Electric Power Planning and
Conservation Act, 16 U.S.C. Sec. 839e, provided such rates do
not exceed the maximum rates in the applicable Service
Schedule and are consistent with the terms and conditions of
said Service Schedule. If, upon filing of this Agreement by
Parties subject to FERC jurisdiction under the Federal Power
Act, FERC orders a hearing to determine whether this Agreement
or a Service Schedule under this Agreement is just and
reasonable under the Federal Power Act, the Agreement or
Service Schedule shall not become effective until the date
when an order issued by FERC, determining this Agreement or
the Service Schedule to be just and reasonable without changes
or new conditions unacceptable to the Parties, is no longer
subject to judicial review. Any changes or conditions imposed
by any agency or court, including FERC ordering a hearing,
shall be cause for immediate withdrawal by any nonconsenting
Party.
13.3 The Parties subject to FERC jurisdiction under the Federal
Power Act shall have the right to terminate their
participation in this Agreement, and any rate schedule or
services included herein, pursuant to the terms of Section 5
of this Agreement and without the necessity of further filing
with or approval by FERC.
13.4 Any amendment or change in maximum rates specified in the
Service Schedules shall not become effective with regard to
any Party that is subject to FERC jurisdiction under the
Federal Power Act until it is accepted for filing or
Western Systems Power Pool Original Sheet No. 27 Rate Schedule FERC No. 6
confirmed and approved by FERC as specified in and subject to
the conditions of Section 13.2.
13.5 Nothing contained in this Agreement shall be construed to
establish any precedent for any other agreement or to grant
any rights to or impose any obligations on any Party beyond
the scope and term of this Agreement.
14. TRANSFER OF INTEREST IN AGREEMENT:
No Party shall voluntarily transfer its membership under this
Agreement without the written consent and approval of all other Parties
except to a successor in operation of the applicable properties of such
Party. With regard to the transfer of the rights and obligations of any
Party associated with transactions under the Service Schedules, neither
Party may assign such rights or obligations unless (a) the other Party
provides its prior written consent which shall not be unreasonably
withheld; or (b) the assignment is to a successor in operation whose
creditworthiness is comparable to or higher than that of the assigning
Party. Any successor or assignee of the rights of any Party, whether by
voluntary transfer, judicial or foreclosure sale or otherwise, shall be
subject to all the provisions and conditions of this Agreement and
Confirmation Agreements (where applicable) to the same extent as though
such successor or assignee were the original Party under this Agreement
or the Confirmation Agreements, and no assignment or transfer of any
rights under this Agreement or any Confirmation Agreement shall be
effective unless and until the assignee or transferee agrees in writing
to assume all of the obligations of the assignor or transferor and to
be bound by all of the provisions and
Western Systems Power Pool First Revised Sheet No. 28 Rate Schedule FERC No. 6 Superseding Original Sheet No. 28
conditions of this Agreement and any Confirmation Agreement (where
applicable). The execution of a mortgage or trust deed or a judicial or
foreclosure sale made thereunder shall not be deemed a voluntary
transfer within the meaning of this Section 14.
15. SEVERABILITY:
In the event that any of the terms, covenants or conditions of
this Agreement or any Confirmation Agreement, or the application of any
such term, covenant or condition, shall be held invalid as to any
person or circumstance by any court, regulatory agency, or other
regulatory body having jurisdiction, all other terms, covenants or
conditions of this Agreement and the Confirmation Agreement and their
application shall not be affected thereby, but shall remain in force
and effect unless a court, regulatory agency, or other regulatory body
holds that the provisions are not separable from all other provisions
of this Agreement or such Confirmation Agreement.
16. MEMBERSHIP:
16.1 Any Electric Utility, Retail Entity or Qualifying Facility may
become a Party to this Agreement. The Executive Committee
shall notify such Electric Utility, Retail Entity or
Qualifying Facility of its decision within sixty (60) days of
a request to become a Party to this Agreement, and any
acceptable entity shall become a Party hereto by the execution
of this Agreement or a counterpart hereof, payment of costs
pursuant to Section 16.4, and concluding any necessary
acceptance or approval referred to in Section 13. Any such
Party, if it is subject to the ratemaking jurisdiction of
FERC,
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 29 Rate Schedule FERC No. 6 |
shall be responsible for any FERC filing necessary for it to
implement its performance under this Agreement.
16.2 Each Party shall continue to meet the requirements of
Section 16.1 in order to remain a Party to this Agreement
16.3 Being a Party to this Agreement shall not serve as a
substitute for contractual arrangements that may be needed
between any Party which operates a Control Area and any other
Party which operates within that Control Area.
16.4 Any entity that becomes a Party to this Agreement which was
not a party to the experimental Western Systems Power Pool
Agreement shall pay a one time fee of $25,000 under this
Agreement in recognition of prior efforts and costs incurred
by the parties to the experimental Western Systems Power Pool
Agreement, which efforts greatly facilitated development of
this Agreement. Such fee shall be credited to future costs of
the Operating Agent incurred hereunder.
17. RELATIONSHIP OF PARTIES:
17.1 Nothing contained herein or in any Confirmation Agreement
shall be construed to create an association, joint venture,
trust, or partnership, or impose a trust or partnership
covenant, obligation, or liability on or with regard to any
one or more of the Parties. Each Party shall be individually
responsible for its own covenants, obligations, and
liabilities under this Agreement and under any applicable
Confirmation Agreement.
Western Systems Power Pool First Revised Sheet No. 30 Rate Schedule FERC No. 6 Superseding Original Sheet No. 30
17.2 All rights of the Parties are several, not joint. No Party
shall be under the control of or shall be deemed to control
another Party. Except as expressly provided in this Agreement,
no Party shall have a right or power to bind another Party
without its express written consent.
18. NO DEDICATION OF FACILITIES:
Any undertaking by one Party to another Party under any
provision of this Agreement shall not constitute the dedication of the
electric system or any portion thereof of the undertaking Party to the
public or to the other Party, and it is understood and agreed that any
such undertaking under any provision of this Agreement by a Party shall
cease upon the termination of such Party's obligations under this
Agreement.
19. NO RETAIL SERVICES:
Nothing contained in this Agreement shall grant any rights to
or obligate any Party to provide any services hereunder directly to or
for retail customers of any Party.
20. THIRD PARTY BENEFICIARIES:
This Agreement shall not be construed to create rights, in, or
to grant remedies to, any third party as a beneficiary of this
Agreement or of any duty, obligation or undertaking established herein
except as provided for in Section 14.
21. LIABILITY AND DAMAGES:
21.1 This Agreement contains express remedies or measures of
damages in Sections 21.3 and 22 for non-performance or
default. THE LIABILITY OF THE NON-PERFORMING OR DEFAULTING
PARTY SHALL BE LIMITED AS SET
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 30A Rate Schedule FERC No. 6 |
FORTH IN SUCH PROVISIONS, AND ALL OTHER DAMAGES OR REMEDIES ARE HEREBY WAIVED. Therefore, except as provided in Sections 21.3 and 22, no Party or its directors, members of its governing bodies, officers or employees shall be liable to any other Party or Parties for any loss or damage to property,
loss of earnings Issued by: Michael E. Small, General Counsel to Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 31 Rate Schedule FERC No. 6 |
or revenues, personal injury, or any other direct, indirect,
or consequential damages or injury, or punitive damages, which
may occur or result from the performance or non-performance of
this Agreement (including any applicable Confirmation
Agreement), including any negligence arising hereunder. Any
liability or damages faced by an officer or employee of a
Federal agency or by that agency that would result from the
operation of this provision shall not be inconsistent with
Federal law.
21.2 [RESERVED]
21.3 The following damages provision shall apply to transactions
under Service Schedules B and C. For transactions under
Service Schedule A, this damages provision or some other
damages provision will apply only if such a damages provision
is agreed to through a Confirmation Agreement. The damages
under this Section 21.3 apply to a Party's failure to deliver
or receive electric power or energy in violation of the terms
of the Agreement and any Confirmation Agreement. The Contract
Quantity and Contract Price referred to in this Section 21.3
are part of the agreement between the Parties for which
damages are being calculated under this Section.
(a) If either Party fails to deliver or receive, as the
case may be, the quantities of electric power or
energy due under the Agreement and any Confirmation
Agreement (thereby becoming a "Non-Performing Party"
for the purposes of this Section 21.3), the other
party (the "Performing
Western Systems Power Pool Original Sheet No. 32 Rate Schedule FERC No. 6 Party") shall be entitled to receive from the Non-Performing Party an amount calculated as follows (unless performance is excused by Uncontrollable Forces as provided in Section 10, the applicable Service Schedule, or by the Performing Party): (1) If the amount the Purchaser scheduled or received in any hour is less than the applicable hourly Contract Quantity, then the Purchaser shall be liable for (a) the product of the amount (whether positive or negative), if any, by which the Contract Price differed from the Sales Price (Contract Price - Sales Price) and the amount by which the quantity received by the Purchaser was less than the hourly Contract Quantity; plus (b) the amount of transmission charge(s), if any, for firm transmission service upstream of the delivery point, which the Seller incurred to achieve the Sales Price, less the reduction, if any, in transmission charge(s) achieved as a result of the reduction in the Purchaser's schedule or receipt of electric energy (based on Seller's reasonable commercial efforts to achieve such reduction). If the total amounts for all hours calculated under this paragraph (1) are negative, then neither the Purchaser nor the Seller shall pay any amount under this Section 21.3(a)(1). |
Western Systems Power Pool Original Sheet No. 33 Rate Schedule FERC No. 6 (2) If the amount the Seller scheduled or delivered in any hour is less than the applicable hourly Contract Quantity, then the Seller shall be liable for (a) the product of the amount (whether positive or negative), if any, by which the Replacement Price differed from the Contract Price (Replacement Price - Contract Price) and the amount by which the quantity delivered by the Seller was less than the hourly Contract Quantity; plus (b) the amount of transmission charge(s), if any, for firm transmission service downstream of the delivery point, which the Purchaser incurred to achieve the Replacement Price, less the reduction, if any, in transmission charge(s) achieved as a result of the reduction in the Seller's schedule or delivery (based on Purchaser's reasonable commercial effort to achieve such reduction). If the total amounts for all hours calculated under this paragraph (2) are negative, then neither the Purchaser nor the Seller shall pay any amount under this Section 21.3(a)(2). (3) The Non-Performing Party shall pay any amount due from it under this section within the billing period as specified in Section 9 of this Agreement or agreed to in the applicable Confirmation Agreement if the Parties agreed to revise the billing period in Section 9. |
Western Systems Power Pool Original Sheet No. 34 Rate Schedule FERC No. 6 (b) The Parties agree that the amounts recoverable under this Section 21.3 are a reasonable estimate of loss and not a penalty, and represent the sole and exclusive remedy for the Performing Party. Such amounts are payable for the loss of bargain and the loss of protection against future risks. (c) Each Party agrees that it has a duty to mitigate damages in a commercially reasonable manner to minimize any damages it may incur as a result of the other Party's performance or non-performance of this Agreement. (d) In the event the Non-Performing Party disputes the calculation of the damages under this Section 21.3, the Non-Performing Party shall pay the full amount of the damages as required by Section 9 of this Agreement to the Performing Party. After informal dispute resolution as required by Section 34.1, any remaining dispute involving the calculation of the damages shall be referred to binding dispute resolution as provided by Section 34.2 of this Agreement. If resolution or agreement results in refunds or the need for refunds to the Non-Performing Party, such refunds shall be calculated in accordance with Section 9.4 of this Agreement. 22. DEFAULT OF TRANSACTIONS UNDER THIS AGREEMENT AND CONFIRMATION |
AGREEMENTS:
22.1 EVENTS OF DEFAULT An "Event of Default" shall mean with respect to a Party ("Defaulting Party"):
Western Systems Power Pool First Revised Sheet No. 35 Rate Schedule FERC No. 6 Superseding Original Sheet No. 35 (a) the failure by the Defaulting Party to make, when due, any payment required pursuant to this Agreement or Confirmation Agreement if such failure is not remedied within two (2) Business Days after written notice of such failure is given to the Defaulting Party by the other Party ("the Non-Defaulting Party"). The Non-Defaulting Party shall provide the notice by facsimile to the designated contact person for the Defaulting Party and also shall send the notice by overnight delivery to such contact person; or (b) the failure by the Defaulting Party to provide clear and good title as required by Section 33.3, or to have made accurate representations and warranties as required by Section 37 and such failure is not cured within five (5) Business Days after written notice thereof to the Defaulting Party; or (c) The institution, with respect to the Defaulting Party, by the Defaulting Party or by another person or entity of a bankruptcy, reorganization, moratorium, liquidation or similar insolvency proceeding or other relief under any bankruptcy or insolvency law affecting creditor's rights or a petition is presented or instituted for its winding-up or liquidation; or (d) The failure by the Defaulting Party to provide adequate assurances of its ability to perform all of its outstanding material obligations to the Non-Defaulting Party under the Agreement or Confirmation Agreement |
Western Systems Power Pool First Revised Sheet No. 36 Rate Schedule FERC No. 6 Superseding Original Sheet No. 36 pursuant to Section 27 of this Agreement or any substitute or modified provision in the Confirmation Agreement. (e) With respect to its Guarantor, if any: (i) if a material representation or warranty made by a Guarantor in connection with this Agreement, or any transaction entered into hereunder, is false or misleading in any material respect when made or when deemed made or repeated; or (ii) the failure of a Guarantor to make any payment required or to perform any other material covenant or obligation in any guarantee made in connection with this Agreement, including any transaction entered into hereunder, and such failure shall not be remedied within three (3) Business Days after written notice; or (iii) a Guarantor becomes Bankrupt; (iv) the failure, without written consent of the other Party, of a Guarantor's guarantee to be in full force and effect for purposes of this Agreement (other than in accordance with its terms) prior to the satisfaction of all obligations of such Party under each transaction to which such guarantee shall relate; or (v) a Guarantor shall repudiate, disaffirm, disclaim, or reject, in whole or in part, or challenge the validity of, any guarantee. Issued by: Michael E. Small, General Counsel Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 36A Rate Schedule FERC No. 6 |
22.2 REMEDIES FOR EVENTS OF DEFAULT
If an Event of Default occurs, the Non-Defaulting
Party shall possess the right to terminate all transactions
between the Parties under this Agreement upon written notice
(by facsimile or other reasonable means) to the Defaulting
Party, such notice of termination to be effective immediately
upon receipt. If the Non-Defaulting Party fails to exercise
this right of termination within thirty (30) days following
the time when the Event of Default becomes known (or more than
thirty days if the Non-Defaulting and Defaulting Parties agree
to an extension), then such right of termination shall no
longer be available to the Non-Defaulting Party as a remedy
for the Event(s) of Default. The Non-Defaulting Party
terminating transaction(s) under this Section 22.2 may do so
without making a filing at FERC.
Upon termination, the Non-Defaulting Party shall
liquidate all transactions as soon as practicable, provided
that in no event will the Non-Defaulting Party be allowed to
liquidate Service Schedule A transactions. The payment
associated with termination ("Termination Payment") shall be
calculated in accordance with this Section 22.2 and Section
22.3. The Termination Payment shall be the sole and exclusive
remedy for the Non-Defaulting Party for each terminated
transaction ("Terminated Transaction") for the time period
beginning at the time notice of termination under this Section
22 is received. Prior to receipt Issued by: Michael E. Small, General Counsel Effective: July 1, 2001 Western Systems Power Pool Issued on: May 2, 2001 |
Western Systems Power Pool Original Sheet No. 37 Rate Schedule FERC No. 6 |
of such notice of termination by the Defaulting Party, the
Non-Defaulting Party may exercise any remedies available to it
under Section 21.3 of this Agreement or Confirmation
Agreement(s), and any other remedies available to it at law or
otherwise.
Upon termination, the Non-Defaulting Party may
withhold any payments it owes the Defaulting Party for any
obligations incurred prior to termination under this Agreement
or Confirmation Agreement(s) until the Defaulting Party pays
the Termination Payment to the Non-Defaulting Party. The
Non-Defaulting Party shall possess the right to set-off the
amount due it under this Section 22 by any such payments due
the Defaulting Party as provided in Section 22.3(d).
22.3 LIQUIDATION CALCULATION OPTIONS
The Non-Defaulting Party shall calculate the
Termination Payment as follows:
(a) The Gains and Losses shall be determined by
comparing the value of the remaining term,
transaction quantities, and transaction prices under
each Terminated Transaction had it not been
terminated to the equivalent quantities and relevant
market prices for the remaining term either quoted by
a bona fide third-party offer or which are reasonably
expected to be available in the market under a
replacement contract for each Terminated Transaction.
To ascertain the market prices of a replacement
contract, the Non-Defaulting Party may consider,
among other valuations, quotations
Western Systems Power Pool Original Sheet No. 38 Rate Schedule FERC No. 6 from leading dealers in energy contracts, any or all of the settlement prices of the NYMEX power futures contracts (or NYMEX power options contracts in the case of Physically-Settled Options) and other bona fide third party offers, all adjusted for the length of the remaining term and differences in transmission. It is expressly agreed that the Non-Defaulting Party shall not be required to enter into replacement transactions in order to determine the Termination Payment. (b) The Gains and Losses calculated under paragraph (a) shall be discounted to present value using the Present Value Rate as of the time of termination (to take account to the period between the time notice of termination was effective and when such amount would have otherwise been due pursuant to the relevant transaction). The "Present Value Rate" shall mean the sum of 0.50% plus the yield reported on page "USD" of the Bloomberg Financial Markets Services Screen (or, if not available, any other nationally recognized trading screen reporting on-line intraday trading in United States government securities) at 11:00 a.m. (New York City, New York time) for the United States government securities having a maturity that matches the average remaining term of the Terminated Transactions; and (c) The Non-Defaulting Party shall set off or aggregate, as appropriate, the Gains and Losses (as calculated in Section 22.3(a)) and Costs and notify |
Western Systems Power Pool Original Sheet No. 39 Rate Schedule FERC No. 6 the Defaulting Party. If the Non-Defaulting Party's aggregate Losses and Costs exceed its aggregate Gains, the Defaulting Party shall, within three (3) Business Days of receipt of such notice, pay the Termination Payment to the Non-Defaulting Party, which amount shall bear interest at the Present Value rate from the time notice of termination was received until paid. If the Non-Defaulting Party's aggregate Gains exceed its aggregate Losses and Costs, the Non-Defaulting Party, after any set-off as provided in paragraph (d), shall pay the remaining amount to the Defaulting Party within three (3) Business Days of the date notice of termination was received including interest at the Present Value from the time notice of termination was received until the Defaulting Party receives payment. (d) The Non-Defaulting Party shall aggregate or set off, as appropriate, at its election, any or all other amounts owing between the Parties (discounted at the Present Value Rate) under this Agreement and any Confirmation Agreements against the Termination Payment so that all such amounts are aggregated and/or netted to a single liquidated amount. The net amount due from any such liquidation shall be paid within three (3) Business Days following the date notice of termination is received. If the Defaulting Party disagrees with the |
calculation of the Termination Payment and the Parties cannot otherwise resolve their differences, the calculation issue shall be submitted to informal dispute resolution as provided in Section 34.1
Western Systems Power Pool Original Sheet No. 40 Rate Schedule FERC No. 6
of this Agreement and thereafter binding dispute resolution
pursuant to Section 34.2 if the informal dispute resolution
does not succeed in resolving the dispute. Pending resolution
of the dispute, the Defaulting Party shall pay the full amount
of the Termination Payment calculated by the Non-Defaulting
Party within three (3) Business Days of receipt of notice as
set forth in Section 33.2(c) subject to the Non-Defaulting
Party refunding, with interest, pursuant to Section 9.4, any
amounts determined to have been overpaid.
For purposes of this Section 22.3:
(i) "Gains" means the economic benefit (exclusive of
Costs), if any, resulting from the termination of the
Terminated Transactions, determined in a commercially
reasonable manner as calculated in accordance with
this Section 22.3;
(ii) "Losses" means the economic loss (exclusive of
Costs), if any, resulting from the termination of the
Terminated Transactions, determined in a commercially
reasonable manner as calculated in accordance with
this Section 22.3;
(iii) "Costs" means brokerage fees, commissions and other
similar transaction costs and expenses reasonably
incurred in terminating any specifically related
arrangements which replace a Terminated Transaction,
transmission and ancillary service costs associated
with Terminated Transactions, and reasonable
attorneys' fees, if any, incurred in connection
Western Systems Power Pool Original Sheet No. 41 Rate Schedule FERC No. 6 with the Non-Defaulting Party enforcing its rights with regard to the Terminated Transactions. The Non-Defaulting Party shall use reasonable efforts to mitigate or eliminate these Costs. (iv) In no event, however, shall a Party's Gains, Losses or Costs include any penalties or similar charges imposed by the Non-Defaulting Party. 22A. DEFAULT IN PAYMENT OF WSPP OPERATING COSTS: 22A.1 A Party shall be deemed to be in default in payment of its share of WSPP operating costs pursuant to Section 7 of this Agreement, if any, when payment is not received within ten (10) days after receipt of written notice. A default by any Party in such payment obligations shall be cured by payment of all overdue amounts together with interest accrued at the rate of one percent (1%) per month, or the maximum interest rate permitted by law, if any, whichever is less, prorated by days from the due date to the date the payment curing the default is made unless and until the Executive Committee shall determine another rate. 22A.2 A defaulting Party, which is in default under Section 22.A1, shall be liable for all costs, including costs of collection and reasonable attorney fees, plus interest as provided in Section 22.A1 hereof. 22A.3 The rights under this Agreement of a Party which is in default of its obligation to pay operating costs under this Agreement for a period of three (3) months or more may be revoked by a vote of the non-defaulting |
Western Systems Power Pool Original Sheet No. 42 Rate Schedule FERC No. 6 Parties' representatives on the Executive Committee consistent with Section 8.3. The defaulting Party's rights shall not be revoked, however, unless said Party has received at least thirty (30) days written notice of the non-defaulting Parties' intent to revoke such rights. Said notice shall state the date on which the revocation of rights shall become effective if the default is not cured and shall state all actions which must be taken or amounts which must be paid to cure the default. This provision allowing the non-defaulting Parties to revoke such rights is in addition to any other remedies provided in this Agreement or at law and shall in no way limit the non-defaulting Parties' ability to seek judicial enforcement of the defaulting Party's obligations to pay its share of the operating costs under this Agreement. Upon the effective date of such revocation of rights, the defaulting party shall not be allowed to enter into any new transactions under this Agreement. The defaulting party under the Agreement or any Confirmation Agreements shall be required to carry out all obligations that existed prior to the effective date of such revocation. If a defaulting Party's rights under this Agreement have been revoked, the Executive Committee may restore that Party's rights upon the defaulting Party paying all amounts due and owing under this Agreement. 22A.4 Upon revocation of the rights of a defaulting Party under this Agreement, Operating Agent costs hereunder shall be equally shared among the |
Western Systems Power Pool Original Sheet No. 43 Rate Schedule FERC No. 6 remaining Parties. Cost allocation adjustments |
shall be retroactive to the date of the default.
23. OTHER AGREEMENTS:
No provision of this Agreement shall preclude any Party from
entering into other agreements or conducting transactions under
existing agreements with other Parties or third parties. This Agreement
shall not be deemed to modify or change any rights or obligations under
any prior contracts or agreements between or among any of the Parties.
24. GOVERNING LAW:
This Agreement and any Confirmation Agreement shall be
governed by and construed in accordance with the laws of the State of
Utah, without regard to the conflicts of laws rules thereof. The
foregoing notwithstanding, (1) if both the Seller and Purchaser are
organized under the laws of Canada, then the laws of the province of
the Seller shall govern, or (2) if the Seller is an agency of or part
of the United States Government, then the laws of the United States of
America shall govern.
25. JUDGMENTS AND DETERMINATIONS:
Whenever it is provided in this Agreement that a Party shall
be the sole judge of whether, to what extent, or under what conditions
it will provide a given service, its exercise of its judgment shall be
final and not subject to challenge. Whenever it is provided that (i) a
service under a given transaction may be curtailed under certain
conditions or circumstances, the existence of which are determined by
or in the judgment of a Party, or (ii) the existence of qualifications
for membership shall be determined by
Western Systems Power Pool Original Sheet No. 44 Rate Schedule FERC No. 6
the Executive Committee pursuant to Section 16, that Party's or the
Executive Committee's determination or exercise of judgment shall be
final and not subject to challenge if it is made in good faith and not
made arbitrarily or capriciously.
26. COMPLETE AGREEMENT:
This Agreement and any subsequent amendments, including the
Service Schedules and Exhibits incorporated herein, and any
Confirmation Agreement, shall constitute the full and complete
agreement of the Parties with respect to the subject matter hereof, and
all prior or contemporaneous representations, statements, negotiations,
understandings and inducements are fully merged and incorporated in
this Agreement.
27. CREDITWORTHINESS:
Should a Party's creditworthiness, financial responsibility,
or performance viability become unsatisfactory to the other Party in
such other Party's reasonably exercised discretion with regard to any
transaction pursuant to this Agreement and any Confirmation Agreement
(after the transaction is agreed to or begins), the dissatisfied Party
(the "First Party") may require the other Party (the "Second Party") to
provide, at the Second Party's option (but subject to the First Party's
acceptance based upon reasonably exercised discretion), either (1) the
posting of a Letter of Credit, (2) a cash prepayment, (3) the posting
of other acceptable collateral or security by the Second Party, (4) a
Guarantee Agreement executed by a creditworthy entity; or (5) some
other mutually agreeable method of satisfying the First Party. The
Second Party's obligations under this Section 27 shall be limited to a
reasonable estimate of the damages to the First Party
Western Systems Power Pool Original Sheet No. 45 Rate Schedule FERC No. 6
(consistent with Section 21.3 of this Agreement) if the Second Party
were to fail to perform its obligations. Events which may trigger the
First Party questioning the Second Party's creditworthiness, financial
responsibility, or performance viability include, but are not limited
to, the following:
(1) The First Party has knowledge that the Second Party (or its
Guarantor if applicable) are failing to perform or defaulting
under other contracts.
(2) The Second Party has exceeded any credit or trading limit set
out in the Confirmation Agreement or other agreement between
the Parties.
(3) The Second Party or its Guarantor has debt which is rated as
investment grade and that debt falls below the investment
grade rating by at least one rating agency or is below
investment grade and the rating of that debt is downgraded
further by at least one rating agency.
(4) Other material adverse changes in the Second Party's financial
condition occur.
(5) Substantial changes in market prices which materially and
adversely impact the Second Party's ability to perform under
this Agreement or any Confirmation Agreement occur.
If the Second Party fails to provide such reasonably
satisfactory assurances of its ability to perform a transaction
hereunder within three (3) Business Days of demand therefore, that will
be considered an Event of Default under Section 22 of this Agreement
and the First Party shall have the right to exercise any of the
remedies provided for under
Western Systems Power Pool First Revised Sheet No. 46 Rate Schedule FERC No. 6 Superseding Original Sheet No. 46
that Section 22. Nothing contained in this Section 27 shall affect any
credit agreement or arrangement, if any, between the Parties.
28. NETTING:
28.1 If the Purchaser and the Seller are each required to pay an
amount to each other in the same calendar month for
transactions under this Agreement, then such amounts with
respect to each Party may be aggregated and the Parties may
discharge their obligations to pay through netting of the
respective amounts due, in which case the Party, if any, owing
the greater aggregate amount may pay to the other Party the
difference between the amounts owed. Each Party reserves to
itself all rights, set-offs, counterclaims, and other remedies
and defenses (to the extent not expressly herein waived or
denied) which such Party has or may be entitled to arising
from or out of this Agreement and any applicable Confirmation
Agreements.
28.2 Parties shall net payments (associated with transactions under
this Agreement and Confirmation Agreement) in accordance with
Exhibit A, if such Parties have executed the form attached as
Exhibit A. The Parties obligation to net shall include the
netting of all payments received by the Parties in the same
calendar month. Parties that have executed Exhibit A shall
provide a signed copy of Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 47 |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 47
Exhibit A to a representative of the WSPP and to any Party
that requests a copy and indicate on the WSPP Homepage that
they have so executed Exhibit A (once the WSPP Homepage
possesses the necessary capability). If a Party indicated its
election to net payments on the WSPP Homepage and that Party
desires to withdraw its agreement to net, that Party shall
provide at least 30 days notice on the WSPP Homepage of the
change in its election to net and also shall provide,
concurrent with its withdrawal notice, written notice to all
Parties with which it has ongoing transactions or with which
it has committed to future transactions under the Agreement at
the time of the notice. Any such changes in netting status
shall apply beginning at least 30 days after notice required
by this Section 28.2 is provided and only shall apply to
transactions agreed to beginning on or after the date the
change in netting status becomes effective.
28.3 The Parties may by separate agreement either through a
Confirmation Agreement or some other agreement set out
specific terms relating to the implementation of the netting
in addition to or in lieu of Exhibit A.
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 47A Rate Schedule FERC No. 6 |
29. TAXES:
The Contract Price for all transactions under the Service
Schedules shall include full reimbursement for, and the Seller is
liable for and shall pay, or cause to be paid, or reimburse the
Purchaser for if the Purchaser has paid, all taxes applicable to a
transaction that arise prior to the delivery point. If the Purchaser is
required to remit such tax, the amount shall be deducted from any sums
due to the Seller. The Seller shall indemnify,
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 48 Rate Schedule FERC No. 6 |
defend, and hold harmless the Purchaser from any claims for such taxes.
The Contract Price does not include reimbursement for, and the
Purchaser is liable for and shall pay, cause to be paid, or reimburse
the Seller for if the Seller has paid, all taxes applicable to a
transaction arising at and from the delivery point, including any taxes
imposed or collected by a taxing authority with jurisdiction over the
Purchaser. The Purchaser shall indemnify, defend, and hold harmless the
Seller from any claims for such taxes. Either Party, upon written
request of the other Party, shall provide a certificate of exemption or
other reasonably satisfactory evidence of exemption if either Party is
exempt from taxes, and shall use reasonable efforts to obtain and
cooperate with the other Party in obtaining any exemption from or
reduction of any tax. Taxes are any amounts imposed by a taxing
authority associated with the transaction.
30. CONFIDENTIALITY:
The terms of any transaction under the Service Schedules or
any other information exchanged by the Purchaser and Seller relating to
the transaction shall not be disclosed to any person not employed or
retained by the Purchaser or the Seller or their affiliates, except to
the extent disclosure is (1) required by law, (2) reasonably deemed by
the disclosing Party to be required to be disclosed in connection with
a dispute between or among the Parties, or the defense of any
litigation or dispute, (3) otherwise permitted by consent of the other
Party, which consent shall not be unreasonably withheld, (4) required
to be made in connection with regulatory proceedings (including
proceedings relating to FERC, the United States Securities and Exchange
Commission or any other Issued by: Michael E. Small, General Counsel to Effective: July 1, 2000 Western Systems Power Pool Issued on: September 29, 2000 Filed to comply with order of the Federal Energy Regulatory Commission, |
Western Systems Power Pool Original Sheet No. 49 Rate Schedule FERC No. 6
federal, state or provincial regulatory agency); (5) required to comply
with North American Electric Reliability Organization, regional
reliability council, or successor organization requirements; or (6)
necessary to obtain transmission service. In the event disclosure is
made pursuant to this provision, the Parties shall use reasonable
efforts to minimize the scope of any disclosure and have the recipients
maintain the confidentiality of any documents or confidential
information covered by this provision, including, if appropriate,
seeking a protective order or similar mechanism in connection with any
disclosure. This provision shall not apply to any information that was
or is hereafter in the public domain (except as a result of a breach of
this provision).
31. TRANSMISSION TARIFF:
Pursuant to FERC Order No. 888, issued on April 24, 1996, and
FERC orders where applicable, the WSPP Default Transmission Tariff has
been filed and has become effective. The Parties agree to be bound by
the terms of that Tariff for so long as they are Western Systems Power
Pool members.
32. TRANSACTION SPECIFIC TERMS AND ORAL AGREEMENTS:
32.1 The Parties' agreement to transaction specific terms which
constitute the Confirmation Agreement shall be made by one of
the following methods: (1) provision of pertinent information
through written Confirmation Agreements (see Exhibit C for a
sample); or (2) oral conversation, provided that such oral
conversation is recorded electronically. By mutual agreement
and consistent with and pursuant to the provisions of this
Section 32, the Parties to a transaction under
Issued by: Michael E. Small, General Counsel to Effective: July 1, 2000 Western Systems Power Pool Issued on: September 29, 2000 Filed to comply with order of the Federal Energy Regulatory Commission, |
Western Systems Power Pool Second Revised Sheet No. 50 Rate Schedule FERC No. 6 Superseding First Revised Sheet No. 50
this Agreement may agree to modify any term of this Agreement
which applies to such transaction (but not to provisions
regarding the operation of the WSPP as an organization
including Sections 7 and 8), such agreement to be reflected in
a Confirmation Agreement. Written confirmation shall be
required for all transactions of one week or more. Upon
request of the Purchaser or at the election of the Seller, the
Seller shall provide written confirmation which must be
received by the Purchaser within five Business Days of the
date of the agreement or request. The Purchaser shall have
five Business Days from date of receipt to respond to the
confirmation. If the Purchaser does not respond within that
time period, the Seller's written confirmation shall be
considered as accepted and final except as provided in Section
32.5. If the Seller fails to provide any required written
confirmation within five Business Days, as described above,
then the Purchaser may submit a written confirmation to the
Seller. The Purchaser shall submit such written confirmation
within five Business Days after the deadline for submitting a
written confirmation applicable to the Seller as set forth
above has expired. If the Seller fails to respond to
Purchaser's confirmation within five Business Days, then the
Purchaser's written confirmation shall be considered as
accepted and final except as provided in Section 32.5.
Notwithstanding the foregoing, any failure of the Seller or
the Purchaser to provide written confirmation of the
transaction shall not invalidate any oral agreement of the
Parties. Nor shall any oral agreement of the Parties be
considered invalidated Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 50A |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 50A
before and during the time period the confirmation process is ongoing and no final Confirmation Agreement under these procedures or through mutual agreement has been reached.
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 51 Rate Schedule FERC No. 6 |
32.2 The Parties agree not to contest, or assert any defense with
respect to, the validity or enforceability of any agreement to
the terms concerning a specific transaction(s), on the basis
that documentation of such terms fails to comply with the
requirements of any statute that agreements be written or
signed. Each Party consents to the recording by the other
Party, without any further notice, of telephone conversations
between representatives of the Parties, which contain
agreements to or discussion concerning the terms of a specific
transaction(s). All such recordings may be introduced and
admitted into evidence for the purpose of proving agreements
to terms, and any objection to such introduction or admission
for such purpose is hereby expressly waived. The terms
documented hereunder, whether stated in a written document or
a recording, are intended by the Parties as a final expression
of their agreement with respect to such terms as are included
therein and may not be contradicted by evidence of any prior
agreement, but may be supplemented by course of dealing,
performance, usage of trade and evidence of consistent
additional mutually agreed-upon terms.
32.3 For individual transactions under the Service Schedules, the
Agreement as it may be modified or supplemented by a
Confirmation Agreement shall bind the Parties and govern the
transactions; provided, however, if the Parties to a
transaction do not reach agreement on such modification or
change to a term of the Agreement, or the Confirmation
Agreement is not considered accepted and final pursuant to
Section 32.1, then the term or terms of the Agreement, which
the Parties could not
Western Systems Power Pool First Revised Sheet No. 52 Rate Schedule FERC No. 6 Superseding Original Sheet No. 52
reach agreement to modify or change or which are not
considered modified pursuant to Section 32.1, shall apply to
that transaction. In the event of a conflict between a binding
and effective Confirmation Agreement and this Agreement, the
Confirmation Agreement shall govern.
32.4 The Seller shall not be required to file written confirmations
with FERC except as provided in the Service Schedules.
32.5 When a Confirmation Agreement contains "non-standard
confirmation provisions" which are provisions other than those
set forth in paragraphs (a) 2 (l) of Exhibit C, those
non-standard confirmation provisions shall not be deemed to be
accepted pursuant to Section 32.1 unless agreed to: (i)
orally, with that oral agreement recorded (provided that such
oral agreement option only shall be available for transactions
of less than one week); or (ii) in a writing executed by both
Parties.
32.6 Other Products and Service Levels: The Parties may agree to
use a product/service level defined by a different agreement
(e.g., the California ISO tariff, the ERCOT agreement or the
EEI agreement) for a particular transaction under this
Agreement. Unless the Parties expressly state and agree that
all the terms and conditions of such other agreement will
apply to any such transaction, the transaction shall be
subject to all the terms of this Agreement, except that (1)
all service level/product definitions, (2) force
majeure/uncontrollable force definitions, and (3) other terms
as mutually agreed shall have the meaning
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 52A Rate Schedule FERC No. 6 |
ascribed to them in the different agreement or in the
applicable confirmation notice or agreement.
32.7 Written confirmation pursuant to this Section 32 may be
provided in electronic format so long as the Parties to the
affected transaction or transactions have agreed on the
procedures and format for doing so.
33. PERFORMANCE, TITLE, AND WARRANTIES FOR TRANSACTIONS UNDER SERVICE
SCHEDULES:
33.1 Performance 33.1.1 The Seller shall deliver to the delivery point(s) as agreed to in the applicable Confirmation Agreement and sell to the Purchaser in accordance with the terms of the Agreement and such Confirmation Agreement. 33.1.2 The Purchaser shall receive and purchase the Contract Quantity, as agreed to by the Parties in the applicable Confirmation Agreement, at the delivery point(s) and purchase from the Seller in accordance with the terms of the Agreement and such Confirmation Agreement. |
33.2 Title and Risk of Loss Title to and risk of loss of the electric energy shall pass from the Seller to the Purchaser at the delivery point agreed to in the Confirmation Agreement; provided, however, with regard to federal agencies or parts of the
United States Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 53 Rate Schedule FERC No. 6 |
Government, title to and risk of loss shall pass to Purchaser
to the extent permitted by and consistent with applicable law.
33.3 Warranties
The Seller warrants that it will transfer to the
Purchaser good title to the electric energy sold under the
Agreement and any Confirmation Agreement, free and clear of
all liens, claims, and encumbrances arising or attaching prior
to the delivery point and that Seller's sale is in compliance
with all applicable laws and regulations. THE SELLER HEREBY
DISCLAIMS ALL OTHER WARRANTIES, EXPRESS OR IMPLIED, INCLUDING
ANY WARRANTY OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR
PURPOSE.
34. DISPUTE RESOLUTION:
34.1 INFORMAL DISPUTE RESOLUTION
Before binding dispute resolution or any other form
of litigation may proceed, any dispute between the Parties to
a transaction under this Agreement first shall be referred to
nonbinding mediation. The Parties shall attempt to agree upon
a mediator from a list of ten (10) candidates provided by the
Chairman of the WSPP Operating Committee or his or her
designee. If the Parties are unable to agree, then the
Chairman or the designee shall appoint a mediator for the
dispute. Neither the mediator nor the person involved on
behalf of the WSPP in developing a list of mediators for the
Parties to choose from or in selecting the
Western Systems Power Pool Original Sheet No. 54 Rate Schedule FERC No. 6
mediator (if the Parties are unable to do so) shall possess a
direct or indirect interest in either Party or the subject
matter of the mediation. The WSPP shall establish procedures
for the appointment of mediators and the conduct of mediation
and those procedures shall apply to the mediation.
34.2 BINDING DISPUTE RESOLUTION
The Parties to a dispute may elect binding dispute
resolution using the following process unless binding
arbitration of certain disputes is required under this
Agreement in which event the Parties shall use the process set
forth in this Section 34.2 to resolve such disputes, unless
the Parties otherwise agree:
(a) WSPP Dispute Resolution: A Party to a dispute
(if binding dispute resolution is required) or all
Parties to a dispute (if agreement of the Parties is
required for binding dispute resolution) may
initiate binding dispute resolution under WSPP
procedures by notifying the Chairman of the WSPP
Operating Committee or his or her designee. The
Chairman or his or her designee shall provide the
Parties with a list of ten (10) eligible
arbitrators. Within ten (10) days of receiving the
list, the Parties shall agree on a single arbitrator
from the list to conduct the arbitration, or notify
the Chairman of the Operating Committee or the
designee of their inability to reach agreement. If
notified of the Parties inability to reach
agreement, then the Chairman or the designee shall
choose the arbitrator from the list within five (5)
days. Neither the arbitrator nor the person
Western Systems Power Pool Original Sheet No. 55 Rate Schedule FERC No. 6 involved on behalf of the WSPP in developing a list of arbitrators for the Parties to choose from or in selecting the arbitrator (if the Parties are unable to do so) shall possess a direct or indirect interest in either Party or the subject matter of the arbitration. The Procedures to be used for this arbitration shall follow the arbitration procedures which shall be developed and maintained by the WSPP and the procedures will be generally consistent with the commercial arbitration rules of the American Arbitration Association though not involving the Association. If the Parties agree to binding dispute resolution |
Western Systems Power Pool Original Sheet No. 56 Rate Schedule FERC No. 6 34.3 COSTS |
Each Party shall be responsible for its own costs and
those of its counsel and representatives. The Parties shall
equally divide the costs of the arbitrator or mediator and the
hearing.
34.4 CONFIDENTIALITY
Any arbitration or mediation under this Section 34
shall be conducted on a confidential basis and not disclosed,
including any documents or results which shall be considered
confidential, unless the Parties otherwise agree or such
disclosure is required by law.
35. FORWARD CONTRACTS:
The Parties acknowledge and agree that all transactions under
the Agreement and Confirmation Agreement(s) are forward contracts and
that the Parties are forward contract merchants, as those terms are
used in the United States Bankruptcy Code. The Parties acknowledge and
agree that all of their transactions, together with this Agreement and
the related Confirmation Agreement(s) form a single, integrated
agreement, and agreements and transactions are entered into in reliance
on the fact that the agreements and each transaction form a single
agreement between the Parties.
36. TRADE OPTION EXCEPTION
The Parties intend that any Physically Settled Option under
this Agreement shall qualify under the trade option exception, 17
C.F.R. [sed] 32.4. Accordingly, each Party buying or selling a
Physically Settled Option agrees and warrants that any such option
Western Systems Power Pool Original Sheet No. 57 Rate Schedule FERC No. 6
shall be offered only to a provider, user, or merchant and that the
entities entering into the options are doing so solely for purposes
related to their business.
37. ADDITIONAL REPRESENTATIONS AND WARRANTIES:
Each Party warrants and represents to the other(s) that it
possesses the necessary corporate, governmental and legal authority,
right and power to enter into and agree to the applicable Confirmation
Agreement for a transaction or transactions and to perform each and
every duty imposed, and that the Parties' agreement to buy and sell
power under this Agreement and the Confirmation Agreement represents a
contract. Each Party also warrants and represents to the other(s) that
each of its representatives executing or agreeing through a
Confirmation Agreement to a transaction under this Agreement is
authorized to act on its behalf.
Each Party further warrants and represents that entering into
and performing this Agreement and any applicable Confirmation Agreement
does not violate or conflict with its Charter, By-laws or comparable
constituent document, any law applicable to it, any order or judgment
of any court or other agency of government applicable to it or any
agreement to which it is a party and that this Agreement and applicable
Confirmation Agreement(s), constitute a legal, valid and binding
obligation enforceable against such Party in accordance with the terms
of such agreements.
Each Party also represents that it is solvent and that on each
delivery this representation shall be deemed renewed unless notice to
the contrary is given in writing by the Purchaser to the Seller before
delivery.
Western Systems Power Pool First Revised Sheet No. 58 Rate Schedule FERC No. 6 Superseding Original Sheet No. 58
38. FLOATING PRICES:
38.1 In the event the Parties intend that the price for a
transaction is to be based on an index, exchange or any other
kind of variable reference price (such price being a "Floating
Price"), the Parties shall specify the "Floating Price" to be
used to calculate the amounts in a Confirmation Agreement due
Seller for that transaction.
38.2 Market Disruption. If a Market Disruption Event has occurred
and is continuing during the Determination Period, the
Floating Price for the affected Trading Day shall be
determined as follows. The Parties shall negotiate in good
faith to agree on a Floating Price (or a method for
determining a Floating Price) for the affected Trading Day. If
the Parties have not so agreed on or before the twelfth
Business Day following the first Trading Day on which the
Market Disruption Event occurred or existed, then the Floating
Price shall be determined in good faith by the Parties based
upon (1) quotes from Dealers in energy contracts; and/or (2)
quotes from Brokers in energy contracts. Each Party may obtain
up to a maximum of four quotes which must be provided to the
other Party no later than twenty-two Business Days following
the first Business Day on which the Market Disruption Event
occurred or existed. These quotes shall reflect transacted
prices. The Floating Price for the affected Trading Day shall
equal a simple average of the quotes obtained and provided by
the Parties consistent with the provisions of this Section 38.
Each Party providing quote(s) to the other Party also shall
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 58A Rate Schedule FERC No. 6 |
identify to that other Party the Dealer(s) and/or the
Broker(s) who provided each of the quotes to allow
verification.
"Determination Period" means each calendar month during
the term of the relevant transaction; provided that if the
term of the transaction is less than one calendar month
the Determination Period shall be the term of the
transaction. "Market Disruption Event" means, with respect
to an index, any of the following events (the existence of
which shall be determined in good faith by the Parties):
(a) the failure of the index to announce or publish
information necessary for determining the Floating Price;
(b) the failure of trading to commence or the permanent
discontinuation or material suspension of trading in the
relevant options contract or commodity on the exchange or
market acting as the index; (c) the temporary or permanent
discontinuance or unavailability of the index; (d) the
temporary or permanent closing of any exchange acting as
the index; or (e) a material change in the formula for or
the method of determining the Floating Price.
"Trading Day" means a day in respect of which the relevant
price source published the relevant price or would have
published the relevant price but for the Market Disruption
Event.
38.3 Calculation of Floating Price. For the purposes of the
calculation of a Floating Price, all numbers shall be
rounded to three (3) decimal places. If the fourth (4th)
decimal number is five (5) or greater, then the third (3rd)
decimal number shall be Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 58B Rate Schedule FERC No. 6 |
increased by one (1), and if the fourth (4th) decimal number
is less than five (5), then the third (3rd) decimal number
shall remain unchanged.
39. AMENDMENT:
39.1 This Agreement may be amended upon the submission to FERC and
acceptance by FERC of that amendment. The Parties through the
Executive Committee shall direct the filing of any amendments.
The Parties to this Agreement agree to bound by this Agreement
as it may be amended, provided that the Parties possess the
right to challenge any amendments at FERC and to exercise any
applicable withdrawal rights under this Agreement.
39.2 Unless otherwise stated in the amendment, all amendments shall
apply only to new transactions entered into or agreed to on or
after the effective date of the amendment. Preexisting
agreements and transactions shall operate under the version of
the WSPP Agreement effective at the time of the agreement for
the transaction unless the Parties to a transaction or
transactions mutually agree otherwise.
39.3 An agreement modifying this Agreement or a Confirmation
Agreement for a transaction needs no consideration to be
binding.
40. EXECUTION BY COUNTERPARTS:
This Agreement may be executed in any number of counterparts,
and upon execution by all Parties, each executed counterpart shall have
the same force and effect as Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 59 |
Rate Schedule FERC No. 6 Superseding Original Sheet No. 59
an original instrument and as if all Parties had signed the same
instrument. Any signature page of this Agreement may be detached from
any counterpart of this Agreement without impairing the legal effect of
any signatures thereon, and may be attached to another counterpart of
this Agreement identical in form hereto but having attached to it one
or more signature pages.
41. WITNESS:
IN WITNESS WHEREOF, the Parties have caused this Agreement to
be executed by their duly authorized representative as of the 27th day
of July, 1991 (or as of the date of execution of this Agreement by each
Party's duly authorized representation, in the case of any Party that
becomes a signatory to this Agreement subsequent to July 27, 1991).
By:________________________________
Name:
Title:
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 60 Rate Schedule FERC No. 6 |
EXHIBIT A
NETTING
Each Party that executes this Exhibit A to the Agreement agrees to net
payments for transactions under WSPP Service Schedule A, B, and C with any other
Party or Parties which also have agreed to net payments by executing a copy of
this Exhibit A. The Party executing this Exhibit A shall indicate below when it
desires that its agreement to net becomes effective. A Party agreeing to net
under this Exhibit A shall comply with the provisions of Section 28.2 of the
Agreement. Defined terms used herein are as defined in the WSPP Agreement.
Netting shall be done in accordance with the following provision:
If the Purchaser and Seller are each required to pay an amount
on the payment due date in the same month for transactions
under the Agreement or Confirmation Agreement, then such
amounts with respect to each Party will be aggregated and the
Parties will discharge their obligations to pay through
netting, in which case the Party owing the greater aggregate
amount will pay to the other party the difference between the
amounts owed consistent with the payment times in Section 9.2
of the Agreement, unless the Parties have otherwise agreed to
a different payment time as allowed by the Agreement. Each
Party reserves to itself all rights, set-offs, counterclaims
and other remedies and/or defenses to which it is or may be
entitled, arising from or out of the Agreement. All
outstanding payments between the Parties which are to be
netted pursuant to this Exhibit A for transactions under WSPP
Service Schedule A, B, and C shall be offset against each
other or set off or recouped therefrom.
__________________________________ __________________________ Name of Authorized Representative Effective Date for Netting __________________________________ Name of WSPP Member __________________________________ __________________________ Signature of Authorized Date of Execution Representative |
Western Systems Power Pool Original Sheet No. 61 Rate Schedule FERC No. 6
[WSPP SAMPLE FORM - PARTIES ARE FREE TO USE THIS OR DISREGARD IT.]
EXHIBIT B
FORM OF COUNTERPARTY GUARANTEE AGREEMENT
This Guarantee Agreement (this "Guarantee"), dated, as of [__________], 199[__], is made and entered into by [_____________], a [__________] corporation ("Guarantor").
WITNESSETH:
WHEREAS, Guarantor will directly or indirectly benefit from the Agreements.
NOW THEREFORE, in consideration of the Guaranteed Party agreeing to conduct business with Company, Guarantor hereby covenants and agrees as follows:
Western Systems Power Pool Original Sheet No. 62 Rate Schedule FERC No. 6
exceed the cap in Section 1(b), damages, costs, except that Guarantor shall be required to pay reasonable attorney fees.
(b) The aggregate liability of the Guarantor shall not exceed
[_____] Million U.S. Dollars [___________].
(a) it is a corporation duly organized and validly existing under the laws of the State of [_____________] and has the corporate power and authority to execute, deliver and carry out the terms and provisions of this Guarantee;
(b) no authorization, approval, consent or order of, or registration or filing with, any court or other governmental body having jurisdiction over Guarantor is required on the part of Guarantor for the execution and delivery of this Guarantee; and
(c) this Guarantee constitutes a valid and legally binding agreement of Guarantor enforceable against Guarantor in accordance with its terms, except as the enforceability of this Guarantee may be limited by the effect of any applicable bankruptcy, insolvency, reorganization, moratorium or similar laws affecting creditors' rights generally and by general principles of equity.
Western Systems Power Pool Original Sheet No. 63 Rate Schedule FERC No. 6 |
Except as to applicable statutes of limitation, no delay of the Guaranteed Party in the exercise of, or failure to exercise, any rights hereunder shall operate as a waiver of such rights, a waiver of any other rights or a release of Guarantor from any obligations hereunder.
Guarantor consents to the renewal, compromise, extension, acceleration or other changes in the time of payment of or other changes in the terms of the Obligations, or any part thereof or any changes or modifications to the terms of the Agreements.
Guarantor may terminate this Guarantee by providing written notice of such termination to the Guaranteed Party and upon the effectiveness of such termination, Guarantor shall have no further liability hereunder, except as provided in the last sentence of this paragraph. No such termination shall be effective until fifteen (15) Business Days after receipt by the Guaranteed Party of such termination notice. No such termination shall affect Guarantor's liability with respect to any obligations arising under any transaction entered into prior to the time the termination is effective, which transaction shall remain guaranteed pursuant to the terms of this Guarantee.
Western Systems Power Pool Original Sheet No. 64 Rate Schedule FERC No. 6 To [Name of Guaranteed Party] ____________________________ ______________________________ ______________________________ Attn: _______________________ Fax No.: (___) _______________ To Guarantor: ______________________________ ______________________________ ______________________________ Attn: _______________________ Fax No.: (___) _______________ |
Notice given by personal delivery or mail shall be effective upon actual receipt. Notice given by telegram or telecopier shall be effective upon actual receipt if received during the recipient's normal business hours, or at the beginning of the recipient's next business day after receipt if not received during the recipient's normal business hours. All Notices by telegram or telecopier shall be confirmed promptly after transmission in writing by certified mail or personal delivery. Any party may change any address to which Notice is to be given to it by giving notice as provided above of such change of address.
EXECUTED as of the day and year first above written.
[___________________________] By: ________________________ Name: ______________________ Title: _____________________
Western Systems Power Pool Second Revised Sheet No. 65 Rate Schedule FERC No. 6 Superseding First Revised Sheet No. 65 EXHIBIT C SAMPLE FORM FOR CONFIRMATION |
1. Transaction Specific Agreements
The undersigned Parties agree to sell and purchase electric energy, or a Physically-Settled Option, pursuant to the WSPP Agreement as it is supplemented and modified below:
(a) Seller: __________________________________
(b) Purchaser: __________________________________
(c) Period of Delivery: From __\__\__ To __\__\__
(d) Schedule (Days and Hours): __________________
(e) Delivery Rate:________________________________
(f) Delivery Point(s): __________________________
(g) Type of Service (Check as Applicable)
Service Schedule A _________
Service Schedule B _________
Service Schedule C _________
Physically-Settled Option Service Schedule B ______
Physically-Settled Option Service Schedule C ______
Other products per Section 32.6 _________________
[Describe Product]
(h) Contract Quantity: ________ Total MWhrs.
(i) Contract or Strike Price: _____________________
(j) Transmission Path for the Transaction (If Applicable):
(k) Date of Agreement if different: _____________
(l) Additional Information for Physically-Settled Options
(i) Option Type: Put __________ Call______________
(ii) Option Style: __________
(iii) Exercise Date or Period: __________
(iv) Premium: __________
(v) Premium Payment Date: _________
(vi) Method for providing notice of exercise _____________
(m) Special Terms and Exceptions:
See Attachment A
[Special Terms and Exceptions shall be shown on an Attachment to this
Confirmation.] --------------------------- --------------------------- Name of Trader for Purchaser Name of Trader for Seller Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Original Sheet No. 66 Rate Schedule FERC No. 6 --------------------------- --------------------------- Authorized Signature Authorized Signature for Purchaser for Seller --------------------------- --------------------------- Date Date |
Western Systems Power Pool Original Sheet No. 67 Rate Schedule FERC No. 6
EXHIBIT D
WSPP MEDIATION AND ARBITRATION PROCEDURES
I. MEDIATION
A. Informal Mediation. WSPP members with a dispute or a
potential dispute involving transactions under the WSPP
Agreement may request non-binding, informal mediation by
contacting the WSPP's General Counsel and by providing a
brief explanation in writing of the dispute and the remedy
being sought. All parties to the dispute must request this
Informal Mediation for it to become effective. After this
contact, a telephonic conference call will be arranged among
the affected WSPP members and the WSPP's General Counsel, the
Chairman of the Operating Committee, and/or some other
independent and knowledgeable person requested by the
Chairman of the Operating Committee to participate. The
purpose of the conference call will be to discuss the issues
and to have an independent person or persons state their
views. Best efforts will be made to set up this conference
call within five Business Days after the WSPP's General
Counsel is contacted subject to accommodating the schedules
of all involved. This Informal Mediation shall be considered
as satisfying the Mediation requirements of Section 34.1 of
the WSPP Agreement.
Western Systems Power Pool Original Sheet No. 68 Rate Schedule FERC No. 6
B. Initiating Formal Mediation. A WSPP member which believes
that it possesses a claim against another WSPP member
relating to a WSPP transaction, which is unable to resolve
the dispute through agreement with the other member to the
transaction, and which desires to pursue that claim shall
initiate non-binding formal mediation pursuant to Section
34.1 of the WSPP Agreement. The member initiating such
mediation shall do so by Serving written notice to the
Chairman of the WSPP Operating Committee, the WSPP's General
Counsel, and the other members against which the claim is
directed. Such notice shall state the nature of the dispute,
the remedy sought, and support the claim.
C. Response to Document Initiating Formal Mediation. Within
eight days, the member or members against which the claim is
directed may provide a response to the notice which shall be
Served on the member which initiated the Mediation, the
Chairman of the WSPP's Operating Committee, and the WSPP's
General Counsel.
D. Choosing the Mediator. The Mediator shall be chosen in
accordance with the procedures set forth in Section 34.1 of
the WSPP Agreement. Each Party may suggest persons to be
included on the list of Mediators to be presented to the
Parties provided that these suggested persons shall be
provided to the WSPP Representative together with relevant
personal histories within two Business Days
Western Systems Power Pool Original Sheet No. 69 Rate Schedule FERC No. 6
of the date by which time the list of Mediators is to be sent
out. The WSPP Representative shall allow at least one person
suggested by each Party to be added to the list of Mediators.
A brief personal history of each person on the list of
potential mediators shall be provided to the Parties, with
that history showing the person's employment over the last
five years and any other relevant facts. The WSPP
Representative shall provide the Parties with the list of
Mediators within five days of receipt of notice of the
dispute. The Parties then shall have five days in which to
reach agreement on a Mediator or inform the WSPP
Representative that they were unable to reach agreement in
which event the WSPP Representative shall appoint the Mediator
consistent with Section 34.1 of the WSPP Agreement. Upon
request of the Parties for expedition, the WSPP Representative
shall use best efforts to expedite this process.
E. Location for the Formal Mediation. The Parties shall agree
on a location for the Mediation. If the Parties fail to reach
agreement, then the WSPP Representative shall set the
location which shall be convenient for the Parties and the
Mediator.
F. Time for the Formal Mediation. The Parties shall agree on
the time for the Mediation after consultation with the
Mediator if one has been appointed. If the Parties fail
to reach agreement, then the WSPP Representative shall set
the time
Western Systems Power Pool Original Sheet No. 70 Rate Schedule FERC No. 6
which shall not be more than twenty-one days after the notice
initiating the Mediation is received after consultation with
the Parties and any Mediator.
G. Conduct of the Formal Mediation. The Mediator shall have
the ability to conduct the Mediation in any manner which the
Mediator believes is appropriate to facilitate resolution of
the dispute. Each Party shall have at least one
representative with the authority to settle the dispute
present at the Mediation. The Mediation shall be private and
confidential and the Mediator shall have the authority to
exclude any person not directly involved unless the Parties
agree otherwise in writing. At the Mediation, each Party
shall have the right to make a brief presentation of its case
and to question the other Party. Each Party also may be
represented by counsel.
H. Replacement of the Mediator. If the Mediator resigns,
withdraws or is no longer able to serve, then the Parties
shall have two Business Days in which to agree on a new
Mediator. If the Parties are unable to agree within such time,
the WSPP Representative shall appoint a replacement Mediator
from the list used to select the first Mediator within two
Business Days after being notified that the Parties are unable
to agree. The dates and deadlines in this section may require
modification if the mediator is replaced. Any extensions shall
be as limited as possible.
Western Systems Power Pool Original Sheet No. 71 Rate Schedule FERC No. 6
II. ARBITRATION
A. Initiating Arbitration. A WSPP member which initiates
Arbitration pursuant to Section 34.2 of the WSPP Agreement
shall do so by Serving the Chairman of the WSPP Operating
Committee, the WSPP General Counsel and the members against
which the claim is directed with written notice of its demand
for arbitration. Such notice shall state the nature of the
dispute, the remedy sought, and support the claim.
B. Response. Within ten days of receipt of the notice, any member
or members against which the claim is directed may provide a
response to the notice. Such response must include any
counterclaims which the member believes are appropriate. If a
counterclaim is submitted, then the member which submitted the
notice may respond to the counterclaim within ten days of
receipt. All such responses shall be Served on the Parties,
the Chairman of the WSPP Operating Committee, and the WSPP
General Counsel.
C. Choosing the Arbitrator. The Arbitrator shall be chosen in
accordance with the procedures set forth in Section 34.2 of
the WSPP Agreement. Each Party may suggest persons to be
included on the list of Arbitrators to be presented to the
Parties provided that these suggested persons are provided to
the WSPP Representative together with relevant personal
histories within two business days
Western Systems Power Pool Original Sheet No. 72 Rate Schedule FERC No. 6
of the date by which time the list of Arbitrators is to be
sent out. The WSPP Representative shall allow at least one
person suggested by each Party to be added to the list of
potential Arbitrators. A brief personal history of each person
on the list of potential Arbitrators shall be provided to the
Parties, with that history showing the person's employment
over the last five years and any other relevant facts. The
WSPP Representative shall provide the Parties with the list of
Arbitrator. within seven days of receipt of notice of the
request for Arbitration. The Parties then shall have ten days
in which to reach agreement on the Arbitrator or to inform the
WSPP Representative that they were unable to reach agreement
in which event the WSPP Representative shall appoint the
Arbitrator consistent with Section 34.2 of the Agreement. Upon
request of the Parties for expedition, the WSPP Representative
shall use best efforts to cause this process to be expedited.
D. Location for the Arbitration. The Parties shall agree on a
location for the Arbitration. If the Parties fail to reach
agreement, then the WSPP Representative shall set the
location which shall be convenient for the Parties and the
Arbitrator.
E. Time for the Arbitration. The Parties shall agree on
the time for the Arbitration and coordinate that time
with the Arbitrator if one has been agreed to or
appointed. If the Parties fail to reach agreement, then the
WSPP Representative
Western Systems Power Pool Original Sheet No. 73 Rate Schedule FERC No. 6
shall set the time which shall not be more than 60 days after
the notice is received. The WSPP Representative shall set a
time after consultation with the Parties and the Arbitrator to
check their schedules.
F. Discovery. After appointment of the Arbitrator, each
Party shall be entitled to obtain relevant documents from the
other Parties and to take depositions. Each Party shall
respond to such a document request within seven days of
receipt of the request and make its employees or consultants
available for depositions to the extent that the employee or
consultant possesses knowledge and information relevant to
the dispute. Each Party shall disclose documents that are
confidential or commercially sensitive subject to a
reasonable protective order. Any disputes concerning
discovery shall be promptly referred to the Arbitrator who
shall have authority to resolve such disputes, including the
authority to require attendance of witnesses at depositions.
The Federal Rules of Civil Procedure shall apply to discovery
under these procedures.
G. Conduct of Arbitration if the Parties Agree to Waive an Oral
Hearing. If the Parties agree to waive an oral hearing, then
the Parties shall Serve Initial Briefs no later than 35 days
after the notice is received or notify the Arbitrator that
they do not wish to submit any additional documents. Parties
shall Serve any Reply Briefs no later than ten days after the
date for Service of Initial Briefs.
Western Systems Power Pool Original Sheet No. 74 Rate Schedule FERC No. 6
H. Conduct of the Arbitration Hearing. No later than fifteen
days before any hearing, any Party may Serve an Initial Brief
or notify the Arbitrator that they do not wish to submit any
additional documents. A Party shall Serve any Reply Brief no
later than five Business Days before any hearing. The
Arbitrator shall preside over any hearing and rule on all
objections including objections as to the admissibility of
evidence or whether the questioning is proper. All testimony
shall be submitted under oath. The Arbitrator is not bound
to follow any particular rules governing the conduct of the
proceeding. The Arbitrator may rely on legal advice provided
through the WSPP. The Arbitrator may require any person
employed by a Party to attend and testify at the hearing.
Each Party shall possess the right to present evidence,
including witnesses, and to cross-examine other Parties'
witnesses. The Arbitration shall be private and the
Arbitrator shall have the authority to exclude any person not
directly involved unless the Parties otherwise agree. Each
Party may be represented by counsel. A stenographic record
of the Arbitration shall be kept.
I. Decision. Within ten Business Days after the end of the
Arbitration hearing, the Arbitrator shall issue his award in
writing. If the Parties waived the right to an oral hearing,
then the Arbitrator shall issue the award within ten Business
Days of the last date Briefs were to be submitted. The
Arbitrator is not limited in the
Western Systems Power Pool Original Sheet No. 75 Rate Schedule FERC No. 6
remedies he may order so long as any arbitration award is
consistent with the provisions and limitations of the WSPP
Agreement and any applicable Confirmation Agreement with
respect to the liability and damages of any Party; provided,
however, upon agreement of the Parties to the dispute, the
Arbitrator's choice of remedies may be limited.
J. Replacement of the Arbitrator. If the Arbitrator resigns,
withdraws, or is no longer able to serve then the Parties
shall have two Business Days in which to agree on a new
Arbitrator. If the Parties are unable to agree within such
time, the WSPP Representative shall appoint a replacement
Arbitrator from the list used to select the first Arbitrator
within two Business Days after being notified that the Parties
are unable to agree. The dates and deadlines in this section
may require modification if the mediator is replaced. Any
extensions shall be as limited as possible.
III. MISCELLANEOUS
A. Confidentiality. Any Arbitration or Mediation shall be
confidential as provided in Section 34.4 of the WSPP
Agreement.
B. Costs. Costs shall be borne by Parties as provided in
Section 34.3 of the WSPP Agreement.
Western Systems Power Pool Original Sheet No. 76 Rate Schedule FERC No. 6
C. Restrictions on Lawsuits. Each Party shall be subject to the
restrictions provided in Section 34.2 of the WSPP Agreement.
D. Attorney-Client/Attorney Workproduct. The Arbitrator or
Mediator shall not take any action which would result in
disclosure of information in violation of the
attorney-client privilege or attorney workproduct doctrine.
IV. DEFINITIONS
A. Arbitrator or Arbitration. The Arbitrator appointed
pursuant to these procedures and Section 34.2 of the WSPP
Agreement and the Arbitration pursuant to these
procedures and the WSPP Agreement.
B. Initial or Reply Briefs. Written documents submitted by the
Parties to support their positions and respond to each others
positions. Such documents shall be limited to 25 pages.
C. Business Days. Defined as in the WSPP Agreement.
D. Mediator or Mediation. The Mediator appointed pursuant to
these procedures and Section 34.1 of the WSPP Agreement and
the Mediation pursuant to these procedures and the WSPP
Agreement.
E. Parties. The WSPP members involved in the Mediation or
Arbitration which have a direct interest in the dispute.
Western Systems Power Pool Original Sheet No. 77 Rate Schedule FERC No. 6
F. Service, Serving, or Served. The method of service
shall be by fax, unless impracticable because of the size of
the document. In all events, the document should be
delivered to the Party by overnight mail. Parties also
should attempt to send the document out by email if possible.
Service will be accomplished to a Party if sent to the
Party's contact person for the disputed transaction. If
there are multiple contact persons for one Party, service to
one such person shall suffice. Service shall be to those
individuals or entities specified in this procedures, but
must include service to the Parties, the Mediator or
Arbitrator (if either has been appointed), and to the WSPP
General Counsel.
G. WSPP Representative. The Chairman of the WSPP Operating
Committee or his or her designee for the purposes of the
Arbitration or Mediation.
Western Systems Power Pool Original Sheet No. 78 Rate Schedule FERC No. 6
SERVICE SCHEDULE A ECONOMY ENERGY SERVICE ---------------------- A-1 PARTIES: This Service Schedule is agreed upon as a part of this Agreement by the Parties. A-2 PURPOSE: The purpose of this Service Schedule is to define additional specific procedures, terms and conditions for requesting and providing Economy Energy Service. A-3 TERMS: A-3.1 A Party may schedule Economy Energy Service from another Party by mutual agreement; provided, however, that each Party shall be the sole judge as to the extent to and the conditions under which it is willing to provide or receive such service hereunder consistent with statutory requirements and contractual commitments including the Agreement and any applicable Confirmation Agreement. A-3.2 Scheduling of Economy Energy Service hereunder shall be a responsibility of the Parties involved. A-3.3 Each Seller/Purchaser may prepare a daily estimate of the amount of Economy Energy Service that it is willing and able to sell/buy each hour and the associated hourly sale/purchase price for the next Business Day, plus the weekend and |
Western Systems Power Pool Original Sheet No. 79 Rate Schedule FERC No. 6
holidays, and communicate this information to all other Parties via the Hub. A-3.4 Purchasers shall arrange purchases directly with Sellers, and shall be responsible for transmission arrangements. A-3.5 Unless otherwise mutually agreed between the Purchaser and the Seller, all Economy Energy Service transactions shall be pre-scheduled, and billings shall be based on amounts and prices agreed to in advance by schedulers, subject to Paragraphs A-3.6 and 3.7 and subject to change by mutual agreement between dispatchers or schedulers due to system changes. A-3.6 The price for Economy Energy Service shall be mutually agreed to in advance between Seller and Purchaser and shall not be subject to the rate caps specified in Section A-3.7 in either of the following two circumstances: (1) where the Seller is a FERC regulated public utility and that Seller has been authorized to sell power like that provided for under this Service Schedule at market-based rates; or (2) where the Seller is not a FERC regulated public utility. A Party is a FERC regulated public utility if it is a "public utility" as defined in Section 201(e) of the Federal Power Act, 16 U.S.C. [sect] 824(e). A-3.7 Except as provided for in Section A-3.6, the price shall not exceed the Seller's forecasted Incremental Cost plus up to: $7.32/kW/ month; $1.68/kW/week; |
Western Systems Power Pool Original Sheet No. 80 Rate Schedule FERC No. 6
33.78[cent]/kW/day; 14.07 mills/kWh; or 21.11 mills/kWh for service of sixteen (16) hours or less per day. The hourly rate is capped at the Seller's forecasted Incremental Cost plus 33.78[cent] /kW/ day. The total demand charge revenues in any consecutive seven-day period shall not exceed the product of the weekly rate and the highest demand experienced on any day in the seven-day period. In lieu of payment, such Parties may mutually agree to exchange economy energy at a ratio not to exceed that ratio provided for in Section C-3.7 of Service Schedule C. The Seller's forecasted Incremental Cost discussed above also may include any transmission and/or ancillary service costs associated with the sale, including the cost of any transmission and/or ancillary services that the Seller must take on its own system. Any such transmission and/or ancillary services charges shall be separately identified by the Seller to the Purchaser for transactions under this Schedule including the exchange of economy energy. The transmission and ancillary service rate ceilings shall be available through the WSPP's Hub or homepage. Any such transmission services (and ancillary service provided in conjunction with such transmission service) by Seller shall be provided pursuant to any applicable transmission tariff or agreement, and the rates therefore shall be consistent with such tariff or agreement. A-3.8 Unless otherwise agreed, the Purchaser shall be responsible for maintaining |
Western Systems Power Pool Original Sheet No. 81 Rate Schedule FERC No. 6
operating reserve requirements as back-up for Economy Energy Service purchased and the Seller shall not be required to maintain such operating reserve. A-3.9 Each Party that is a FERC regulated public utility as defined in A-3.6 shall file the Confirmation Agreement with FERC for each transaction under this Service Schedule with a term in excess of one year no later than 30 days after service begins if that Party would have been required to file such Confirmation Agreements or similar agreements with FERC under an applicable FERC accepted market based rate schedule. |
Western Systems Power Pool Original Sheet No. 82 Rate Schedule FERC No. 6 SERVICE SCHEDULE B UNIT COMMITMENT SERVICE ----------------------- B-1 PARTIES: This Service Schedule is agreed upon as part of this Agreement by the Parties. B-2 PURPOSE: The purpose of this Service Schedule is to define additional specific procedures, terms, and conditions for requesting and providing Unit Commitment Service. B-3 TERMS: B-3.1 A Party may schedule Unit Commitment Service from another Party by mutual agreement; provided, however, that each Party shall be the sole judge as to the extent to and the conditions under which it is willing to provide or receive such service hereunder consistent with statutory requirements and contractual commitments including the Agreement and any applicable Confirmation Agreement. Once an agreement is reached, then the obligation for Unit Commitment Service becomes a firm commitment, for both Parties, for the agreed capacity and terms. B-3.2 Unless otherwise mutually agreed by the Parties involved in a Unit Commitment Service transaction, the terms set forth in this Service Schedule B shall govern such transaction. |
Western Systems Power Pool Original Sheet No. 83 Rate Schedule FERC No. 6
B-3.3 Unless otherwise agreed between the Purchaser and the Seller, all transactions shall be prescheduled, subject to any conditions agreed to by schedulers, for a specified unit for a specified period of time. B-3.4 Purchasers shall arrange purchases directly with Sellers. B-3.5 The price for Unit Commitment Service shall be mutually agreed to in advance between Seller and Purchaser and shall not be subject to the rate caps specified in Section B-3.6 in either of the following two circumstances: (1) where the Seller is a FERC regulated public utility and that Seller has been authorized to sell power like that provided for under this Service Schedule at market-based rates; or (2) where the Seller is not a FERC regulated public utility. A Party is a FERC regulated public utility if it is a "public utility" as defined in Section 201(e) of the Federal Power Act, 16 U.S.C. [sect]. 824(e). B-3.6 Except as provided for in Section B-3.5, the price shall not exceed the Seller's forecasted Incremental Cost plus up to: $7.32/kW/month; $1.68/kW/week; 33.78[cent]/kW/day; 14.07 mills/kWh; or 21.11 mills/kWh for service of sixteen (16) hours or less per day. The hourly rate is capped at the Seller's forecasted Incremental Cost plus 33.78[cent]/kW/day. The total demand charge revenues in any consecutive seven-day period shall not exceed the product of the weekly rate and the |
Western Systems Power Pool Original Sheet No. 84 Rate Schedule FERC No. 6
highest demand experienced on any day in the seven-day period. The Seller's forecasted Incremental Cost discussed above also may include any transmission and/or ancillary service costs associated with the sale, including the cost of any transmission and/or ancillary services that the Seller must take on its own system. Any such transmission and/or ancillary service charges shall be separately identified by the Seller to the Purchaser. The transmission and ancillary service rate ceilings shall be available through the WSPP's Hub or homepage. B-3.7 Start-up costs and no-load costs if included by the Seller shall be stated separately in the price. B-3.8 Energy schedules for the Purchaser's share of a unit may be modified by the Purchaser with not less than a thirty (30) minute notice before the hour in which the change is to take place, unless otherwise mutually agreed or unforeseen system operating conditions occur. B-3.9 Unit Commitment Service is intended to have assured availability; however, scheduled energy deliveries may be interrupted or curtailed as follows: (a) By the Seller by giving proper recall notice to the Purchaser if the Seller and the Purchaser have mutually agreed to recall provisions, (b) By the Seller when all or a portion of the output of the unit is unavailable, by an amount in proportion to the amount of the reduction in the output of the |
Western Systems Power Pool Original Sheet No. 85 Rate Schedule FERC No. 6 unit, unless otherwise agreed by the schedulers, (c) By the Seller to prevent system separation during an emergency, provided the Seller has exercised all prudent operating alternatives prior to the interruption or curtailment, (d) Where applicable, by the Seller to meet its public utility or statutory obligations to its customers, or (e) By either the Seller or the Purchaser due to the unavailability of transmission capacity necessary for the delivery of scheduled energy. B-3.10 Each Party that is a FERC regulated public utility as defined above in B-3.5 shall file the Confirmation Agreement with FERC for each transaction under this Service Schedule with a term in excess of one year no later than 30 days after service begins if that Party would have been required to file such Confirmation Agreements or similar agreements with FERC under an applicable FERC accepted market based rate schedule. |
B-4 BILLING AND PAYMENT PROVISIONS:
B-4.1 Except as provided in Sections B-4.2 and B-5, billing for Unit Commitment Service shall be computed based upon the agreed upon prices. B-4.2 In the event the Seller requests recall of Unit Commitment Service in a shorter time frame than was mutually agreed pursuant to Section B-3.9(a) and the |
Western Systems Power Pool Original Sheet No. 86 Rate Schedule FERC No. 6
Purchaser agrees to allow such recall, the Purchaser shall be relieved of any obligation to pay start-up costs. B-5 TERMINATION PROVISION: In the event Unit Commitment Service is curtailed or interrupted except as provided in Section B-3.9(a), the Purchaser shall have the option to cancel the Unit Commitment Service at any time by paying the Seller for (i) all energy deliveries scheduled up to the notice of termination and (ii) all separately stated start-up and no-load costs. |
Western Systems Power Pool First Revised Sheet No. 87 Rate Schedule FERC No. 6 Superseding Original Sheet No. 87 SERVICE SCHEDULE C FIRM CAPACITY/ENERGY SALE OR EXCHANGE SERVICE --------------------------------------------- C-1 PARTIES: This Service Schedule is agreed upon as a part of this Agreement by the Parties. C-2 PURPOSE: The purpose of this Service Schedule is to define additional specific procedures, terms, and conditions for requesting and providing Firm Capacity/Energy Sale or Exchange Service. C-3 TERMS: C-3.1 A Party may schedule Firm Capacity/Energy Sale or Exchange Service from another Party by mutual agreement; provided, however, that each Party shall be the sole judge as to the extent to and the conditions under which it is willing to provide or receive such service hereunder consistent with statutory requirements and contractual commitments including the Agreement and any applicable Confirmation Agreement. Once an agreement is reached, then the obligation for Firm Capacity/Energy Sale or Exchange Service becomes a firm commitment, for both Parties, for the agreed service and terms. C-3.2 Unless otherwise agreed between the Purchaser and the Seller, all transactions shall be prescheduled, subject to any conditions agreed to by schedulers. C-3.3 Firm capacity transactions shall include buying, selling, or exchanging capacity between Parties with or without associated energy. Firm capacity is deemed a capacity sale from the Seller's resources and backed by the Seller's |
Western Systems Power Pool First Revised Sheet No. 88 Rate Schedule FERC No. 6 Superseding Original Sheet No. 88 capacity reserves. C-3.4 Firm energy transactions shall include buying, selling, or exchanging firm energy between Parties. Subject to mutual agreement, firm energy is deemed a quantity of energy the Seller has agreed to sell and deliver and the Purchaser has agreed to buy within a specified time period. C-3.5 Purchaser shall arrange purchases directly with Sellers. C-3.6 The price for Firm Capacity/Energy Sale or Exchange Service shall be mutually agreed to in advance between Seller and Purchaser and shall not be subject to the rate caps specified in Section C-3.7 in either of the following two circumstances: (1) where the Seller is a FERC regulated public utility and that Seller has been authorized to sell power like that provided for under this Service Schedule at market-based rates; or (2) where the Seller is not a FERC regulated public utility. A Party is a FERC regulated public utility if it is a "public utility" as defined in Section 201(e) of the Federal Power Act, 16 U.S.C. [sect]. 824(e). C-3.7 Except as provided for in Section C-3.6, the price shall not exceed the Seller's forecasted Incremental Cost plus up to: $7.32/kW/month; $1.68/kW/week; 33.78[cent]/kW/day; 14.07 mills/kWh; or 21.11 mills/kWh for service of sixteen (16) hours or less per day. The hourly rate is capped at the Seller's forecasted Incremental Cost plus 33.78[cent]/kW/day. The total demand charge revenues in any consecutive seven-day period shall not exceed the product of the weekly rate and the |
Western Systems Power Pool First Revised Sheet No. 89 Rate Schedule FERC No. 6 Superseding Original Sheet No. 89
highest demand experienced on any day in the seven-day period. Exchange ratios among such Parties shall be as mutually agreed between the Purchaser and the Seller, but shall not exceed the ratio of 1.5 to 1.0. The Seller's forecasted Incremental Cost discussed above also may include any transmission and/or ancillary service costs associated with the sale, including the cost of any transmission and/or ancillary services that the Seller must take on its own system. Any such transmission and/or ancillary service charges shall be separately identified by the Seller to the Purchaser for transactions under this Schedule including exchanges. The transmission and ancillary service rate ceiling shall be available through the WSPP's Hub or homepage. Any such transmission service (and ancillary services provided in conjunction with such transmission service) by Seller shall be provided pursuant to any applicable transmission tariff or agreement, and the rates therefore shall be consistent with such tariff or agreement.
C-3.8 Firm Capacity/Energy Sale or Exchange Service shall be
interruptible only if the interruption is: (a) within the
recall time or allowed by other applicable provisions
governing interruptions of service under this Service
Schedule mutually agreed to by the Seller and the Purchaser,
(b) due to an Uncontrollable Force as provided in Section 10
of this Agreement; or (c) where applicable, to meet Seller's
public utility or statutory obligations to its customers. If
service under this Service Schedule is interrupted under
Section C-3.8(a) or (b), neither Seller nor Purchaser shall
be obligated to pay any damages under this Agreement or
Confirmation Agreement. If service under this Service
Schedule is interrupted for any reason
Western Systems Power Pool Original Sheet No. 89A Rate Schedule FERC No. 6
other than pursuant to Section C-3.8(a) or (b), the Non-Performing Party shall be responsible for payment of damages as provided in Section 21.3 of this Agreement or in any Confirmation.
Western Systems Power Pool First Revised Sheet No. 90 Rate Schedule FERC No. 6 Superseding Original Sheet No. 90 C-3.9 Each Party that is a FERC regulated public utility as defined in Section C-3.6 shall file the Confirmation Agreement with FERC for each transaction under this Service Schedule with a term in excess of one year no later than 30 days after service begins if that Party would have been required to file such Confirmation Agreements or similar agreements with FERC under an applicable FERC accepted market based rate schedule. C-3.10 Seller shall be responsible for ensuring that Service Schedule C transactions are scheduled as firm power consistent with the most recent rules adopted by the applicable NERC regional reliability council. |
Western Systems Power Pool First Revised Sheet No. 91 Rate Schedule FERC No. 6 Superseding Original Sheet No. 91 LIST OF MEMBERS ACN Power, Inc. AES NewEnergy, Inc. Allegheny Energy Supply Co., LLC Amerada Hess Corporation Ameren Energy Generating Company American Electric Power Service |
Corporation as agent for Ohio Power
Company, Public Service Company of
Oklahoma and Southwestern Electric
Power Company
APS Energy Services Company, Inc.
Aquila Energy Marketing Corporation
Arizona Electric Power Co.
Arizona Public Service Co.
Arkansas Electric Coop. Corp.
Associated Electric Cooperative, Inc.
Astra Oil Company, Inc.
Avista Corporation
Avista Energy, Inc.
Basin Electric Power Cooperative
Benton Public Utility District No. 1 of Benton County
Blackhills Power & Light Company
Bonneville Power Adm.
BP Energy Company
Burbank, City of
Calif. Dept. of Water Resources
Calpine Energy Services, L.P.
Candela Energy Corporation
Cargill-Alliant, LLC
Carolina Power & Light Company
Cheyenne Light, Fuel and Power Co.
Cinergy Capital & Trading, Inc.
Cinergy Operating Companies
City of Anaheim, Public Utilities Dept.
City of Azusa
City of Banning
City of Glendale Water & Power Dept.
City of Independence
City of Klamath Falls
City of Palo Alto
City of Riverside, California
City of Santa Clara Electric Department
City of Sikeston, Board of Municipal Utilities
City Utilities of Springfield, Missouri
City Water & Light (Jonesboro, AR)
Clatskanie PUD
Cleco Marketing & Trading LLC
Cleco Power LLC
CMS Marketing, Services and Trading Company
CNG Power Services Corp.
Colorado River Commission of Nevada
Colorado Springs Utilities
Colton, City of
Columbia Energy Power Marketing Columbia Power Corporation
Cominco, Ltd.
Commonwealth Energy Corporation
ConAgra Energy Services, Inc.
Conectiv Energy Supply, Inc.
Conoco Gas & Power Marketing - a division of Conoco Inc.
Constellation Power Source Cook Inlet Energy Supply Coral Power, L.L.C. Deseret G&T DTE Energy Trading, Inc. Duke Energy Trading & Marketing, LLC Duke Power Duke Solutions, Inc. Duke/Louis Dreyfuss, LLC Dynegy Power Marketing, Inc. Dynegy Power Services, Inc. E prime Edison Mission Marketing & Trading, Inc. Edison Source Edmonton Power Authority, Alberta El Paso Electric El Paso Merchant Energy, L.P. Empire District Electric Co. Energy Transfer Group, LLC EnerZ Corporation Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool First Revised Sheet No. 92 Rate Schedule FERC No. 6 Superseding Original Sheet No. 92 Engage Energy America LLC Engelhard Power Marketing, Inc. ENMAX Energy Corporation ENMAX Energy Marketing Inc. Enron Power Marketing, Inc. Enserco Energy Inc. Entergy Arkansas, Inc. Entergy Gulf States, Inc. Entergy Louisiana, Inc. Entergy Mississippi, Inc. Entergy New Orleans, Inc. Entergy Power, Inc. Entergy Services, Inc. as agent for the Entergy Operating Companies Entergy-Koch Trading, LP Equitable Power Services Co. Eugene Water & Electric Board Exelon Generation Company, LLC Farmington, City of Federal Energy Sales, Inc. FPL Energy Power Marketing Inc. Golden Spread Electric Cooperative Grand River Dam Authority Hafslund Energy Trading, LLC Hetch-Hetchy Water & Power Hinson Power Co., LLC Howard Energy Co., Inc. IDACORP Energy L.P. Idaho Power Company IGI Resources, Inc. Illinova Energy Partners, Inc. Imperial Irrigation District Industrial Energy Applications, Inc. InterCoast Power Marketing J. Aron & Company KAMO Electric Cooperative, Inc. Kansas City Board of Public Utilities Kansas City Power & Light KN Energy Marketing Lafayette Utilities System LG&E Energy Marketing Inc. Lincoln Electric System Los Alamos County Los Angeles Dept. of Water & Power Louisiana Generating LLC Louisville Gas & Electric Company Maclaren Energy Inc. Mason County PUD No. 3 McMinnville Water & Light Merchant Energy Group of the Americas, Inc. Merrill Lynch Capital Services, Inc. Metropolitan Water District MidAmerican Energy Company MidCon Power Services Corp. MIECO, Inc. Minnesota Power, Inc. Mirant Americas Energy Marketing, LP Missouri Joint Municipal Electric Utility Comm. Modesto Irrigation District Morgan Stanley Capital Group, Inc. M-S-R Public Power Agency Municipal Energy Agency of Mississippi Municipal Energy Agency of Nebraska Nebraska Public Power District Nevada Power Co. New West Energy NorthPoint Energy Solutions Inc. Northern California Power Agency Northern States Power Company NP Energy Inc. NRG Power Marketing Inc. OGE Energy Resources, Inc. Oklahoma Gas & Electric Oklahoma Municipal Power Authority Omaha Public Power District ONEOK Power Marketing Company Otter Tail Power Company Pacific Gas & Electric Co. Pacific Northwest Generating Coop. PacifiCorp PacifiCorp Power Marketing, Inc. PanCanadian Energy Services Pasadena, City of PG&E Energy Services PG&E Energy Trading - Power, L.P. PG&E Power Services Company Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002 Western Systems Power Pool Issued on: December 21, 2001 |
Western Systems Power Pool Sixth Revised Sheet No. 93 Rate Schedule FERC No. 6 Superseding Fifth Sheet No. 93 Phibro Inc. Pinnacle West Capital Corporation Plains Elec. Gen. & Trans. Coop. Inc. Platte River Power Authority Portland General Electric Co. Power Exchange Corporation Powerex PPL Electric Utilities Corporation PPL EnergyPlus, LLC PPL Montana, LLC Public Service Co. of NM Public Service Co. of Colorado Public Util. Dist. No. 1 of Douglas Cty. Public Util. Dist. No. 1 of Franklin Cty. PUD No. 1 of Chelan County PUD No. 1 of Grays Harbor County PUD No. 1 of Snohomish County PUD No. 2 of Grant County Puget Sound Energy QST Energy Trading Inc. Questar Energy Trading Rainbow Energy Marketing Corporation Redding, City of Reliant Energy Services, Inc. Rocky Mountain Generation Coop., Inc. Roseville Electric Sacramento Municipal Utility District Salt River Project San Diego Gas & Electric Co. Seattle City Light Sempra Energy Resources Sempra Energy Solutions Sempra Energy Trading Corp. Sierra Pacific Power Co. Southern Calif. Edison Co. Southern California Water Company Southern Company Services, Inc. Southern Illinois Power Cooperative Southwest Power Administration Southwestern Public Service Split Rock Energy LLC Statoil Energy Trading, Inc. Strategic Energy LLC Sunflower Electric Power Corp. Tacoma Power Tenaska Power Services Co. Tennessee Valley Authority Texaco Energy Services Texas-New Mexico Power Company The Detroit Edison Co. The Energy Authority The Montana Power Company The Power Company of America, LP Tractebel Energy Marketing, Inc. TransAlta Energy Marketing (US) Inc. TransCanada Power, div. of TransCanada Energy Ltd. Tri-State Generation and Transmission Assoc. Tucson Electric Power Turlock Irrigation District TXU Energy Trading Company Union Electric Company Utah Associated Municipal Power Systems UtiliCorp United Vastar Power Marketing, Inc. Vernon, City of VIASYN, Inc. Virginia Electric and Power Company Vitol Gas & Electric LLC |
WAPA-Colorado River Storage Project Management Center
WAPA-Desert Southwest Region
WAPA-Rocky Mountain Region
WAPA-Upper Great Plains Region
WAPA-Sierra Nevada Region
West Kootenay Power Ltd.
Western Farmers Electric Co-op
Western Power Services, Inc.
Western Resources, Inc.
Williams Energy Marketing & Trading Co.
WPS Energy Services, Inc.
XCEL Energy Services, Inc.
Issued by: Michael E. Small, General Counsel to Effective: March 1, 2002
Western Systems Power Pool
Issued on: December 21, 2001
Exhibit 10(G)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 90
Effective: June 1, 2002
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 90 Open Access Transmission Tariff -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that it may not be possible to renew this Agreement beyond its initial term without the construction of additional Network Upgrades. Transmission Customer's right to renew this Agreement beyond its initial term therefore is subject to there being adequate available transmission capacity not allocated to an entity with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 90 Open Access Transmission Tariff -------------------------------------------------------------------------------- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
West Trading Group - Transmission
Reliant Energy Services, Inc.
P.O. Box 4455
Houston, TX 77210-4455
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ----------------------------- --------------- --------------- Name Title Date Transmission Customer: --------------------- By: ----------------------------- --------------- --------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 90 Open Access Transmission Tariff -------------------------------------------------------------------------------- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
500 MW from Bighorn (Jean) 230 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path Bighorn 230 kV - Arden 230 kV - Mead 230 kV.
3.0 Point of Receipt Delivering Party Bighorn (Jean) 230 kV Substation Reliant Energy Services, Inc. 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Reliant Energy Services, Inc. |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 90 Open Access Transmission Tariff -------------------------------------------------------------------------------- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10(H)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 95
Effective: July 1, 2001
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that Transmission Provider is experiencing high load growth and that Transmission Provider's obligation to serve Native Load Customers is projected to increase significantly in the future. For this reason, Transmission Customer understands that there may not be sufficient transmission capacity for Transmission Provider to continue to serve Transmission Customer at the expiration of the term of this Agreement. Accordingly, notwithstanding Section 2.2 of the Transmission Provider's Tariff, Transmission Customer's right to renew this Agreement at the expiration of the initial term is subject to a determination that there is adequate transmission capacity to continue to serve Transmission Customer in addition to Native Load Customers and other customers with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Calpine Corporation
50 West San Fernando Street
San Jose, CA 95133
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ----------------------- ---------------------- ---------------------- Name Title Date Transmission Customer: --------------------- By: ----------------------- ---------------------- ---------------------- Name Title Date Page 3 of 4 -------------------------------------------------------------------------------- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
500 MW from Crystal 500 kV Substation in Nevada Power Company's Control Area to Nevada Power's Uncongested Grid using the Contract Path Crystal 500 kV - Harry Allen 500 kV - NW 230 kV - NVP Uncongested Grid.
3.0 Point of Receipt Delivering Party Crystal 500 kV Substation Calpine Corporation 4.0 Point of Delivery Receiving Party Nevada Power's Control Area Loan Serving Entity |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
9.0 Transmission Customer must demonstrate to Transmission Provider, at least three (3) months in advance of taking service, that Transmission Customer has a contract to serve Nevada Power Control Area customers that Transmission Provider otherwise would be obligated to serve.
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 96
Effective: July 1, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 96 Open Access Transmission Tariff ---- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that Transmission Provider is experiencing high load growth and that Transmission Provider's obligation to serve Native Load Customers is projected to increase significantly in the future. For this reason, Transmission Customer understands that there may not be sufficient transmission capacity for Transmission Provider to continue to serve Transmission Customer at the expiration of the term of this Agreement. Accordingly, notwithstanding Section 2.2 of the Transmission Provider's Tariff, Transmission Customer's right to renew this Agreement at the expiration of the initial term is subject to a determination that there is adequate transmission capacity to continue to serve Transmission Customer in addition to Native Load Customers and other customers with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Calpine Corporation
50 West San Fernando Street
San Jose, CA 95133
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ----------------------- ---------------------- ---------------------- Name Title Date Transmission Customer: --------------------- By: ----------------------- ---------------------- ---------------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ----- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
400 MW from Crystal 500 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path Crystal 500 kV - Harry Allen 500 kV - Mead 500 kV - Mead 230 kV.
3.0 Point of Receipt Delivering Party Crystal 500 kV Substation Calpine Corporation 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Market |
Nevada Power will propose the addition of a Mead 500/230 kV transformer such that this contract path would allow for deliveries to Mead 230 kV. Nevada Power will work with the appropriate third party utilities to accomplish the interconnection. Any firm service that is offered by Nevada Power to Mead 230 kV using this contract path is contingent upon the successful completion of the transformer installation.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ----- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10{I)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 97
Effective: July 1, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 97 Open Access Transmission Tariff ---- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that Transmission Provider is experiencing high load growth and that Transmission Provider's obligation to serve Native Load Customers is projected to increase significantly in the future. For this reason, Transmission Customer understands that there may not be sufficient transmission capacity for Transmission Provider to continue to serve Transmission Customer at the expiration of the term of this Agreement. Accordingly, notwithstanding Section 2.2 of the Transmission Provider's Tariff, Transmission Customer's right to renew this Agreement at the expiration of the initial term is subject to a determination that there is adequate transmission capacity to continue to serve Transmission Customer in addition to Native Load Customers and other customers with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Manger, New Business Development
Duke Energy Trading and Marketing
4 Triad Center
Suite 1000
Salt Lake City, UT 84180
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ---------------------- ------------------- ------------------- Name Title Date Transmission Customer: --------------------- By: ---------------------- ------------------- ------------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
600 MW from Harry Allen 500 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path Harry Allen 500 kV - Mead 500 kV - Mead 230 kV.
3.0 Point of Receipt Delivering Party Harry Allen 500 kV Substation Duke Energy Trading and Marketing 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Duke Energy Trading and Marketing |
Nevada Power will propose the addition of a Mead 500/230 kV transformer such that this contract path would allow for deliveries to Mead 230 kV. Nevada Power will work with the appropriate third party utilities to accomplish the interconnection. Any firm service that is offered by Nevada Power to Mead 230 kV using this contract path is contingent upon the successful completion of the transformer installation.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10(J)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 98
Effective: July 1, 2001
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that existing long term firm service customers have the right to continue to take transmission service from the Transmission Provider when the contract expires, rolls over, or is renewed, and twenty-year term firm point-to-point Transmission Service will have equal priority with Native Load Customers and Network Customers. Practically, Transmission Customer understands that subsequent plans of Transmission Provider shall be developed to ensure sufficient transmission capacity is available to meet the needs of Native Load Customers, Network Customers, and existing Long-Term Firm Point-to-Point Transmission Service Agreements. Notwithstanding Transmission Customers right to renew this Agreement under Sections 2.2 and 13.2 of the Transmission Provider's Tariff, Transmission Customer agrees that Transmission Provider, upon reasonable written notice provided no earlier than ten (10) years after the commencement of service under this Agreement, shall request and that Transmission Customer shall declare within 120 days whether it intends to exercise its right to renew this Agreement at the end of the initial term in accordance with the intent of Sections 2.2 and 13.2 of the Transmission Provider's Tariff.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement provided such service is available as defined in Section 4 above.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Mirant Americas Energy Marketing, LP
1155 Perimeter Center West
Atlanta, GA 30338
9.0 The Tariff is incorporated herein and made a part hereof.
10.0 This Agreement shall become effective upon the filing of the associated executed or unexecuted Interconnection and Operating Agreement (IOA) with the Commission. Notwithstanding Transmission Customer's right to request Transmission Provider to file an unexecuted IOA, Transmission Provider and Transmission Customer agree to, within 30 days of the filing of this Agreement with the Commission, either execute the IOA or have the Transmission Provider file with the Commission an unexecuted IOA. If an unexecuted IOA is filed with the Commission, Transmission Provider and Transmission Customer agree to comply with the terms and conditions of the IOA ultimately imposed by the Commission.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ---------------------- -------------------- ------------------ Name Title Date Transmission Customer: --------------------- By: ---------------------- -------------------- ------------------ Name Title Date -------------------------------------------------------------------------------- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
225 MW from Harry Allen 500 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path HA 500 kV - Mead 500 kV - Mead 230 kV.
3.0 Point of Receipt Delivering Party Harry Allen 500 kV Substation Mirant Americas Energy Marketing, LP 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Network Service |
Nevada Power will propose the addition of a Mead 500/230 kV transformer such that this contract path would allow for deliveries to Mead 230 kV. Nevada Power will work with the appropriate third party utilities to accomplish the interconnection. Any firm service that is offered by Nevada Power to Mead 230 kV using this contract path is contingent upon the successful completion of the transformer installation.
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 99
Effective: July 1, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 99 Open Access Transmission Tariff ---- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that existing long term firm service customers have the right to continue to take transmission service from the Transmission Provider when the contract expires, rolls over, or is renewed, and twenty-year term firm point-to-point Transmission Service will have equal priority with Native Load Customers and Network Customers. Practically, Transmission Customer understands that subsequent plans of Transmission Provider shall be developed to ensure sufficient transmission capacity is available to meet the needs of Native Load Customers, Network Customers, and existing Long-Term Firm Point-to-Point Transmission Service Agreements. Notwithstanding Transmission Customers right to renew this Agreement under Sections 2.2 and 13.2 of the Transmission Provider's Tariff, Transmission Customer agrees that Transmission Provider, upon reasonable written notice provided no earlier than ten (10) years after the commencement of service under this Agreement, shall request and that Transmission Customer shall declare within 120 days whether it intends to exercise its right to renew this Agreement at the end of the initial term in accordance with the intent of Sections 2.2 and 13.2 of the Transmission Provider's Tariff.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement provided such service is available as defined in Section 4 above.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Mirant Americas Energy Marketing, LP
1155 Perimeter Center West
Atlanta, GA 30338
9.0 The Tariff is incorporated herein and made a part hereof.
10.0 This Agreement shall become effective upon the filing of the associated executed or unexecuted Interconnection and Operating Agreement (IOA) with the Commission. Notwithstanding Transmission Customer's right to request Transmission Provider to file an unexecuted IOA, Transmission Provider and Transmission Customer agree to, within 30 days of the filing of this Agreement with the Commission, either execute the IOA or have the Transmission Provider file with the Commission an unexecuted IOA. If an unexecuted IOA is filed with the Commission, Transmission Provider and Transmission Customer agree to comply with the terms and conditions of the IOA ultimately imposed by the Commission.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ------------------------ ---------------------- --------------------- Name Title Date Transmission Customer: --------------------- By: ------------------------ ---------------------- ---------------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
275 MW from Harry Allen 500 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path HA 500 kV - Mead 500 kV - Mead 230 kV.
3.0 Point of Receipt Delivering Party Harry Allen 500 kV Substation Mirant Americas Energy Marketing, LP 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Network Service |
Nevada Power will propose the addition of a Mead 500/230 kV transformer such that this contract path would allow for deliveries to Mead 230 kV. Nevada Power will work with the appropriate third party utilities to accomplish the interconnection. Any firm service that is offered by Nevada Power to Mead 230 kV using this contract path is contingent upon the successful completion of the transformer installation.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10(K)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 100
Effective: July 1, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 100 Open Access Transmission Tariff --- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that Transmission Provider is experiencing high load growth and that Transmission Provider's obligation to serve Native Load Customers is projected to increase significantly in the future. For this reason, Transmission Customer understands that there may not be sufficient transmission capacity for Transmission Provider to continue to serve Transmission Customer at the expiration of the term of this Agreement. Accordingly, notwithstanding Section 2.2 of the Transmission Provider's Tariff, Transmission Customer's right to renew this Agreement at the expiration of the initial term is subject to a determination that there is adequate transmission capacity to continue to serve Transmission Customer in addition to Native Load Customers and other customers with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Pinnacle West Energy Corporation P.O. Box 53999, Mail Station 8985 Phoenix, AZ 85072-3999
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: --------------------- --------------------- ---------------------- Name Title Date Transmission Customer: --------------------- By: --------------------- --------------------- ---------------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
350 MW from Harry Allen 500 kV Substation in Nevada Power Company's Control Area to Mead 500 kV Substation using the Contract Path HA 500 kV - Mead 500 kV.
3.0 Point of Receipt Delivering Party Harry Allen 500 kV Substation Pinnacle West Energy Corporation 4.0 Point of Delivery Receiving Party Mead 500 kV Substation Market |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10(L)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 101
Effective: July 1, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 101 Open Access Transmission Tariff --- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Transmission Customer understands that Transmission Provider is experiencing high load growth and that Transmission Provider's obligation to serve Native Load Customers is projected to increase significantly in the future. For this reason, Transmission Customer understands that there may not be sufficient transmission capacity for Transmission Provider to continue to serve Transmission Customer at the expiration of the term of this Agreement. Accordingly, notwithstanding Section 2.2 of the Transmission Provider's Tariff, Transmission Customer's right to renew this Agreement at the expiration of the initial term is subject to a determination that there is adequate transmission capacity to continue to serve Transmission Customer in addition to Native Load Customers and other customers with a higher priority to transmission capacity. If adequate capacity is not available, Transmission Customer's right to renew this Agreement is subject to Sections 19-21 of the Transmission Provider's Tariff and also is subject to Transmission Customer's agreement to pay any costs of Network Upgrades that Transmission Provider is authorized to charge to Transmission Customer in accordance with Commission policy.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 If any event occurs that will materially affect the time for completion of new facilities or the ability to complete them, Transmission Provider shall promptly notify the Transmission Customer. A technical meeting between the Parties shall be held to evaluate the alternatives available. If the Transmission Provider and the Transmission Customer mutually agree that no other reasonable alternatives exist and the requested service cannot be provided out of existing capability under the conditions of Part II of the Tariff, the obligation to provide the requested Firm Point-To-Point Transmission Service shall terminate and any deposit made by the Transmission Customer shall be returned with interest pursuant to Commission regulations 35.19a(a)(2)(iii). However, the Transmission Customer shall be responsible for all prudently incurred costs by the Transmission Provider through the time construction was suspended.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
West Trading Group - Transmission
Reliant Energy Services, Inc.
P.O. Box 4455
Houston, TX 77210-4455
9.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
By: ------------------------ ----------------- -------------------------- Name Title Date Transmission Customer: --------------------- By: ------------------------ ----------------- ------------------------- Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
500 MW from Harry Allen 500 kV Substation in Nevada Power Company's Control Area to Mead 230 kV Substation using the Contract Path Harry Allen 500 kV - NW 230 kV - NVP Uncongested Grid - Mead 230 kV.
3.0 Point of Receipt Delivering Party Harry Allen 500 kV Substation Reliant Energy Services, Inc. 4.0 Point of Delivery Receiving Party Mead 230 kV Substation Reliant Energy Services, Inc. |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Exhibit 10(M)
SIERRA PACIFIC RESOURCES OPERATING
COMPANIES FERC ELECTRIC TARIFF,
FIRST REVISED VOLUME NO. 1
SERVICE AGREEMENT NO. 102
Effective:August 4, 2001
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. 102 Open Access Transmission Tariff --- -------------------------------------------------------------------------------- |
Service Agreement For Long-Term
Firm Point-To-Point Transmission Service
2.0 The Transmission Customer has been determined by the Transmission Provider to have a Completed Application for Firm Point-To-Point Transmission Service under the Tariff.
3.0 The Transmission Customer has provided to the Transmission Provider an Application deposit in accordance with the provisions of Section 17.3 of the Tariff.
4.0 Service under this agreement shall commence on the later of (1) the requested service commencement date, or (2) the date on which construction of any Direct Assignment Facilities and/or Network Upgrades are completed, or (3) such other date as it is permitted to become effective by the Commission. Service under this agreement shall terminate on the actual termination date or such date as mutually agreed upon by the parties.
5.0 Renewal of this transmission service will be subject to the preservation of the pre-existing rights held by existing and queued transmission customers at the time of Transmission Customer's application for this service. Additional network upgrades could be necessary to preserve those customers' rights. If necessary, the appropriate share of those costs will be determined in accordance with the Tariff.
6.0 The Transmission Provider agrees to provide and the Transmission Customer agrees to take and pay for Firm Point-To-Point Transmission Service in accordance with the provisions of Part II of the Tariff and this Service Agreement.
7.0 Any notice or request made to or by either Party regarding this Service Agreement shall be made to the representative of the other Party as indicated below.
Executive Director, Transmission Services
Sierra Pacific Power Company
P.O. Box 10100
Reno, Nevada 89520
and/or
Director, Regional Transmission
Nevada Power Company
P.O. Box 230
Las Vegas, NV 89151
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
Las Vegas Cogeneration II, L.L.C.
1701 East Alexander Road
North Las Vegas, NV 89030
8.0 The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by their respective authorized officials.
Transmission Provider: --------------------- By: ----------------------------- ----------------------- ------------------ Name Title Date Transmission Customer: --------------------- By: ----------------------------- ----------------------- ------------------ Name Title Date -------------------------------------------------------------------------------- |
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
1.0 Term of Transaction: 1 Year
Start Date: 5-01-02
Termination Date: 4-30-03
2.0 Description of capacity and energy to be transmitted by Transmission Provider including the electric Control Area in which the transaction originates.
230 MW from LVCogeneration II in Nevada Power Company's control area to Mead 230 KV Substation in WAPA's control area.
3.0 Point of Receipt Delivering Party LVCogen Sub Las Vegas Cogeneration II, L.L.C. 4.0 Point of Delivery Receiving Party Mead 230 KV Substation California ISO |
8.0 Service under this Agreement may be subject to some combination of the charges detailed below. (The appropriate charges for individual transactions will be determined in accordance with the terms and conditions of the Tariff.)
Sierra Pacific Resources Operating Companies
FERC Electric Tariff First Revised Volume No. 1 Service Agreement No. Open Access Transmission Tariff ---- |
8.2 System Impact and/or Facilities Study Charge(s): Pending finalization, $10,000 deposit in place.
8.3 Direct Assignment Facilities Charge: None under this TSA. However, Direct Assignment Facilities will be required to provide the associated interconnection and are defined in the Interconnection & Operation Agreement.
8.4 Ancillary Services Charges: As negotiated.
8.5. Power Factor Requirements: As defined in Interconnection and Operation Agreement.
EXHIBIT 10(N)
$150,000,000
CREDIT AGREEMENT
dated as of
November 30, 2001
among
SIERRA PACIFIC POWER COMPANY,
UNION BANK OF CALIFORNIA, N.A.,
as Sole Bookrunner and Administrative Agent,
WELLS FARGO BANK, N.A.,
as Syndication Agent,
and
BANK ONE, NA,
BNP PARIBAS and
MELLON BANK, N.A.,
as Co-Documentation Agents,
and
the LENDERS party hereto from time to time
Co-Arranged By
UNION BANK OF CALIFORNIA, N.A. and
WELLS FARGO BANK, N.A.
TABLE OF CONTENTS Page ---- ARTICLE I DEFINITIONS; CONSTRUCTION.........................................................1 SECTION 1.01 Defined Terms.............................................................1 SECTION 1.02 Classification of Loans and Borrowings...................................16 SECTION 1.03 Terms Generally..........................................................16 SECTION 1.04 Accounting Terms; GAAP...................................................16 ARTICLE II THE CREDITS......................................................................16 SECTION 2.01 The Commitments..........................................................16 SECTION 2.02 Loans and Borrowings.....................................................17 SECTION 2.03 Requests for Revolving Borrowings........................................17 SECTION 2.04 Funding of Borrowings....................................................18 SECTION 2.05 Interest Elections.......................................................19 SECTION 2.06 Termination, Reduction and Extension of Commitments......................20 SECTION 2.07 Repayment of Loans; Evidence of Debt.....................................23 SECTION 2.08 Prepayment of Loans......................................................24 SECTION 2.09 Fees.....................................................................24 SECTION 2.10 Interest.................................................................25 SECTION 2.11 Alternate Rate of Interest...............................................25 SECTION 2.12 Increased Costs..........................................................26 SECTION 2.13 Break Funding Payments...................................................26 SECTION 2.14 Taxes....................................................................27 SECTION 2.15 Payments Generally; Pro Rata Treatment; Sharing of Set-offs..............28 SECTION 2.16 Mitigation Obligations; Replacement of Lenders...........................30 ARTICLE III REPRESENTATIONS AND WARRANTIES...................................................30 SECTION 3.01 Corporate Status.........................................................30 SECTION 3.02 Corporate Power and Authorization........................................31 SECTION 3.03 Execution and Binding Effect.............................................31 SECTION 3.04 Governmental Approvals and Filings.......................................31 SECTION 3.05 Absence of Conflicts.....................................................31 SECTION 3.06 Audited Financial Statements.............................................32 SECTION 3.07 Interim Financial Statements.............................................32 SECTION 3.08 Absence of Undisclosed Liabilities.......................................33 SECTION 3.09 Absence of Material Adverse Change.......................................33 SECTION 3.10 Accurate and Complete Disclosure.........................................33 SECTION 3.11 Margin Regulations.......................................................33 SECTION 3.12 Litigation...............................................................33 SECTION 3.13 Absence of Events of Default.............................................34 SECTION 3.14 Absence of Other Conflicts...............................................34 SECTION 3.15 Insurance................................................................34 SECTION 3.16 Title to Property; No Liens..............................................34 SECTION 3.17 Taxes....................................................................35 SECTION 3.18 Borrower Not An Investment Company.......................................35 |
TABLE OF CONTENTS (Continued) Page ---- SECTION 3.19 Environmental Matters....................................................35 SECTION 3.20 ERISA....................................................................36 SECTION 3.21 Pari Passu Status........................................................37 SECTION 3.22 Indebtedness.............................................................37 SECTION 3.23 Collateral Bonds.........................................................37 ARTICLE IV CONDITIONS.......................................................................37 SECTION 4.01 Effective Date...........................................................37 SECTION 4.02 Conditions to All Loans..................................................41 ARTICLE V AFFIRMATIVE COVENANTS............................................................41 SECTION 5.01 Basic Reporting Requirements.............................................41 SECTION 5.02 Insurance................................................................44 SECTION 5.03 Payment of Taxes and Other Potential Charges and Priority Claims.........45 SECTION 5.04 Preservation of Corporate Status and Franchises..........................45 SECTION 5.05 Governmental Approvals and Filings.......................................45 SECTION 5.06 Maintenance of Properties................................................46 SECTION 5.07 Avoidance of Other Conflicts.............................................46 SECTION 5.08 Financial Accounting Practices...........................................46 SECTION 5.09 Use of Proceeds..........................................................46 SECTION 5.10 End of Fiscal Periods....................................................47 ARTICLE VI NEGATIVE COVENANTS...............................................................47 SECTION 6.01 Financial Covenants......................................................47 SECTION 6.02 Liens....................................................................47 SECTION 6.03 Mergers..................................................................48 SECTION 6.04 Dispositions of Properties...............................................49 SECTION 6.05 Investments and Acquisitions.............................................50 SECTION 6.06 Dividends and Stock Repurchases..........................................50 SECTION 6.07 Transactions with Affiliates.............................................50 SECTION 6.08 Change of Business.......................................................50 SECTION 6.09 Equal and Ratable Lien; Grant of Security Interest in Certain Events.....51 SECTION 6.10 Restrictive Agreements...................................................51 ARTICLE VII DEFAULTS.........................................................................52 SECTION 7.01 Events of Default........................................................52 SECTION 7.02 Consequences of an Event of Default......................................54 ARTICLE VIII THE AGENTS.......................................................................55 SECTION 8.01 Appointment..............................................................55 SECTION 8.02 General Nature of Administrative Agent's Duties..........................55 SECTION 8.03 Exercise of Powers.......................................................56 SECTION 8.04 General Exculpatory Provisions...........................................56 |
TABLE OF CONTENTS (Continued) Page ---- SECTION 8.05 Administration by the Administrative Agent...............................57 SECTION 8.06 Lenders Not Relying on Administrative Agent or Other Lenders.............58 SECTION 8.07 Indemnification..........................................................58 SECTION 8.08 Administrative Agent in its Individual Capacity..........................59 SECTION 8.09 Holders of Notes.........................................................59 SECTION 8.10 Successor Administrative Agent...........................................59 SECTION 8.11 Additional Administrative Agents.........................................60 SECTION 8.12 Calculations.............................................................60 SECTION 8.13 Syndication Agent........................................................61 SECTION 8.14 Sole Bookrunner..........................................................61 SECTION 8.15 Co-Documentation Agents..................................................61 ARTICLE IX MISCELLANEOUS....................................................................61 SECTION 9.01 Amendments and Waivers...................................................61 SECTION 9.02 No Implied Waiver; Cumulative Remedies...................................62 SECTION 9.03 Notices..................................................................63 SECTION 9.04 Expenses; Taxes; Indemnity...............................................63 SECTION 9.05 Severability.............................................................64 SECTION 9.06 Prior Understandings.....................................................65 SECTION 9.07 Duration; Survival.......................................................65 SECTION 9.08 Counterparts.............................................................65 SECTION 9.09 Limitation on Payments...................................................65 SECTION 9.10 Set-Off..................................................................65 SECTION 9.11 Sharing of Collections...................................................66 SECTION 9.12 Successors and Assigns; Participations; Assignments......................66 SECTION 9.13 Governing Law; Submission to Jurisdiction Waiver of Jury Trial; Limitation of Liability..................................................69 |
Schedule I COMMITMENTS Schedule II JURISDICTIONS Schedule III LITIGATION Schedule IV LIENS Schedule V ENVIRONMENTAL CLAIMS Schedule VI EXISTING INDEBTEDNESS EXHIBITS -------- Exhibit A FORM OF ASSIGNMENT AND ACCEPTANCE Exhibit B FORM OF BORROWING REQUEST Exhibit C FORM OF PROMISSORY NOTE Exhibit D FORM OF QUARTERLY COMPLIANCE CERTIFICATE -iii- |
CREDIT AGREEMENT, dated as of November 30, 2001, among |
SIERRA PACIFIC POWER COMPANY, a Nevada corporation, UNION BANK OF CALIFORNIA,
N.A., as Sole Bookrunner and Administrative Agent, WELLS FARGO BANK, N.A., as
Syndication Agent, BANK ONE, NA, BNP PARIBAS and MELLON BANK, N.A., as
Co-Documentation Agents, the LENDERS party hereto from time to time, and UNION
BANK OF CALIFORNIA, N.A. and WELLS FARGO BANK, N.A., as Co-Lead Arrangers.
WHEREAS, the Borrower (as defined below) has requested, and the Lenders (as defined below) have agreed to make available, the credit facilities described below upon the terms and conditions contained herein.
NOW, THEREFORE, in consideration of the premises and of the mutual covenants herein contained and intending to be legally bound hereby, the parties hereto agree as follows:
ARTICLE I
DEFINITIONS; CONSTRUCTION
As used in this Agreement, the following terms have the following meanings:
A. Prior to the Occurrence of an Acceptable Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ----------- ----------- ----------- ---------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- Eurodollar Spread 0.65% 0.875% 0.975% 1.05% 1.25% -------------------------------------------------------------------------------------------------------------------- ABR Spread 0% 0% 0% 0.05% 0.25% -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 3, 0.10% per annum, (B) in the case of Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum.
B. Upon and After the Occurrence of an Acceptable Rate Case:
==================================================================================================================== Category 1 Category 2 Category 3 Category 4 Category 5 ---------- ----------- ----------- ----------- ----------- A- or higher BBB+ or higher BBB or higher BBB- or higher BB+ or lower by S&P and A3 by S&P and Baa1 by S&P and Baa2 by S&P and Baa3 by S&P or Ba1 or higher by or higher by or higher by or higher by or lower by Moody's Moody's Moody's Moody's Moody's ==================================================================================================================== Facility Fee 0.10% 0.125% 0.15% 0.20% 0.30% -------------------------------------------------------------------------------------------------------------------- Eurodollar Spread 0.525% 0.75% 0.85% 0.925% 1.125% -------------------------------------------------------------------------------------------------------------------- ABR Spread 0% 0% 0% 0% 0.125% -------------------------------------------------------------------------------------------------------------------- |
Notwithstanding the foregoing, in the event that, and at all times during which, the aggregate principal amount of the Loans outstanding hereunder exceeds 50% of the total Commitments, (i) each of the foregoing Eurodollar Spreads shall be increased by (A) in the case of Category 1, 0.10% per annum, (B) in the case of each of Category 2, Category 3 and Category 4, 0.125% per annum, and (C) in the case of Category 5, 0.25% per annum, and (ii) the foregoing ABR Spreads shall be increased by (A) in the case of Category 4, 0.05% per annum, and (B) in the case of Category 5, 0.25% per annum.
For purposes of the foregoing pricing tables, (1) if either Moody's or S&P shall not have in effect a rating for the Index Debt of Borrower (other than by reason of the circumstances referred
to in the last sentence of this definition), then such rating agency shall be deemed to have established a rating in Category 5, (2) if the ratings established or deemed to have been established by Moody's and S&P for the Index Debt of Borrower shall be changed (other than as a result of a change in the rating system of Moody's or S&P), such change shall be effective as of two Business Days after it is first announced by the applicable rating agency, (3) if more than one Category is applicable at any one time, the Applicable Rate shall be based on the applicable Category having the lowest number (i.e., Category 1 is lower than Category 2), and (4) upon the occurrence of an Acceptable Rate Case and at all times thereafter, the pricing table set forth above under the caption "Upon and After the Occurrence of an Acceptable Rate Case" shall be effective. Each change in the Applicable Rate (including any change based on the occurrence of an Acceptable Rate Case) shall apply during the period commencing on the effective date of such change and ending on the date immediately preceding the effective date of the next such change. If the rating system of Moody's or S&P shall change, or if either such rating agency shall cease to be in the business of rating corporate debt obligations, the Borrower and the Lenders shall negotiate in good faith to amend this definition to reflect such changed rating system or the unavailability of ratings from such rating agency and, pending the effectiveness of any such amendment, the Applicable Rate shall be determined by reference to the rating most recently in effect prior to such change or cessation.
may be (a) terminated or reduced from time to time pursuant to Section 2.06 or 7.02 and (b) reduced or increased from time to time pursuant to assignments by or to such Lender pursuant to Section 9.12. The initial amount of each Lender's Commitment is set forth on Schedule I or in the Assignment and Acceptance pursuant to which such Lender shall have assumed its Commitment, as applicable. The aggregate amount of the Lenders' Commitments shall in no event exceed $150,000,000.
necessary, to the next 1/100 of 1%) of the quotations for such day for such transactions received by the Administrative Agent from three Federal funds brokers of recognized standing selected by it.
transformers or other equipment that contain dielectric fluid containing levels of polychlorinated biphenyls, and radon gas; (b) any chemicals, materials or substances defined as or included in the definition of "hazardous substances," "hazardous waste," "hazardous materials," "extremely hazardous substances," "restricted hazardous waste," "toxic substances," "toxic pollutants," "contaminants," or "pollutants," or words of similar import, under any applicable Environmental Law; and (c) any other chemical, material or substance, the Release of which is prohibited, limited or regulated by any Governmental Authority.
successors and assigns) shall for any reason no longer perform the functions of a securities rating agency, "S&P" shall be deemed to refer to any other nationally recognized securities rating agency approved for purposes hereof by the Required Lenders and the Borrower.
For purposes of this Agreement, Loans may be classified and referred to by Class (e.g., a "Revolving Loan") or by Type (e.g., a "Eurodollar Loan" or an "ABR Loan") or by Class and Type (e.g., a "Eurodollar Revolving Loan"). Borrowings also may be classified and referred to by Class (e.g., a "Revolving Borrowing") or by Type (e.g., a "Eurodollar Borrowing") or by Class and Type (e.g., a "Eurodollar Revolving Borrowing").
The definitions of terms herein shall apply equally to the singular and plural forms of the terms defined. Whenever the context may require, any pronoun shall include the corresponding masculine, feminine and neuter forms. The words "include", "includes" and "including" shall be deemed to be followed by the phrase "without limitation". The word "will" shall be construed to have the same meaning and effect as the word "shall". Unless the context requires otherwise (a) any definition of or reference to any agreement, instrument or other document herein shall be construed as referring to such agreement, instrument or other document as from time to time amended, supplemented or otherwise modified (subject to any restrictions on such amendments, supplements or modifications set forth herein), (b) any reference herein to any Person shall be construed to include such Person's successors and assigns, (c) the words "herein", "hereof" and "hereunder", and words of similar import, shall be construed to refer to this Agreement in its entirety and not to any particular provision hereof and (d) all references herein to Articles, Sections, Exhibits and Schedules shall be construed to refer to Articles and Sections of, and Exhibits and Schedules to, this Agreement.
Except as otherwise expressly provided herein, all terms of an accounting or financial nature shall be construed in accordance with GAAP, as in effect from time to time.
ARTICLE II
THE CREDITS
exceeding such Lender's Commitment or (ii) the sum of the Revolving Credit Exposures of all Lenders exceeding the total Commitments. Within the foregoing limits and subject to the terms and conditions set forth herein, the Borrower may borrow, prepay and reborrow Revolving Loans.
To request a Revolving Borrowing, the Borrower shall notify the Administrative Agent of such request by telephone (a) in the case of a Eurodollar Revolving Borrowing, not later than 12:00 noon, New York, New York time, three Business Days before the date of the
proposed Borrowing, or (b) in the case of an ABR Borrowing, not later than
12:00 noon, New York, New York time, one Business Day before the date of the
proposed Borrowing. Each such telephonic Borrowing Request shall be irrevocable
and shall be confirmed promptly by hand delivery or telecopy to the
Administrative Agent of a written Borrowing Request in the form attached hereto
as Exhibit B and signed by the Borrower. Each such telephonic and written
Borrowing Request shall specify the following information in compliance with
Section 2.02:
(i) the aggregate amount of the requested Borrowing;
(ii) the date of such Borrowing, which shall be a
Business Day;
(iii) whether such Borrowing is to be an ABR
Borrowing or a Eurodollar Borrowing;
(iv) in the case of a Eurodollar Borrowing, the initial Interest Period to be applicable thereto, which shall be a period contemplated by the definition of the term "Interest Period"; and
(v) the location and number of the Borrower's account to which funds are to be disbursed, which shall comply with the requirements of Section 2.04.
If no election as to the Type of Revolving Borrowing is specified, then the requested Revolving Borrowing shall be an ABR Borrowing. If no Interest Period is specified with respect to any Eurodollar Revolving Borrowing, then the Borrower shall be deemed to have selected an Interest Period of one month's duration. Promptly following receipt of a Borrowing Request in accordance with this Section, the Administrative Agent shall advise each Lender of the details thereof and of the amount of such Lender's Loan to be made as part of the requested Borrowing.
Agent forthwith on demand such corresponding amount with interest thereon, for
each day from and including the date such amount is made available to the
Borrower to but excluding the date of payment to the Administrative Agent, at
(i) in the case of such Lender, the Federal Funds Effective Rate or (ii) in the
case of the Borrower, the interest rate applicable to the Loans of such
Borrowing. If such Lender pays such amount to the Administrative Agent, then
such amount shall constitute such Lender's Loan included in such Borrowing.
(i) the Borrowing to which such Interest Election applies and, if different options are being elected with respect to different portions thereof, the portions thereof to be allocated to each resulting Borrowing (in which case the information to be specified pursuant to clauses (iii) and (iv) of this paragraph shall be specified for each resulting Borrowing);
(ii) the effective date of the election made pursuant to such Interest Election Request, which shall be a Business Day;
(iii) whether the resulting Borrowing is to be an ABR Borrowing or a Eurodollar Borrowing; and
(iv) if the resulting Borrowing is a Eurodollar Borrowing, the Interest Period to be applicable thereto after giving effect to such election, which shall be a period contemplated by the definition of the term "Interest Period".
If any such Interest Election Request requests a Eurodollar Borrowing but does not specify an Interest Period, then the Borrower shall be deemed to have selected an Interest Period of one month's duration.
(x) if Lenders having Commitments totaling an amount
equal to at least 51% of the aggregate amount of the
Commitments then in effect do not agree as contemplated by
Section 2.06(e)(i), then the Revolving Termination Date shall
not be extended pursuant to this Section 2.06(e) and the
Commitments of all of the Lenders shall remain in effect until
the Revolving Termination Date except as otherwise provided in
this Agreement; and
(y) the Borrower may not request any extension of the Revolving Termination Date pursuant to this Section 2.06(e)(i) more frequently than once in any calendar year.
(ii) Any Loan by any Lender the Commitment of which is to terminate pursuant to Section 2.06(e)(i) hereof that would otherwise be made or converted by such Lender as a Eurodollar Loan having an Interest Period ending after the date such Commitment is to terminate shall be made or continued as an ABR Loan and all ABR Loans of such Lender that would otherwise be converted into Eurodollar Loans having such Interest Periods shall remain as ABR Loans.
(iii) It shall be a condition precedent to any
extension of the Revolving Termination Date that: (a) on the date of such
extension no Default or Event of Default shall have occurred and be continuing;
(b) the representations and warranties made by the Borrower in Article III
shall be true and correct on and as of the date of such extension (or if any
such
representation or warranty is expressly stated to have been made as of a specific date, as of such specific date); and (c) on the date of such extension there shall have been no material adverse change in the consolidated financial condition, operations, business or prospects taken as a whole of the Borrower and its Subsidiaries from that set forth in its financial statements as of September 30, 2001 referred to in Section 3.06 hereof or, if the Borrower has delivered its financial statements for any fiscal year to the Lenders and the Administrative Agent pursuant to Section 5.01(a) hereof, as of the date of the most recent such financial statements. Each request for an extension of the Revolving Termination Date pursuant to Section 2.06(e) shall constitute a certification by the Borrower to the effect set forth in the preceding sentence (both as of the date of such request and, unless the Borrower notifies the Administrative Agent prior to the date of such extension, as of the date of such extension).
(a) the Administrative Agent determines (which determination shall be conclusive, absent manifest error) that adequate and reasonable means do not exist for ascertaining the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period; or
(b) the Administrative Agent is advised by the Required Lenders that the Adjusted LIBO Rate or the LIBO Rate, as applicable, for such Interest Period will not adequately and fairly reflect the cost to such Lenders (or Lender) of making or maintaining their Loans (or its Loan) included in such Borrowing for such Interest Period;
then the Administrative Agent shall give notice thereof to the Borrower and the Lenders by telephone or telecopy as promptly as practicable thereafter and, until the Administrative Agent
notifies the Borrower and the Lenders that the circumstances giving rise to such notice no longer exist, (i) any Interest Election Request that requests the conversion of any Borrowing to, or continuation of any Borrowing as, a Eurodollar Borrowing shall be ineffective, and (ii) if any Borrowing Request requests a Eurodollar Revolving Borrowing, such Borrowing shall be made as an ABR Revolving Borrowing.
(i) impose, modify or deem applicable any reserve, special deposit or similar requirement against assets of, deposits with or for the account of, or credit extended by, any Lender or its Parent (except any such reserve requirement reflected in the Adjusted LIBO Rate); or
(ii) impose on any Lender or its Parent or the London interbank market any other condition affecting this Agreement or Eurodollar Loans made by such Lender;
and the result of any of the foregoing shall be to increase the cost to such Lender or its Parent of making or maintaining any Eurodollar Loan (or of maintaining its obligation to make any such Loan) or to reduce the amount of any sum received or receivable by such Lender hereunder (whether of principal, interest or otherwise), then the Borrower will pay to such Lender such additional amount or amounts as will compensate such Lender or its Parent, as the case may be, for such additional costs incurred or reduction suffered.
convert, continue or prepay any Revolving Loan on the date specified in any notice delivered pursuant hereto (regardless of whether such notice is permitted to be revocable under Section 2.08(b) and is revoked in accordance herewith), or (d) the assignment of any Eurodollar Loan other than on the last day of the Interest Period applicable thereto as a result of a request by the Borrower pursuant to Section 2.16, then, in any such event, the Borrower shall compensate each Lender for the loss, cost and expense attributable to such event. In the case of a Eurodollar Loan, the loss to any Lender attributable to any such event shall be deemed to include an amount determined by such Lender to be equal to the excess, if any, of (i) the amount of interest that such Lender would pay for a deposit equal to the principal amount of such Loan for the period from the date of such payment, conversion, failure or assignment to the last day of the then current Interest Period for such Loan (or, in the case of a failure to borrow, convert or continue, the duration of the Interest Period that would have resulted from such borrowing, conversion or continuation) if the interest rate payable on such deposit were equal to the Adjusted LIBO Rate for such Interest Period, over (ii) the amount of interest that such Lender would earn on such principal amount for such period if such Lender were to invest such principal amount for such period at the interest rate that would be bid by such Lender (or an Affiliate of such Lender) for dollar deposits from other banks in the eurodollar market at the commencement of such period. A certificate of any Lender setting forth any amount or amounts that such Lender is entitled to receive pursuant to this Section shall be delivered to the Borrower and shall be conclusive, absent manifest error. The Borrower shall pay such Lender the amount shown as due on any such certificate within 10 days after receipt thereof.
the Borrower by a Lender, a Co-Lead Arranger, the Syndication Agent or the Administrative Agent (on its own behalf or on behalf of a Lender, a Co-Lead Arranger or the Syndication Agent) shall be conclusive, absent manifest error.
the amount of the Commitments under Section 2.06 shall be applied to the respective Commitments of the Lenders, pro rata according to the amounts of their respective Commitments; (ii) each Borrowing shall be allocated pro rata among the Lenders according to the amounts of their respective Commitments (in the case of the making of Revolving Loans) or their respective Loans (in the case of conversions and continuations of Loans); (iii) each payment or prepayment of principal of Loans by the Borrower shall be made for the account of the Lenders pro rata in accordance with the respective unpaid principal amounts of the Loans held by them; and (iv) each payment of interest on Loans by the Borrower shall be made for the account of the Lenders pro rata in accordance with the amounts of interest on such Loans then due and payable to the respective Lenders.
Lender to satisfy such Lender's obligations under such Sections until all such unsatisfied obligations are fully paid.
ARTICLE III
REPRESENTATIONS AND WARRANTIES
The Borrower hereby represents and warrants to the Administrative Agent and each Lender as follows:
The Borrower and each Subsidiary of the Borrower is a corporation, trust or limited liability company duly organized, validly existing and in good standing under the Laws
of its jurisdiction of organization. The Borrower and each Subsidiary of the Borrower has the power (corporate or otherwise) and authority to own its Property and to transact the business in which it is engaged or presently proposes to engage. The Borrower and each Subsidiary of the Borrower is duly qualified to do business as a foreign corporation, trust or limited liability company and is in good standing in all jurisdictions in which the ownership of its Properties or the nature of its activities or both makes such qualification necessary or advisable. Schedule II states as of the date hereof the jurisdiction of organization of the Borrower and each Subsidiary of the Borrower, and the jurisdictions in which the Borrower and each Subsidiary of the Borrower is qualified to do business as a foreign corporation, trust or limited liability company.
The Borrower has the corporate power and authority to execute, deliver, perform, and take all actions contemplated by this Agreement and each of the other Loan Documents to which it is a party, and all such actions have been duly and validly authorized by all necessary corporate proceedings on its part. Without limiting the foregoing, the Borrower has the corporate power and authority to borrow pursuant to the Loan Documents to the fullest extent permitted hereby and thereby from time to time, and has taken all necessary corporate action to authorize such borrowings.
This Agreement and each of the other Loan Documents to which the Borrower is a party and which is required to be delivered on or before the Effective Date pursuant to Section 4.01 has been duly and validly executed and delivered by the Borrower. This Agreement and each such other Loan Document constitutes, and when executed and delivered by the Borrower will constitute, the legal, valid and binding obligation of the Borrower, enforceable against the Borrower in accordance with its terms, except as the enforceability hereof or thereof may be limited by bankruptcy, insolvency or other similar laws of general application affecting the enforcement of creditors' rights or by general principles of equity limiting the availability of equitable remedies.
The Public Utilities Commission of Nevada and the California Public Utilities Commission have each duly and validly issued orders authorizing the Borrower to enter into this Agreement and the other Loan Documents to which it is a party and to take all actions contemplated hereby or thereby or in connection herewith or therewith, and such orders remain in full force and effect in the form issued. No other Governmental Action is required for the due execution, delivery and performance by the Borrower of this Agreement or any of the other Loan Documents to which it is a party.
Neither the execution and delivery of any of the Loan Documents by the Borrower, nor the consummation of the transactions herein or therein contemplated by the Borrower, nor the performance of or the compliance with the terms and conditions hereof or thereof by the Borrower, does or will:
(a) violate or conflict with any Law; or
(i) the articles of incorporation or by-laws (or other constituent documents) of the Borrower or any Subsidiary of the Borrower;
(ii) any agreement or instrument creating, evidencing or securing any Indebtedness to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound; or
(iii) any other material agreement or instrument to which the Borrower or any Subsidiary of the Borrower is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders consolidated balance sheets of the Borrower and its consolidated Subsidiaries as of December 31, 1998, 1999 and 2000 and the related consolidated statements of income, retained earnings and changes in cash flows for the fiscal years then ended, as examined and reported on by independent certified public accountants for the Borrower, who delivered an unqualified opinion in respect thereof. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of each such fiscal year and the results of their operations and their retained earnings and changes in cash flows for the fiscal years then ended, all in conformity with GAAP.
The Borrower has heretofore furnished to each of the Agents and each of the Lenders an interim consolidated balance sheet of the Borrower and its consolidated Subsidiaries as of the end of the third fiscal quarter of the fiscal year beginning January 1, 2001, together with the related consolidated statements of income, retained earnings and changes in cash flows for the applicable fiscal period ending on such date. Such financial statements (including the notes thereto) present fairly the financial condition of the Borrower and its consolidated Subsidiaries as of the end of such fiscal quarter and the results of their operations and their retained earnings and changes in cash flows for the fiscal periods then ended, all in conformity with GAAP, subject to normal and recurring year-end audit adjustments.
Neither the Borrower nor any Subsidiary of the Borrower has
any liability or obligation of any nature whatever (whether absolute, accrued,
contingent or otherwise, whether or not due), forward or long-term commitments
or unrealized or anticipated losses from unfavorable commitments, except (a) as
disclosed in the financial statements referred to in Sections 3.06 and 3.07, and
(b) liabilities, obligations, commitments and losses incurred after September
30, 2001, in the ordinary course of business and consistent with past practices.
Since September 30, 2001, there has been no material adverse change in the business, operations, condition (financial or otherwise), or prospects of the Borrower and its Subsidiaries taken as a whole.
All information heretofore, contemporaneously or hereafter provided by or on behalf of the Borrower to any Agent or any Lender pursuant to or in connection with any Loan Document or any transaction contemplated hereby or thereby is or will be (as the case may be) true and accurate in all material respects on the date as of which such information is dated (or, if not dated, when received by such Agent or such Lender) and does not or will not (as the case may be) omit to state any material fact necessary to make such information not misleading at such time in light of the circumstances in which it was provided. The Borrower has disclosed to each Agent and each Lender in writing every fact or circumstance which has, or which so far as the Borrower can reasonably foresee is reasonably likely and is reasonably likely to have, a Material Adverse Effect.
No part of the proceeds of any Loan hereunder will be used for the purpose of buying or carrying any "margin stock", as such term is used in Regulation U of the Board, as amended from time to time, or to extend credit to others for the purpose of buying or carrying any "margin stock". Neither the Borrower nor any Subsidiary of the Borrower is engaged in the business of extending credit to others for the purpose of buying or carrying "margin stock". Neither the Borrower nor any Subsidiary of the Borrower owns any "margin stock". Neither the making of any Loan nor any use of proceeds of any such Loan will violate or conflict with the provisions of Regulation T, U or X of the Board, as amended from time to time.
There is no pending or (to the Borrower's knowledge after due inquiry) threatened action, suit, proceeding or investigation (including any Environmental Claim) by or before any Governmental Authority against or affecting the Borrower or any Subsidiary of the Borrower which, if adversely decided, individually or in the aggregate, would reasonably be expected to have a Material Adverse Effect, except for (a) matters described in the financial statements referred to in Section 3.06 and (b) matters set forth in Schedule III.
No event has occurred and is continuing and no condition exists which constitutes a Default or an Event of Default.
Neither the Borrower nor any Subsidiary of the Borrower is in violation of or conflict with, or is subject to any contingent liability on account of any violation of or conflict with:
(a) any Law (including ERISA, the Code, any applicable occupational health, safety or welfare Law or any applicable Environmental Law);
(b) its articles of incorporation or by-laws (or other constituent documents); or
(c) any agreement or instrument to which it is party or by which it or any of its properties (now owned or hereafter acquired) may be subject or bound;
except for matters which, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.
The Borrower and each Subsidiary of the Borrower maintains with financially sound and reputable insurers insurance with respect to its properties and business and against at least such liabilities, casualties and contingencies and in at least such types and amounts as is customary in the case of corporations engaged in the same or a similar business or having similar properties similarly situated.
The Borrower and each Subsidiary of the Borrower has good and
marketable title in fee simple to all real Property owned or purported to be
owned by it and good title to all other Property of whatever nature owned or
purported to be owned by it, including but not limited to all Property reflected
in the most recent audited balance sheet referred to in Section 3.06 or
submitted pursuant to Section 5.01(b), as the case may be (except as sold or
otherwise disposed of in the ordinary course of business after the date of such
balance sheet), subject to no Liens except for (i) Liens reflected in the most
recent audited balance sheet referred to in Section 3.06 or submitted pursuant
to Section 5.01(b), as the case may be, (ii) Liens consisting of zoning or
planning restrictions, easements, permits and other restrictions or limitations
on the use of real Property or irregularities in title thereto which do not
materially detract from the value of, or impair the use of, such Property by the
Borrower or any Subsidiary of the Borrower in the operation of its business,
(iii) Liens for current Taxes not yet due and delinquent and (iv) Liens set
forth on Schedule IV.
All tax and information returns required to be filed by or on behalf of the Borrower or any Subsidiary of the Borrower have been properly prepared, executed and filed. All Taxes upon the Borrower or any Subsidiary of the Borrower or upon any of their respective Properties, incomes, sales or franchises which are due and payable have been paid, other than those not yet delinquent and payable without premium or penalty, and except for those being diligently contested in good faith by appropriate proceedings, and in each case for which adequate reserves and provisions for Taxes have been made on the books of the Borrower and each Subsidiary of the Borrower. The reserves and provisions for Taxes on the books of the Borrower and each Subsidiary of the Borrower are adequate for all open years and for its current fiscal period. Neither the Borrower nor any Subsidiary of the Borrower knows of any proposed additional assessment or basis for any material assessment for additional Taxes (whether or not reserved against).
Neither the Borrower nor any Subsidiary of the Borrower is an "investment company" or a company controlled by an "investment company" within the meaning of the Investment Company Act of 1940.
(a) The Borrower and each of its Subsidiaries have complied with and are in compliance with all applicable Environmental Laws and the requirements of any permits issued under such Environmental Laws. Except as disclosed on Schedule V, there are no pending or threatened Environmental Claims against the Borrower or any of its Subsidiaries (including any such claim arising out of the ownership, lease or operation by the Borrower or any of its Subsidiaries of any real Property no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries. Except as disclosed on Schedule V, there are no facts, circumstances, conditions or occurrences with respect to the business or operations of the Borrower or any of its Subsidiaries, or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries (including any real Property formerly owned, leased or operated by the Borrower or any of its Subsidiaries but no longer owned, leased or operated by the Borrower or any of its Subsidiaries) or any Property adjoining or adjacent to any such real Property that could be expected (i) to form the basis of an Environmental Claim against the Borrower or any of its Subsidiaries or any real Property owned, leased or operated by the Borrower or any of its Subsidiaries or (ii) to cause any real Property owned, leased or operated by the Borrower or any of its Subsidiaries to be subject to any restrictions on the ownership, occupancy or transferability of such real Property by the Borrower or any of its Subsidiaries under any applicable Environmental Law.
(b) Hazardous Materials have not at any time been generated, used, treated or stored on, or transported to or from, any real Property owned, leased or operated by the Borrower or any of its Subsidiaries where such generation, use, treatment or storage has violated or could be expected to violate any Environmental Law. Hazardous Materials have not at any time been Released on or from any real Property owned, leased or operated by the Borrower or any of its
Subsidiaries where such Release has violated or would be expected to violate any applicable Environmental Law.
(c) Notwithstanding anything to the contrary in this Section, the representations made in this Section shall not be untrue unless the effect of all violations, claims, restrictions, failures and noncompliances of the types described in this Section would reasonably be expected to, individually or in the aggregate, have a Material Adverse Effect.
(a) Each Plan (and each related trust, insurance contract or fund) is in substantial compliance with its terms and with all applicable Laws, including without limitation ERISA and the Code; each Plan (and each related trust, if any) which is intended to be qualified under Section 401(a) of the Code has received a determination letter from the Internal Revenue Service to the effect that it meets the requirements of Sections 401(a) and 501(a) of the Code; no Reportable Event has occurred; no Multiemployer Plan is insolvent or in reorganization; no Plan has an Unfunded Current Liability; no Plan which is subject to Section 412 of the Code or Section 302 of ERISA has an accumulated funding deficiency within the meaning of such sections of the Code or ERISA or has applied for or received a waiver of an accumulated funding deficiency or an extension of any amortization period within the meaning of Section 412 of the Code or Section 303 or 304 of ERISA; all contributions required to be made with respect to a Plan have been timely made; neither the Borrower nor any Subsidiary of the Borrower nor any ERISA Affiliate has incurred any material liability (including any indirect, contingent or secondary liability) to or on account of a Plan pursuant to Section 409, 502(i), 502(l), 515, 4062, 4063, 4064, 4069, 4201, 4204 or 4212 of ERISA or Section 401(a)(29), 4971 or 4975 of the Code or expects to incur any such liability under any of the foregoing sections with respect to any Plan; no condition exists which presents a material risk to the Borrower or any Subsidiary of the Borrower or any ERISA Affiliate of incurring a liability to or on account of a Plan pursuant to the foregoing provisions of ERISA and the Code; no proceedings have been instituted to terminate or appoint a trustee to administer any Plan; no action, suit, proceeding, hearing, audit or investigation with respect to the administration, operation or the investment of assets of any Plan (other than routine claims for benefits) is pending, expected or threatened; using actuarial assumptions and computation methods consistent with Part 1 of subtitle E of Title IV of ERISA, the aggregate liabilities of the Borrower and its Subsidiaries and its ERISA Affiliates to all Multiemployer Plans in the event of a complete withdrawal therefrom, as of the close of the most recent fiscal year of each such Plan ended prior to the date of the most recent Borrowing, would not have a Material Adverse Effect; each group health plan (as defined in Section 607(1) of ERISA or Section 4980B(g)(2) of the Code) which covers or has covered employees or former employees of the Borrower, any Subsidiary of the Borrower, or any ERISA Affiliate has at all times been operated in compliance with the provisions of Part 6 of subtitle B of Title I of ERISA and Section 4980B of the Code; no Lien imposed under the Code or ERISA on the assets of the Borrower or any Subsidiary of the Borrower or any ERISA Affiliate exists or is likely to arise on account of any Plan; and the Borrower and its Subsidiaries may cease contributions to or terminate any Plan maintained by any of them without incurring any material liability.
(b) Each Foreign Pension Plan, if any, has been maintained in substantial compliance with its terms and with the requirements of any and all applicable Laws, statutes,
rules, regulations and orders and has been maintained, where required, in good standing with applicable regulatory authorities. All contributions required to be made with respect to a Foreign Pension Plan have been timely made. Neither the Borrower nor any of its Subsidiaries has incurred any obligation in connection with the termination of or withdrawal from any Foreign Pension Plan. The present value of the accrued benefit liabilities (whether or not vested) under each Foreign Pension Plan, determined as of the end of the Borrower's most recently ended fiscal year on the basis of actuarial assumptions, each of which is reasonable, did not exceed the current value of the assets of such Foreign Pension Plan allocable to such benefit liabilities.
The claims and rights of the Lenders against the Borrower hereunder are not subordinated to, but rank at least pari passu with, the claims and rights of other holders of its unsecured indebtedness except to the extent otherwise provided by Law (including, without limitation, the Bankruptcy Code and the provisions of 31 U.S.C. [sec]. 3713).
Upon any issuance of General and Refunding Mortgage Bonds pursuant to Section 6.09(b) and at all times thereafter, such General and Refunding Mortgage Bonds will have been duly and validly issued and will be entitled to the security and benefits of the General and Refunding Mortgage Indenture; will be secured equally and ratably with and only with all other bonds issued and outstanding under the General and Refunding Mortgage Indenture; will be secured by direct and valid, duly perfected Liens on and security interests in the collateral purported to secure such bonds in the General and Refunding Mortgage Indenture, subject only to the prior Lien of the First Mortgage Indenture and to Permitted Liens (as such term is defined in the General and Refunding Mortgage Indenture); and will constitute collateral security for the obligations of the Borrower as purported to be provided in the General and Refunding Mortgage Indenture and herein.
ARTICLE IV
CONDITIONS
This Agreement and the other Loan Documents shall become effective as against the Lenders and the Agents on the first date on which all of the following conditions shall be satisfied or waived:
and, to the extent any Lender has requested a Note pursuant to Section 2.07(f), a Note conforming to the requirements hereof, duly executed on behalf of the Borrower.
(i) Each of the representations and warranties made by the Borrower herein and in each other Loan Document shall be true and correct in all material respects on and as of the Effective Date as if made on and as of such date, both before and after giving effect to the Loans requested to be made on such date.
(ii) No Default or Event of Default shall have occurred and be continuing on the Effective Date.
The obligation of each Lender to make, convert or continue any Loan on the occasion of any Borrowing is subject to satisfaction of the conditions precedent set forth in Section 4.01 and satisfaction of the following further conditions precedent:
Each request by the Borrower for any Loan or conversion or continuation thereof shall constitute a representation and warranty by the Borrower that the conditions set forth in this Section 4.02 have been satisfied as of the date of such request. Failure of the Administrative Agent to receive notice from the Borrower to the contrary before such Loan is made shall constitute a further representation and warranty by the Borrower that the conditions referred to in this Section 4.02 have been satisfied as of the date such Loan is made.
ARTICLE V
AFFIRMATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender:
the corresponding figures for the preceding fiscal year. Such financial
statements shall be accompanied by an opinion of independent certified public
accountants of recognized national standing selected by the Borrower, which
opinion shall not be subject to any qualification as to scope of audit or as to
any other matter which the Required Lenders determine is adverse. Such opinion
in any event shall contain a written statement of such accountants
substantially to the effect that (i) such accountants examined such financial
statements in accordance with generally accepted auditing standards and
accordingly made such tests of accounting records and such other auditing
procedures as such accountants considered necessary in the circumstances and
(ii) in the opinion of such accountants such financial statements present
fairly the financial position of the Borrower and its consolidated Subsidiaries
as of the end of such fiscal year and the results of their operations and their
retained earnings and cash flows for such fiscal year, in conformity with GAAP.
(i) Any Default or Event of Default.
(ii) The occurrence or existence of any event or condition
(including (A) the violation or alleged violation of any Environmental
Law by the Borrower or any Subsidiary of the Borrower or the assertion
of any Environmental Claim against the Borrower or any Subsidiary of
the Borrower, (B) the commencement of any other action, suit,
proceeding or investigation by or before any Governmental Authority
against or affecting the Borrower or any Subsidiary of the Borrower, or
(C) the violation, breach or default or alleged violation, breach or
default by the Borrower or any Subsidiary of the Borrower or any other
Person under any agreement or instrument material to the business,
operations, condition (financial or otherwise) or prospects of the
Borrower and its Subsidiaries taken as a whole) which event or
condition, either individually or in the aggregate, has, or would
reasonably be expected to have, a Material Adverse Effect.
(iii) Any change in the rating of the Index Debt of Borrower.
(i) any Reportable Event and any request for a waiver under Section 412(d) of the Code for any Plan;
(ii) the distribution under Section 4041 of ERISA of a notice of intent to terminate any Plan or any action taken by the Borrower or an ERISA Affiliate to terminate any Plan, in each case with respect to which there are insufficient assets to pay benefits as they become due;
(iii) the institution by the PBGC of proceedings under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan, or the receipt by the Borrower or any ERISA Affiliate of a notice from a Multiemployer Plan that such action has been taken by the PBGC with respect to such Multiemployer Plan;
(iv) the complete or partial withdrawal from a Multiemployer Plan by the Borrower or any ERISA Affiliate that results in liability under Section 4201 or 4204 of ERISA (including the obligation to satisfy secondary liability as a result of a purchaser default) or the receipt by the Borrower or any ERISA Affiliate of notice from a Multiemployer Plan that it is in reorganization or insolvency pursuant to Section 4241 or 4245 of ERISA or that it intends to terminate or has terminated under Section 4041A of ERISA; and
(v) the adoption of an amendment to any Plan that, pursuant to Section 401(a)(29) of the Code or Section 307 of ERISA, would result in the loss of tax-exempt status of the trust of which such Plan is a part if the Borrower or an ERISA Affiliate fails to timely provide security to the Plan in accordance with the provisions of said Sections.
The Borrower shall, and shall cause each of its Subsidiaries to, maintain with financially sound and reputable insurers insurance with respect to its properties and business and against such liabilities, casualties and contingencies and of such types and in such amounts as is customary in the case of corporations engaged in the same or similar businesses or having similar properties similarly situated and as is satisfactory from time to time to the Required Lenders in their reasonable discretion.
The Borrower shall, and shall cause each of its Subsidiaries to, pay or discharge
(a) on or prior to the date on which penalties or Liens attach thereto, all Taxes imposed upon it or any of its Properties;
(b) on or prior to the date when due, all lawful claims of materialmen, mechanics, carriers, warehousemen, landlords and other like Persons which, if unpaid, might result in the creation of a Lien upon any such Property; and
(c) on or prior to the date when due, all other lawful claims which, if unpaid, might result in the creation of a Lien upon any such Property or which, if unpaid, might give rise to a claim entitled to priority over general creditors of the Borrower or such Subsidiary in a case under the Bankruptcy Code;
The Borrower shall keep and maintain in full force and effect all Governmental Actions necessary or advisable in connection with execution and delivery of any Loan Document, consummation of the transactions herein or therein contemplated, performance of or compliance with the terms and conditions hereof or thereof or to ensure the legality, validity, binding effect or enforceability hereof or thereof.
The Borrower shall, and shall cause each of its Subsidiaries to, maintain or cause to be maintained in good repair, working order and condition the properties now or hereafter owned, leased or otherwise possessed by it and shall make or cause to be made all needful and proper repairs, renewals, replacements and improvements thereto so that the business carried on in connection therewith may be properly and advantageously conducted at all times.
The Borrower shall not, and shall not permit any of its Subsidiaries to, violate or conflict with, be in violation of or in conflict with, or be or remain subject to any liability (contingent or otherwise) on account of any violation or conflict with:
(a) any Law;
(b) its articles of incorporation or by-laws; or
(c) any agreement or instrument to which it or any of its Subsidiaries is a party or by which any of them or any of their respective properties (now owned or hereafter acquired) may be subject or bound,
except for matters which would not reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
The Borrower shall, and shall cause each of its Subsidiaries to, make and keep books, records and accounts which, in reasonable detail, accurately and fairly reflect its transactions and dispositions of its assets and maintain a system of internal accounting controls sufficient to provide reasonable assurances that (a) transactions are executed in accordance with management's general or specific authorization, (b) transactions are recorded as necessary (i) to permit preparation of financial statements in conformity with GAAP and (ii) to maintain accountability for assets, (c) access to assets is permitted only in accordance with management's general or specific authorization and (d) the recorded accountability for assets is compared with the existing assets at reasonable intervals and appropriate action is taken with respect to any differences.
The Borrower shall apply the proceeds of all Loans hereunder only for working capital and general corporate purposes of the Borrower, including commercial paper backup. The Borrower shall not use the proceeds of any Loans hereunder directly or indirectly for any unlawful purpose, in any manner inconsistent with Section 3.11, or inconsistent with any other provision of any Loan Document.
The Borrower shall cause (a) each of its, and each of its Subsidiary's, fiscal years to end on December 31 and (b) each of its, and each of its Subsidiary's, fiscal quarters to end on March 31, June 30, September 30 and December 31.
ARTICLE VI
NEGATIVE COVENANTS
The Borrower hereby covenants to the Administrative Agent and each Lender as follows:
Fiscal Quarter Ended Period -------------------- ------ December 31, 2001 the three consecutive fiscal quarters ended as of the lastday of such fiscal quarter March 31, 2002 and each the four consecutive fiscal quarter ended thereafter fiscal quartersended as of the last day of such fiscal quarter |
(a) Liens existing on the date hereof and securing obligations existing on the date hereof, as such Liens and obligations are listed on Schedule IV;
(d) Liens on "transition property" arising pursuant to
Section 843 of the California Public Utility Code for the benefit of
holders of rate reduction bonds issued pursuant to a valid financing
order of the California Public Utilities Commission;
(e) Liens arising from taxes, assessments, charges or claims described in Section 5.03 that are not yet due or that remain payable without penalty or to the extent permitted to remain unpaid under the proviso to such Section 5.03;
(f) Deposits or pledges of cash or securities in the ordinary course of business to secure (i) worker's compensation, unemployment insurance or other social security obligations, (ii) performance of bids, tenders, trade contracts (other than for payment of money) or leases, (iii) stay, surety or appeal bonds, or (iv) other obligations of a like nature incurred in the ordinary course of business;
(g) Zoning restrictions, easements, minor restrictions on the use of real Property, minor irregularities in title thereto and other minor Liens that do not secure the payment of money or the performance of an obligation and that do not in the aggregate materially detract from the value of an asset to, or materially impair its use in the business of, the Borrower or such Subsidiary; and
"Permitted Liens" shall in no event include any Lien imposed by, or required to be granted pursuant to, ERISA or any Environmental Law.
The Borrower shall not, and shall not permit any of its
Subsidiaries to, (a) merge with or into or consolidate with any other Person,
(b) liquidate, wind-up, dissolve or divide, or (c) agree, become or remain
liable (contingently or otherwise) to do any of the foregoing, except that:
Prior to the making of any Investment or the consummation of any Acquisition by the Borrower or any of its Subsidiaries, the amount or purchase price of which, as the case may be, when aggregated with the amounts and purchase prices of other Investments and Acquisitions made by the Borrower and its Subsidiaries, would exceed $10,000,000 in the aggregate at any time, the Borrower shall deliver to the Administrative Agent (i) a certificate, in a form reasonably satisfactory to the Administrative Agent, certifying that no Default or Event of Default exists or will result from such Acquisition and (ii) pro forma financial statements in support of such certification.
The Borrower shall not enter into any transaction of any kind with any Person that Controls the Borrower or is Controlled by the Borrower or is under common Control with the Borrower other than (a) salary, bonus, employee stock option and other compensation arrangements with directors or officers in the ordinary course of business, (b) transactions that are fully disclosed to the board of directors (or executive committee thereof) of the Borrower and expressly authorized by a resolution of the board of directors (or executive committee) of the Borrower which is approved by a majority of the directors (or executive committee) not having an interest in the transaction, (c) transactions between or among the Borrower and its Wholly-Owned Subsidiaries, (d) transactions between the Borrower and its Subsidiaries, on the one hand, and NPC and its Subsidiaries, on the other hand, and (e) transactions on overall terms at least as favorable to the Borrower as would be the case in an arm's-length transaction between unrelated parties of equal bargaining power.
The Borrower shall not engage in any business other than the businesses of (a) the generation or purchase of electrical power and (b) the purchase of natural gas, and in each case the transmission and distribution thereof to industrial, commercial and residential customers. In addition to, and not by way of limitation of, the previous sentence, the Borrower shall maintain ongoing business segments (as defined in FASB Statement 131 - Disclosure about Segments of an Enterprise and Related Information) consisting of electricity and gas assets (exclusive of cash and readily marketable securities) and operating income reflected in the financial statements of the Borrower as being directly attributable to the generation, transmission and/or distribution of
electricity or gas, which segments and operating income shall, in the aggregate, comprise not less than 80% of the consolidated assets (exclusive of cash and readily marketable securities) of the Borrower and its Subsidiaries.
(a) If, notwithstanding the prohibition contained in Section 6.02, the Borrower or any of its Subsidiaries is subjected to any Lien upon any of its Property, other than those permitted by the provisions of Section 6.02, the Borrower will, and will cause its Subsidiaries to, make or cause to be made effective provisions whereby the Borrowings will be secured equally and ratably with any and all other obligations thereby secured, such security to be pursuant to agreements reasonably satisfactory to the Administrative Agent and, in any such case, the Borrowings shall have the benefit, to the fullest extent that, and with such priority as, the Lenders may be entitled under applicable law, of an equitable Lien on such Property. Such violation of Section 6.02 will constitute an Event of Default, whether or not provision is made for an equal and ratable Lien pursuant to this Section 6.09, and no such Lien or agreements with respect thereto shall be deemed to be a waiver of or consent to such Event of Default by the Administrative Agent or any Lender.
(x) Moody's shall rate the Index Debt of Borrower as Baa3 or lower; or
(y) S&P shall rate the Index Debt of Borrower as BB+ or lower;
then the Borrower shall issue or cause to be issued, not later than five (5) Business Days after the date on which the Triggering Event first occurs, for the ratable benefit of the Lenders, General and Refunding Mortgage Bonds, to the full extent permitted under applicable orders of the Public Utilities Commission of Nevada and the General and Refunding Mortgage Indenture, in an aggregate face amount equal to the aggregate amount of the Commitments (but with an aggregate outstanding principal amount equal to the amount of principal of the Loans outstanding from time to time), with interest and other terms and conditions substantially similar to the Loans, and the Borrower shall perform or cause to be performed all acts, and execute or cause to be executed all resolutions, orders, instruments, certificates, agreements and other documents required under the General and Refunding Mortgage Indenture (including the documents referred to in Section 4.01(p)) to give effect to the foregoing within such five-Business Day period.
Except for agreements referenced in or permitted under this Article VI, the Borrower will not, and will not permit any of its Subsidiaries to, directly or indirectly, enter into, incur or permit to exist any agreement or other arrangement that prohibits, restricts or imposes any condition upon (a) the ability of the Borrower or any of its Subsidiaries to create, incur or permit to exist any Lien upon any of its Property or assets, or (b) the ability of any Subsidiary of the Borrower to pay dividends or other distributions with respect to any shares of its capital stock
or to make or repay loans or advances to the Borrower or any other Subsidiary of the Borrower or to guarantee Indebtedness of the Borrower or any other Subsidiary of the Borrower.
ARTICLE VII
DEFAULTS
(a) The Borrower shall fail to pay when due principal of any Loan.
(b) The Borrower shall fail to pay when due interest on any Loan, any fees, indemnity or expenses, or any other amount due hereunder or under any other Loan Document and such failure shall have continued for a period of three (3) Business Days.
(c) Any representation or warranty made or deemed made by the Borrower in or pursuant to or in connection with any Loan Document, or any statement made by the Borrower in any financial statement, certificate, report, exhibit or document furnished by the Borrower to the Administrative Agent or any Lender pursuant to or in connection with any Loan Document, shall prove to have been false or misleading in any material respect as of the time when made or deemed made (including by omission of material information necessary to make such representation, warranty or statement not misleading).
(d) The Borrower shall default in the performance or observance of any covenant contained in Article VI or any of the covenants contained in Section 5.01(f)(i), 5.09 or 5.10.
(e) The Borrower shall default in the performance or observance of any other covenant, agreement or duty under this Agreement or any other Loan Document and (i) in the case of a default under Section 5.01 (other than as referred to in subsection (f)(i) thereof) such default shall have continued for a period of ten (10) Business Days and (ii) in the case of any other default such default shall have continued for a period of 30 days after notice from the Administrative Agent to the Borrower.
(f) The Borrower or any Subsidiary of the Borrower shall (i) fail to make any payment (x) on account of any Indebtedness aggregating $10,000,000 or more in principal amount or (y) aggregating $10,000,000 or more on any Indebtedness, or any interest or premium thereon, in each case, when due (whether by scheduled maturity, required prepayment, acceleration, demand or otherwise), and, in each case, such failure shall have continued beyond any applicable grace period specified in any agreement or instrument relating to such Indebtedness, or (ii) fail to perform or observe any other term, covenant or condition on its part to be performed or observed under any agreement or instrument relating to any Indebtedness when required to be performed or observed, and such failure shall have continued beyond any applicable grace period specified in any
agreement or instrument relating to such Indebtedness, if the effect of such failure to perform or observe is to accelerate, or to permit the acceleration of, the maturity of such Indebtedness, the unpaid principal amount of which then aggregates $10,000,000 or more.
(g) One or more final judgments or orders for the payment of money shall have been entered against the Borrower or any Subsidiary of the Borrower, which judgments or orders exceed $10,000,000 in the aggregate, and such judgments or orders shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(h) One or more writs or warrants of attachment, garnishment, execution, distraint or similar process exceeding in value the aggregate amount of $10,000,000 shall have been issued against the Borrower or any Subsidiary of the Borrower or any of their respective properties and shall have remained undischarged and unstayed for a period of thirty (30) consecutive days.
(i) Any Governmental Action now or hereafter made by or with any Governmental Authority in connection with any Loan Document is not obtained or shall have ceased to be in full force and effect or shall have been modified or amended or shall have been held to be illegal or invalid, and the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that the consequence of any of the foregoing events would reasonably be expected to have, individually or in the aggregate, a Material Adverse Effect.
(j) Any Loan Document or any material term or provision thereof shall have ceased to be in full force and effect, or the Borrower or any Governmental Authority with jurisdiction over the Borrower shall, or shall purport to, terminate, repudiate, declare voidable or void or otherwise contest, any Loan Document or any material term or provision thereof or any obligation or liability of the Borrower thereunder.
(k) An event or condition specified in Section 5.01(h) hereof shall occur or exist with respect to any Plan or Multiemployer Plan or any Lien arises pursuant to ERISA and, as a result of such event or condition or Lien, together with all other such events or conditions or Liens, the Borrower or any ERISA Affiliate shall incur or shall be reasonably likely to incur a liability to a Plan, a Multiemployer Plan or the PBGC or suffer an encumbrance to exist in favor of any thereof (or any combination of the foregoing) which would constitute a Material Adverse Effect.
(l) The Borrower or any Subsidiary of the Borrower shall have violated any Environmental Law or become subject to any Environmental Claim and, in either case, the Required Lenders shall have determined (which determination shall be conclusive provided it is reached in good faith) that such event would reasonably be expected, either individually or in the aggregate, to have a Material Adverse Effect.
(m) A proceeding shall have been instituted in respect of the Borrower or any Subsidiary of the Borrower:
(i) seeking to have an order for relief entered in respect of such Person, or seeking a declaration or entailing a finding that such Person is insolvent or a similar declaration or finding, or seeking dissolution, winding-up, charter revocation or forfeiture, liquidation, reorganization, arrangement, adjustment, composition or other similar relief with respect to such Person, its assets or its debts under any Law relating to bankruptcy, insolvency, relief of debtors or protection of creditors, termination of legal entities or any other similar Law now or hereafter in effect, or
(ii) seeking appointment of a receiver, trustee, liquidator, assignee, sequestrator or other custodian for such Person or for all or any substantial part of its Property,
and such proceeding shall result in the entry, making or grant of any such order for relief, declaration, finding, relief or appointment, or such proceeding shall remain undismissed and unstayed for a period of thirty (30) consecutive days.
(n) The Borrower or any Subsidiary of the Borrower shall become insolvent; shall fail to pay, become unable to pay, or state that it is or will be unable to pay, its debts as they become due; shall voluntarily suspend transaction of its business; shall make a general assignment for the benefit of creditors; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(i), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such order for relief, declaration, finding or relief described therein; shall institute (or fail to controvert in a timely and appropriate manner) a proceeding described in Section 7.01(m)(ii), or (whether or not any such proceeding has been instituted) shall consent to or acquiesce in any such appointment or to the taking of possession by any such custodian of all or any substantial part of its Property; shall dissolve, wind-up, revoke or forfeit its charter (or other constituent documents) or liquidate itself or any substantial part of its Property; or shall take any action in furtherance of any of the foregoing.
(o) A Change in Control shall occur.
(a) If an Event of Default specified in Section 7.01 (other than subsections (m) and (n) thereof) shall occur and be continuing or shall exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder or under any other Loan Document, at law, in equity or otherwise, the Lenders shall be under no further obligation to make Loans hereunder, and the Administrative Agent may, and, upon the written request of the Required Lenders shall, by notice to the Borrower, from time to time do any or all of the following:
(i) Declare the Commitments terminated, whereupon the Commitments will terminate and any fees hereunder shall be immediately due and
payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(ii) Declare the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations to be immediately due and payable without presentment, demand, protest or further notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
(b) If an Event of Default specified in subsection (m) or (n) of Section 7.01 shall occur or exist, then, in addition to all other rights and remedies which the Administrative Agent or any Lender may have hereunder or under any other Loan Document, at law, in equity or otherwise, the Commitments shall automatically terminate and the Lenders shall be under no further obligation to make Loans, and the unpaid principal amount of the Loans, interest accrued thereon and all other Obligations shall become immediately due and payable without presentment, demand, protest or notice of any kind, all of which are hereby waived, and an action therefor shall immediately accrue.
ARTICLE VIII
THE AGENTS
Each Lender hereby irrevocably appoints Union Bank of California, N.A. to act as Administrative Agent for such Lender under this Agreement and the other Loan Documents. Each Lender hereby irrevocably authorizes the Administrative Agent to take such action on behalf of such Lender under the provisions of this Agreement and the other Loan Documents, and to exercise such powers and to perform such duties, as are expressly delegated to or required of the Administrative Agent by the terms hereof or thereof, together with such powers as are reasonably incidental thereto. Union Bank of California, N.A. hereby agrees to act as Administrative Agent on behalf of the Lenders on the terms and conditions set forth in this Agreement and the other Loan Documents, subject to its right to resign as provided in Section 8.10. Each Lender hereby irrevocably authorizes the Administrative Agent to execute and deliver each of the Loan Documents executed after the date hereof and to accept delivery of such of the other Loan Documents delivered after the date hereof as may not require execution by the Administrative Agent (with such consents of the Lenders as required pursuant to Section 9.01). Each Lender agrees that the rights and remedies granted to the Administrative Agent under the Loan Documents shall be exercised exclusively by the Administrative Agent, and that no Lender shall have any right individually to exercise any such right or remedy, except to the extent expressly provided herein or therein.
Notwithstanding anything to the contrary elsewhere in this Agreement or in any other Loan Document:
(a) The Administrative Agent shall have no duties or responsibilities except those expressly set forth in this Agreement and the other Loan Documents, and no
implied duties or responsibilities on the part of the Administrative Agent shall be read into this Agreement or any other Loan Document or shall otherwise exist.
(b) The duties and responsibilities of the Administrative Agent under this Agreement and the other Loan Documents shall be mechanical and administrative in nature, and the Administrative Agent shall not have a fiduciary relationship in respect of any Lender.
(c) The Administrative Agent is and shall be solely the agent of the Lenders. The Administrative Agent does not assume, and shall not at any time be deemed to have, any relationship of agency or trust with or for, or any other duty or responsibility to, the Borrower or any other Person (except only for its relationship as agent for, and its express duties and responsibilities to, the Lenders as provided in this Agreement and the other Loan Documents).
(d) The Administrative Agent shall be under no obligation to take any action hereunder or under any other Loan Document if the Administrative Agent believes in good faith that taking such action may conflict with any Law or any provision of this Agreement or any other Loan Document, or may require the Administrative Agent to qualify to do business in any jurisdiction where it is not then so qualified.
The Administrative Agent shall take any action of the type
specified in this Agreement or any other Loan Document as being within the
Administrative Agent's rights, powers or discretion in accordance with
directions from the Required Lenders (or, to the extent this Agreement or such
other Loan Document expressly requires the direction or consent of some other
Person or set of Persons, then instead in accordance with the directions of such
other Person or set of Persons). In the absence of such directions, the
Administrative Agent shall have the authority (but under no circumstances shall
be obligated), in its sole discretion, to take any such action, except to the
extent that this Agreement or such other Loan Document expressly requires the
direction or consent of the Required Lenders (or some other Person or set of
Persons), in which case the Administrative Agent shall not take such action
absent such direction or consent. Any action or inaction pursuant to such
direction, discretion or consent shall be binding on all the Lenders. The
Administrative Agent shall not have any liability to any Person as a result of
(a) the Administrative Agent acting or refraining from acting in accordance with
the directions of the Required Lenders (or other applicable Person or set of
Persons), (b) the Administrative Agent refraining from acting in the absence of
instructions to act from the Required Lenders (or other applicable Person or set
of Persons), whether or not the Administrative Agent has discretionary power to
take such action, or (c) the Administrative Agent taking discretionary action it
is authorized to take under this Section (subject, in the case of clauses (b)
and (c), to the provisions of Section 8.04(a)).
Notwithstanding anything to the contrary elsewhere in this Agreement or any other Loan Document:
(a) The Administrative Agent shall not be liable for any action taken or omitted to be taken by it under or in connection with this Agreement or any other Loan Document, unless caused by its own gross negligence or willful misconduct.
(b) The Administrative Agent shall not be responsible for (i) the execution, delivery, effectiveness, enforceability, genuineness, validity or adequacy of this Agreement or any other Loan Document, (ii) any recital, representation, warranty, document, certificate, report or statement in, provided for in, or received under or in connection with, this Agreement or any other Loan Document, (iii) any failure of the Borrower or any Lender to perform any of their respective obligations under this Agreement or any other Loan Document, or (iv) the existence, validity, enforceability, perfection, recordation, priority, adequacy or value, now or hereafter, of any Lien or other direct or indirect security afforded or purported to be afforded by any of the Loan Documents or otherwise from time to time.
(c) The Administrative Agent shall not be under any obligation to ascertain, inquire or give any notice relating to (i) the performance or observance of any of the terms or conditions of this Agreement or any other Loan Document on the part of the Borrower, (ii) the business, operations, condition (financial or otherwise) or prospects of the Borrower or any other Person, or (iii) except to the extent set forth in Section 8.05(f), the existence of any Default or Event of Default.
(d) The Administrative Agent shall not be under any obligation, either initially or on a continuing basis, to provide any Lender with any notices, reports or information of any nature, whether in its possession presently or hereafter, except for such notices, reports and other information expressly required by this Agreement or any other Loan Document to be furnished by the Administrative Agent to such Lender.
(a) The Administrative Agent may rely upon any notice or other communication of any nature (written or oral, including but not limited to telephone conversations, whether or not such notice or other communication is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the proper party or parties, and the Administrative Agent shall not have any duty to verify the identity or authority of any Person giving such notice or other communication.
(b) The Administrative Agent may consult with legal counsel (including, without limitation, in-house counsel for the Administrative Agent or in-house or other counsel for the Borrower), independent public accountants and any other experts selected by it from time to time, and the Administrative Agent shall not be liable for any action taken or omitted to be taken in good faith by it in accordance with the advice of such counsel, accountants or experts.
(c) The Administrative Agent may conclusively rely upon the truth of the statements and the correctness of the opinions expressed in any certificates or opinions furnished to the Administrative Agent in accordance with the requirements of this Agreement or any other Loan Document. Whenever the Administrative Agent shall deem it necessary or desirable that a
matter be proved or established with respect to the Borrower or any Lender, such matter may be established by a certificate of the Borrower or such Lender, as the case may be, and the Administrative Agent may conclusively rely upon such certificate (unless other evidence with respect to such matter is specifically prescribed in this Agreement or another Loan Document).
(d) The Administrative Agent may fail or refuse to take any action unless it shall be indemnified to its satisfaction from time to time against any and all amounts, liabilities, obligations, losses, damages, penalties, actions, judgments, suits, costs, expenses or disbursements of any kind or nature which may be imposed on, incurred by or asserted against the Administrative Agent by reason of taking or continuing to take any such action.
(e) The Administrative Agent may perform any of its duties under this Agreement or any other Loan Document by or through agents or attorneys-in-fact. The Administrative Agent shall not be responsible for the negligence or misconduct of any agents or attorneys-in-fact selected by it with reasonable care.
(f) The Administrative Agent shall not be deemed to have any knowledge or notice of the occurrence of any Default or Event of Default unless the Administrative Agent has received notice from a Lender or the Borrower referring to this Agreement, describing such Default or Event of Default, and stating that such notice is a "notice of default". If the Administrative Agent receives such a notice, the Administrative Agent shall give prompt notice thereof to each Lender.
Each Lender acknowledges as follows:
(a) Neither the Administrative Agent nor any other Lender has made any representations or warranties to it, and no act taken hereafter by the Administrative Agent or any other Lender shall be deemed to constitute any representation or warranty by the Administrative Agent or such other Lender to it.
(b) It has, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it has deemed appropriate, made its own credit and legal analysis and decision to enter into this Agreement and the other Loan Documents.
(c) It will, independently and without reliance upon the Administrative Agent or any other Lender, and based upon such documents and information as it shall deem appropriate at the time, make its own decisions to take or not take action under or in connection with this Agreement and the other Loan Documents.
Each Lender agrees to reimburse and indemnify the Administrative Agent and its directors, officers, employees and agents (to the extent not reimbursed by the Borrower and without limitation of the obligations of the Borrower to do so, in each case pursuant to the terms of this Agreement and the other Loan Documents), based on its Applicable Percentage, from and
With respect to its Commitment and the Obligations owing to it, the Administrative Agent shall have the same rights and powers under this Agreement and each other Loan Document as any other Lender and may exercise the same as though it were not the Administrative Agent, and the terms "Lenders," "holders of Notes" and like terms shall include the Administrative Agent in its individual capacity as such. The Administrative Agent and its affiliates may, without liability to account, make loans to, accept deposits from, acquire debt or equity interests in, act as trustee under indentures of, and engage in any other business with, the Borrower and any stockholder, subsidiary or affiliate of the Borrower, as though the Administrative Agent were not the Administrative Agent hereunder.
The Administrative Agent may deem and treat the Lender which is payee of a Note as the owner and holder of such Note for all purposes hereof unless and until an Assignment and Acceptance with respect to the assignment or transfer thereof shall have been filed with the Administrative Agent in accordance with Section 9.12. Any authority, direction or consent of any Person who at the time of giving such authority, direction or consent is shown in the Register as being a Lender shall be conclusive and binding on each present and subsequent holder, transferee or assignee of any Note or Notes payable to such Lender or of any Note or Notes issued in exchange therefor.
The Administrative Agent may resign at any time by giving 10 days' prior written notice thereof to the Lenders and the Borrower. The Administrative Agent may be removed by the Required Lenders at any time with or without cause by giving 10 days' prior written notice
The Administrative Agent shall not be liable for any calculation, apportionment or distribution of payments made by it in good faith, in the absence of its own gross negligence or
willful misconduct. If such calculation, apportionment or distribution is subsequently determined to have been made in error, the sole recourse of any Lender to whom payment was due but not made (except as provided in the preceding sentence) shall be to recover from the other Lenders any payment in excess of the amount to which they are determined to be entitled or, if the amount due was not paid by the Borrower, to recover such amount from the Borrower.
As Syndication Agent, Wells Fargo Bank, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Wells Fargo Bank, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Wells Fargo Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Sole Bookrunner, Union Bank of California, N.A. shall not have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, Union Bank of California, N.A. shall not have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Union Bank of California, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
As Co-Documentation Agents, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any right, power, obligation, liability, responsibility or duty under this Agreement or any other Loan Document other than those applicable to all Lenders as such. Without limiting the foregoing, none of Bank One, NA, BNP Paribas or Mellon Bank, N.A. shall have any or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on Bank One, NA, BNP Paribas or Mellon Bank, N.A. in deciding to enter into this Agreement or in not taking action hereunder or under the Loan Documents.
ARTICLE IX
MISCELLANEOUS
Neither this Agreement nor any other Loan Document may be amended, modified or supplemented except in accordance with the provisions of this Section 9.01. The Administrative Agent and the Borrower may from time to time amend, modify or supplement the provisions of this Agreement or any other Loan Document for the purpose of amending, adding to or waiving any provision, or changing in any manner the rights and duties of the Borrower, the Administrative Agent or any Lender. Any such amendment, modification or supplement made
(a) Increase the Commitment of any Lender over the amount thereof then in effect, without the written consent of each Lender affected thereby;
(b) Extend the Revolving Termination Date, without the written consent of all the Lenders;
(c) Reduce the principal amount of or extend the time for any payment of principal of any Loan, or reduce the rate of interest or extend the time for payment of any interest borne by any Loan, or extend the time for payment of or reduce the amount of any fees, or reduce the amount of or postpone the date for payment of any other obligation, without the written consent of each Lender affected thereby;
(d) Change the definition of "Required Lenders" or amend this
Section 9.01 or Section 9.12(a) or any other provision of this
Agreement that requires the consent of all of the Lenders to the taking
or failure to take action hereunder, without the written consent of all
the Lenders;
(e) Amend or waive any of the provisions of Article VIII, or impose additional duties upon the Administrative Agent or otherwise adversely affect the rights, interests or obligations of the Administrative Agent, without the written consent of the Administrative Agent; or
(f) Release any General and Refunding Bonds issued to the Administrative Agent pursuant to Section 6.09(b), without the written consent of all the Lenders;
No course of dealing and no delay or failure of the Administrative Agent or any Lender in exercising any right, power or privilege under this Agreement or any other Loan Document shall affect any other or future exercise thereof or the exercise of any other right, power or privilege; nor shall any single or partial exercise of any such right, power or privilege or any abandonment or discontinuance of steps to enforce such a right, power or privilege preclude any further exercise thereof or of any other right, power or privilege. The rights and remedies of the Administrative Agent and the Lenders under this Agreement and any other Loan
Document are cumulative and not exclusive of any rights or remedies which the Administrative Agent or any Lender would otherwise have hereunder or thereunder, at law, in equity or otherwise.
(b) Any Lender giving any notice to the Borrower or any other party to a Loan Document shall simultaneously send a copy thereof to the Administrative Agent, and the Administrative Agent shall promptly notify the other Lenders of the receipt by it of any such notice.
(c) The Administrative Agent and each Lender may rely on any notice (whether or not such notice is made in a manner permitted or required by this Agreement or any other Loan Document) purportedly made by or on behalf of the Borrower, and neither the Administrative Agent nor any Lender shall have any duty to verify the identity or authority of any Person giving such notice.
(a) The Borrower agrees to pay or cause to be paid and to save
the Administrative Agent and each of the Lenders harmless against liability for
the payment of all reasonable out-of-pocket costs and expenses (including but
not limited to reasonable fees and expenses of counsel) incurred by the
Administrative Agent or any Lender from time to time arising from or relating to
(i) in the case of the Administrative Agent, the negotiation, syndication,
preparation, execution, delivery, administration and performance of this
Agreement and the other Loan Documents, (ii) in the case of the Syndication
Agent, the syndication of this Agreement and the other Loan Documents, (iii) in
the case of the Administrative Agent, any amendments, modifications,
supplements, waivers or consents to this Agreement or any other Loan Document
(whether or not ultimately entered into or granted), and (iv) in the case of the
Administrative Agent or any Lender, the enforcement or preservation of rights
under this Agreement or any other Loan Document (including but not limited to
any such costs or expenses arising from or relating to (A) collection or
enforcement of an outstanding Loan or any other amount owing hereunder or
thereunder by the Administrative Agent or such Lender, and (B) any
litigation, proceeding, dispute, work-out, restructuring or rescheduling related in any way to this Agreement or the Loan Documents).
(b) The Borrower hereby agrees to pay all stamp, document, transfer, recording, filing, registration, search, sales and excise fees and taxes and all similar impositions now or hereafter determined by the Administrative Agent or any Lender to be payable in connection with this Agreement or any other Loan Documents or any other documents, instruments or transactions pursuant to or in connection herewith or therewith (which determination shall be conclusive provided it is reached in good faith), and the Borrower agrees to save the Administrative Agent and each Lender harmless from and against any and all present or future claims, liabilities or losses with respect to or resulting from any omission to pay or delay in paying any such fees, taxes or impositions.
(c) The Borrower hereby agrees to reimburse and indemnify each of the Indemnified Parties from and against any and all losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements of any kind or nature whatsoever (including, without limitation, the reasonable fees and disbursements of counsel for such Indemnified Party in connection with any investigative, administrative or judicial proceeding commenced or threatened, whether or not such Indemnified Party shall be designated a party thereto) that may at any time be imposed on, asserted against or incurred by such Indemnified Party as a result of, or arising out of, or in any way related to or by reason of, this Agreement or any other Loan Document, any transaction from time to time contemplated hereby or thereby, or any transaction financed in whole or in part or directly or indirectly with the proceeds of any Loan (and without in any way limiting the generality of the foregoing, including any violation or breach of any Environmental Law or any other Law by the Borrower or any Subsidiary of the Borrower; any Environmental Claim arising out of the management, use, control, ownership or operation of Property by any of such Persons, including all onsite and offsite activities involving Hazardous Materials; or any exercise by the Administrative Agent or any Lender of any of its rights or remedies under this Agreement or any other Loan Document); but excluding any such losses, liabilities, claims, damages, expenses, obligations, penalties, actions, judgments, suits, costs or disbursements resulting solely from the gross negligence or willful misconduct of such Indemnified Party, as finally determined by a court of competent jurisdiction. If and to the extent that the foregoing obligations of the Borrower under this subsection (c), or any other indemnification obligation of the Borrower hereunder or under any other Loan Document, are unenforceable for any reason, the Borrower hereby agrees to make the maximum contribution to the payment and satisfaction of such obligations which is permissible under applicable Law.
The provisions of this Agreement are intended to be severable. If any provision of this Agreement shall be held invalid or unenforceable in whole or in part in any jurisdiction such provision shall, as to such jurisdiction, be ineffective to the extent of such invalidity or unenforceability without in any manner affecting the validity or enforceability thereof in any other jurisdiction or the remaining provisions hereof in any jurisdiction.
This Agreement and the other Loan Documents, as such agreements shall be amended from time to time, supersede all prior and contemporaneous understandings and agreements, whether written or oral, among the parties hereto relating to the transactions provided for herein and therein.
All representations and warranties of the Borrower contained herein or in any other Loan Document or made in connection herewith or therewith shall survive the making, and shall not be waived by the execution and delivery, of this Agreement or any other Loan Document, any investigation by or knowledge of the Administrative Agent or any Lender, the making of any Loan, or any other event or condition whatever. All covenants and agreements of the Borrower contained herein or in any other Loan Document shall continue in full force and effect from and after the date hereof so long as the Borrower may borrow hereunder and until payment in full of all Obligations. Without limitation, all obligations of the Borrower hereunder or under any other Loan Document to make payments to or indemnify the Administrative Agent or any Lender shall survive the payment in full of all other Obligations, termination of the Borrower's right to borrow hereunder, and all other events and conditions whatever. In addition, all obligations of each Lender to make payments to or indemnify the Administrative Agent shall survive the payment in full by the Borrower of all Obligations, termination of the Borrower's right to borrow hereunder, and all other events or conditions whatever.
This Agreement may be executed in any number of counterparts and by the different parties hereto on separate counterparts each of which, when so executed, shall be deemed an original, but all such counterparts shall constitute but one and the same instrument.
The parties hereto intend to conform to all applicable Laws in effect from time to time limiting the maximum rate of interest that may be charged or collected. Accordingly, notwithstanding any other provision hereof or of any other Loan Document, the Borrower shall not be required to make any payment to or for the account of any Lender, and each Lender shall refund any payment made by the Borrower, to the extent that such requirement or such failure to refund would violate or conflict with nonwaivable provisions of applicable Laws limiting the maximum amount of interest which may be charged or collected by such Lender.
The Borrower hereby agrees that, to the fullest extent permitted by Law, if any Obligation of the Borrower shall be due and payable (by acceleration or otherwise), each Lender shall have the right, without notice to the Borrower, to set-off against and to appropriate and apply to such Obligation any indebtedness, liability or obligation of any nature owing to the Borrower by such Lender, including but not limited to all deposits (whether time or demand, general or special, provisionally credited or finally credited, whether or not evidenced by a
certificate of deposit) now or hereafter maintained by the Borrower with such
Lender. Such right shall be absolute and unconditional in all circumstances
and, without limitation, shall exist whether or not such Lender or any other
Person shall have given notice or made a demand to the Borrower or any other
Person, whether such indebtedness, obligation or liability owed to the Borrower
is contingent, absolute, matured or unmatured (it being agreed that such Lender
may deem such indebtedness, obligation or liability to be then due and payable
at the time of such setoff), and regardless of the existence or adequacy of any
collateral, guaranty or any other security, right or remedy available to any
Lender or any other Person. The Borrower hereby agrees that, to the fullest
extent permitted by Law, any Participant and any branch, subsidiary or
affiliate of any Lender or any Participant shall have the same rights of
set-off as a Lender as provided in this Section (regardless of whether such
Participant, branch, subsidiary or affiliate would otherwise be deemed in
privity with or a direct creditor of the Borrower). The rights provided by this
Section are in addition to all other rights of set-off and banker's lien and
all other rights and remedies which any Lender (or any such Participant,
branch, subsidiary or affiliate) may otherwise have under this Agreement, any
other Loan Document, at law or in equity, or otherwise, and nothing in this
Agreement or any other Loan Document shall be deemed a waiver or prohibition of
or restriction on the rights of set-off or bankers' lien of any such Person.
The Lenders hereby agree among themselves that if any Lender
shall receive (by voluntary payment, realization upon security, set-off or from
any other source) any amount on account of the Loans, interest thereon, or any
other Obligation contemplated by this Agreement or the other Loan Documents to
be made by the Borrower pro rata to all Lenders (or pro rata to holders of
Notes) in greater proportion than any such amount received by any other
applicable Lender, then the Lender receiving such proportionately greater
payment shall notify each other Lender and the Administrative Agent of such
receipt, and equitable adjustment will be made in the manner stated in this
Section 9.11 so that, in effect, all such excess amounts will be shared ratably
among all of the applicable Lenders. The Lender receiving such excess amount
shall purchase (which it shall be deemed to have done simultaneously upon the
receipt of such excess amount) for cash from the other applicable Lenders a
participation in the applicable Obligations owed to such other Lenders in such
amount as shall result in a ratable sharing by all applicable Lenders of such
excess amount (and to such extent the receiving Lender shall be a Participant).
If all or any portion of such excess amount is thereafter recovered from the
Lender making such purchase, such purchase shall be rescinded and the purchase
price restored to the extent of such recovery, together with interest or other
amounts, if any, required by Law to be paid by the Lender making such purchase.
The Borrower hereby consents to and confirms the foregoing arrangements. Each
Participant shall be bound by this Section as fully as if it were a Lender
hereunder.
(a) Successors and Assigns. This Agreement shall be binding upon and inure to the benefit of the Borrower, the Lenders, all future holders of the Notes, the Agents and their respective successors and assigns, except that the Borrower may not assign or transfer any of its
rights hereunder or interests herein without the prior written consent of all the Lenders and the Administrative Agent, and any purported assignment without such consent shall be void.
(i) any such Lender's obligations under this Agreement and the other Loan Documents shall remain unchanged,
(ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations,
(iii) the parties hereto shall continue to deal solely and directly with such Lender in connection with such Lender's rights and obligations under this Agreement and each of the other Loan Documents,
(iv) such Participant shall be bound by the provisions of
Section 9.11, and
(v) no Participant (unless such Participant is an
Affiliate of such Lender, or is itself a Lender) shall be entitled
to require such Lender to take or refrain from taking action under
this Agreement or under any other Loan Document, except that such
Lender may agree with such Participant that such Lender will not,
without such Participant's consent, take any action, or consent to
the taking of any action, of the type described in Section 9.01(a),
(b) or (c).
(i) any such assignment to a Purchasing Lender which is not a Lender or an affiliate of a Lender shall be made only with the consent (which in each case shall not be unreasonably withheld) of the Borrower (so long as no Default or Event of Default shall have occurred and be continuing) and the Administrative Agent;
(ii) if a Lender makes such an assignment of less than all of its then remaining rights and obligations under this Agreement and the other Loan Documents, such transferor Lender shall retain, after such assignment, a minimum principal amount of $10,000,000 of the Commitments and Loans then outstanding, and such assignment, unless made to an assignee who is a Lender hereunder prior to such assignment, shall be in a minimum principal amount of $10,000,000 of the Commitments and Loans then outstanding;
(iii) each such assignment shall be of a constant, and not a varying, percentage of the Commitment of the transferor Lender and of all of the transferor Lender's rights and obligations under this Agreement and the other Loan Documents; and
(iv) each such assignment shall be made pursuant to an Assignment and Acceptance.
In order to effect any such assignment, the transferor Lender and the Purchasing Lender shall execute and deliver to the Administrative Agent a duly completed Assignment and Acceptance (including the consents required by clause (i) of the preceding sentence) with respect to such assignment, together with any Note or Notes subject to such assignment and a processing and recording fee of $3,500; and, upon receipt thereof, the Administrative Agent shall accept such Assignment and Acceptance. Upon receipt of notice from the transferor Lender that it has received the consideration described in the Assignment and Acceptance, the Administrative Agent shall record such acceptance in the Register. Upon such execution, delivery, acceptance and recording, from and after the close of business at the Administrative Agent's Principal Office on the settlement date specified in such Assignment and Acceptance:
(x) the Purchasing Lender shall be a party hereto and, to the extent provided in such Assignment and Acceptance, shall have the rights and obligations of a Lender hereunder, and
(y) the transferor Lender thereunder shall be released from its obligations under this Agreement to the extent so transferred (and, in the case of an Assignment and Acceptance covering all or the remaining portion of a transferor Lender's rights and obligations under this Agreement, such transferor Lender shall cease to be a party to this Agreement) from and after the settlement date.
On or prior to the settlement date specified in an Assignment and Acceptance, the Borrower, at its expense, shall execute and deliver to the Administrative Agent (for delivery to the Purchasing Lender) new Notes evidencing such Purchasing Lender's assigned Commitment or Loans and (for delivery to the transferor Lender) replacement Notes in the principal amount of the Loans or Commitment retained by the transferor Lender (such Notes to be in exchange for, but not in payment of, those Notes then held by such transferor Lender). Each such Note shall be dated the date and be substantially in the form of the predecessor Note. The Administrative Agent shall mark the predecessor Notes "exchanged" and deliver them to the Borrower. Accrued interest and accrued fees shall be paid to the Purchasing Lender at the same time or times provided in the predecessor Notes and this Agreement.
(ii) WAIVES ANY OBJECTION WHICH IT MAY HAVE AT ANY TIME TO THE LAYING OF VENUE OF ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, WAIVES ANY CLAIM THAT ANY SUCH RELATED LITIGATION HAS BEEN BROUGHT IN AN INCONVENIENT FORUM, AND WAIVES ANY RIGHT TO OBJECT, WITH RESPECT TO ANY RELATED LITIGATION BROUGHT IN ANY SUCH COURT, THAT SUCH COURT DOES NOT HAVE JURISDICTION OVER IT;
(iii) CONSENTS AND AGREES TO SERVICE OF ANY SUMMONS, COMPLAINT OR OTHER LEGAL PROCESS IN ANY RELATED LITIGATION BY REGISTERED OR CERTIFIED U.S. MAIL, POSTAGE PREPAID, TO IT AT THE ADDRESS FOR NOTICES DESCRIBED IN SECTION 9.03, AND CONSENTS AND AGREES THAT SUCH SERVICE SHALL CONSTITUTE IN EVERY RESPECT VALID AND EFFECTIVE SERVICE (BUT NOTHING HEREIN SHALL AFFECT THE VALIDITY OR EFFECTIVENESS OF PROCESS SERVED IN ANY OTHER MANNER PERMITTED BY LAW); AND
(iv) WAIVES THE RIGHT TO TRIAL BY JURY IN ANY RELATED LITIGATION.
OMISSION, OR EVENT OCCURRING IN CONNECTION HEREWITH OR THEREWITH (WHETHER FOR BREACH OF CONTRACT, TORT OR ANY OTHER THEORY OF LIABILITY). EACH PARTY TO THIS AGREEMENT HEREBY WAIVES, RELEASES AND AGREES NOT TO SUE UPON ANY CLAIM FOR ANY SUCH DAMAGES, WHETHER SUCH CLAIM PRESENTLY EXISTS OR ARISES HEREAFTER AND WHETHER OR NOT SUCH CLAIM IS KNOWN OR SUSPECTED TO EXIST IN ITS FAVOR.
* * *
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed and delivered as of the day and year first above written.
Address SIERRA PACIFIC POWER COMPANY ------- c/o Sierra Pacific Resources 6100 Neil Road P.O. Box 30150 By_______________________________ Reno, Nevada 89520 Name: |
Attn: Richard K. Atkinson Title:
Signature Page to Pacific Power Company Credit Agreement
Address UNION BANK OF CALIFORNIA, N.A., as ------- Administrative Agent, as Co-Lead Union Bank of California, N.A. Arranger, as Sole Bookrunner and 445 South Figueroa Street, 15(th) Floor as a Lender Los Angeles, CA 90071 Attn: Robert Olson By_______________________________ Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address WELLS FARGO BANK, N.A., as ------- Syndication Agent, as Co-Lead Wells Fargo Bank, N.A. Arranger and as a Lender 555 Montgomery Street, 17(th) Floor San Francisco, CA 94111 Attn: Dennis Bloch By_______________________________ Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address BANK ONE, NA, as Co-Documentation Agent ------- and as a Lender Bank One, NA 1 Bank One Plaza, Suite IL1-0363 Chicago, IL 60670 By_______________________________ Attn: Dawn M. Lawler Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address BNP PARIBAS, as Co-Documentation Agent ------- and as a Lender BNP Paribas 787 Seventh Avenue New York, NY 10019 By_______________________________ Attn: Sean Finnegan Name: Title: By_______________________________ Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address MELLON BANK, N.A., as Co-Documentation ------- Agent and as a Lender Mellon Bank, N.A. One Mellon Center 500 Grant Street, Room 4530 Pittsburgh, PA 15258-0001 By_______________________________ Attn: Mark W. Rogers Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address BAYERISCHE LANDESBANK GIROZENTRALE ------- Bayerische Landesbank Girozentrale 560 Lexington Avenue New York, NY 10022 By_______________________________ Attn: Jim Monaghan Name: Title: By_______________________________ Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address THE INDUSTRIAL BANK OF JAPAN, LIMITED ------- The Industrial Bank of Japan, Limited 350 S. Grand Avenue, Suite 1500 Los Angeles, CA 09971 By_______________________________ Attn: Al Torres Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address LEHMAN COMMERCIAL PAPER INC. ------- Lehman Commercial Paper Inc. 101 Hudson Street Jersey City, NJ 07302 By_______________________________ Attn: Michele Swanson Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address FIRST UNION NATIONAL BANK ------- First Union National Bank 301 South College Street Charlotte, NC 38388-0251 By_______________________________ Attn: Joe Dancy Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
Address MERRILL LYNCH BANK USA ------- Merrill Lynch Bank USA 15 W. South Temple, Suite 300 Salt Lake City, UT 84101 By_______________________________ Attn: Butch Alder Name: |
Title:
Signature Page to Pacific Power Company Credit Agreement
[See definitions of "Commitment" in Section 1.01]
LENDER COMMITMENT AMOUNT ------ ----------------- Union Bank of California, N.A. $23,571,428.57 Wells Fargo Bank, N.A. $23,571,428.57 Bank One, NA $21,176,470.59 BNP Paribas $21,176,470.59 Mellon Bank, N.A. $18,403,361.34 Bayerische Landesbank Girozentrale $15,882,352.94 Lehman Commercial Paper Inc. $9,201,680.67 The Industrial Bank of Japan, Limited $6,428,571.43 First Union National Bank $5,294,117.65 Merrill Lynch Bank USA $5,294,117.65 Total: $150,000,000.00 |
Exhibit 10(O)
Financing Agreement
Dated as of March 1, 2001
By and Between
Washoe County, Nevada
and
Sierra Pacific Power Company
Relating To
Water Facilities Refunding Revenue Bonds
(Sierra Pacific Power Company Project)
Series 2001
The amounts payable to the Issuer (except for amounts payable to, and certain rights and privileges of, the Issuer under Sections 4.2(e), 4.2(g), 5.3 and 6.4 hereof and any rights of the Issuer to receive any notices, certificates, requests, requisitions or communications hereunder) and certain other rights of the Issuer under this Financing Agreement have been pledged and assigned under the Indenture of Trust dated as of March 1, 2001, between the Issuer and The Bank of New York, as Trustee.
Financing Agreement
Table of Contents
(This Table of Contents is not a part of this Agreement and is only for convenience of reference).
Section Heading Page Article I Definitions............................................................................1 Article II Representations........................................................................4 Section 2.1. Representations and Covenants by the Issuer............................................4 Section 2.2. Representations by the Company.........................................................5 Article III Issuance of the Bonds..................................................................6 Section 3.1. Agreement to Issue Bonds; Application of Bond Proceeds.................................6 Section 3.2. Deposit of Additional Funds by Company; Redemption of Prior Bonds......................6 Section 3.3. Investment of Moneys in the Bond Fund and the Prior Bonds Redemption Fund..............6 Section 3.4. Tax Exempt Status of Bonds.............................................................7 Article IV Loan and Provisions for Repayment......................................................8 Section 4.1. Loan of Bond Proceeds..................................................................8 Section 4.2. Loan Repayments and Other Amounts Payable..............................................8 Section 4.3. No Defense or Set-Off.................................................................10 Section 4.4. Payments Pledged and Assigned.........................................................10 Section 4.5. Payment of the Bonds and Other Amounts................................................10 Article V Special Covenants and Agreements......................................................11 Section 5.1. Company to Maintain its Corporate Existence; Conditions Under Which Exceptions Permitted..............................................................11 Section 5.2. Annual Statement......................................................................11 Section 5.3. Maintenance and Repair; Insurance; Taxes; Disposition.................................11 Section 5.4. Recordation and Other Instruments.....................................................12 Section 5.5. No Warranty by the Issuer.............................................................12 Section 5.6. Agreement as to Ownership of the Project..............................................12 Section 5.7. Company to Furnish Notice of Adjustments of Interest Rate Periods.....................12 Section 5.8. Information Reporting, Etc............................................................12 Section 5.9. Limited Liability of Issuer...........................................................13 |
Section 5.10. Inspection of Project.................................................................13 Article VI Events of Default and Remedies........................................................13 Section 6.1. Events of Default Defined.............................................................13 Section 6.2. Remedies on Default...................................................................15 Section 6.3. No Remedy Exclusive...................................................................16 Section 6.4. Agreement to Pay Fees and Expenses of Counsel.........................................16 Section 6.5. No Additional Waiver Implied by One Waiver; Consents to Waivers.......................16 Article VII Options and Obligations of Company; Prepayments; Redemption of Bonds..................17 Section 7.1. Option to Prepay......................................................................17 Section 7.2. Obligation to Prepay..................................................................17 Section 7.3. Notice of Prepayment..................................................................17 Article VIII Miscellaneous.........................................................................18 Section 8.1. Notices...............................................................................18 Section 8.2. Assignments...........................................................................18 Section 8.3. Severability..........................................................................18 Section 8.4. Execution of Counterparts.............................................................18 Section 8.5. Amounts Remaining in Bond Fund........................................................18 Section 8.6. Amendments, Changes and Modifications.................................................19 Section 8.7. Governing Law.........................................................................19 Section 8.8. Authorized Issuer and Company Representatives.........................................19 Section 8.9. Term of the Agreement.................................................................19 Section 8.10. Cancellation at Expiration of Term....................................................19 Signature.....................................................................................................20 |
This Financing Agreement made and entered into as of March 1, 2001, by and between Washoe County, Nevada, a political subdivision of the State of Nevada, party of the first part (hereinafter referred to as the "Issuer"), and Sierra Pacific Power Company, a corporation duly organized and existing under the laws of the State of Nevada, party of the second part (hereinafter referred to as the "Company"),
W i t n e s s e t h:
In consideration of the respective representations and agreements hereinafter contained, the parties hereto agree as follows (provided, that in the performance of the agreements of the Issuer herein contained, any obligation it may thereby incur shall not constitute or give rise to a pecuniary liability or a charge upon its general credit or against its taxing powers but shall be payable solely out of the Revenues (as hereinafter defined) derived from this Financing Agreement and the Bonds, as hereinafter defined):
Article I
Definitions
The following terms shall have the meanings specified in this Article unless the context clearly requires otherwise. The singular shall include the plural and the masculine shall include the feminine.
"Act" means the County Economic Development Revenue Bond Law, as amended, contained in Sections 244A.669 to 244A.763, inclusive, of the Nevada Revised Statutes.
"Act of Bankruptcy" means the filing of a petition in bankruptcy by or against the Company or the Issuer under the Bankruptcy Code.
"Administrative Expenses" means the reasonable and necessary expenses (including the reasonable value of employee services and necessary out-of-pocket expenses and fees of Counsel) incurred by the Issuer in connection with the Bonds, this Agreement, the Indenture and any transaction or event contemplated by this Agreement or the Indenture.
"Agreement" means this Financing Agreement by and between the Issuer and the Company, as from time to time amended and supplemented.
"Auction Agent" means the auction agent appointed in accordance with
Section 2.03(e)(iv) of the Indenture.
"Authorized Company Representative" means any person who, at the time, shall have been designated to act on behalf of the Company by a written certificate furnished to the Issuer, the Remarketing Agent and the Trustee containing the specimen signature of such person and
signed on behalf of the Company by any officer of the Company. Such certificate may designate an alternate or alternates.
"Authorized Issuer Representative" means any person at the time designated to act on behalf of the Issuer by a written certificate furnished to the Company and the Trustee containing the specimen signature of such person and signed on behalf of the Issuer by its Chairman. Such certificate may designate an alternate or alternates.
"Bankruptcy Code" means the United States Bankruptcy Reform Act of 1978, as amended from time to time, or any substitute or replacement legislation.
"Bond" or "Bonds" means the Issuer's bonds identified in Section 2.02 of the Indenture.
"Bond Counsel" means the Counsel who renders the opinion as to the tax-exempt status of interest on the Bonds or other nationally recognized municipal bond counsel mutually acceptable to the Issuer and the Company.
"Bond Fund" means the fund created by Section 6.02 of the Indenture.
"Code" means the United States Internal Revenue Code of 1986, as amended, and regulations promulgated or proposed thereunder.
"Company" means Sierra Pacific Power Company, a Nevada corporation, and its successors and assigns and any surviving, resulting or transferee corporation as permitted in Section 5.1 hereof.
"Counsel" means an attorney at law or a firm of attorneys (who may be an employee of or counsel to the Issuer or the Company or the Trustee) duly admitted to the practice of law before the highest court of any state of the United States of America or of the District of Columbia.
"Extraordinary Services" and "Extraordinary Expenses" means all services rendered and all expenses (including fees and expenses of Counsel) incurred under the Indenture and the Tax Agreement other than Ordinary Services and Ordinary Expenses.
"Force Majeure" means acts of God, strikes, lockouts or other industrial disturbances; acts of public enemies; orders or restraints of any kind of the governments of the United States or of the State, or any of their departments, agencies or officials, or any civil or military authority; insurrections; riots; landslides; lightning; earthquakes; fires; tornadoes; volcanoes; storms; droughts; floods; explosions, breakage, or malfunction or accident to machinery, transmission lines, pipes or canals, even if resulting from negligence; civil disturbances; or any other cause not reasonably within the control of the Company.
"Governing Body" means the Board of County Commissioners of the Issuer.
"Hereof," "herein," "hereunder" and other words of similar import refer to this Agreement as a whole.
"Indenture" means the Indenture of Trust relating to this Agreement between the Issuer and The Bank of New York, as Trustee, of even date herewith, pursuant to which the Bonds are authorized to be issued, including any indentures supplemental thereto or amendatory thereof.
"Insider" shall have the meaning set forth in the Bankruptcy Code.
"Issuer" means Washoe County, Nevada, and any successor body to the duties or functions of the Issuer.
"Moody's" means Moody's Investors Service, Inc., a corporation organized and existing under the laws of the State of Delaware, its successors and their assigns, and, if such corporation shall be dissolved or liquidated or shall no longer perform the functions of a securities rating agency, "Moody's" shall be deemed to refer to any other nationally recognized securities rating agency designated by the Company and acceptable to the Remarketing Agent, with notice to the Trustee.
"Ordinary Services" and "Ordinary Expenses" means those services normally rendered and those expenses, including fees and expenses of Counsel, normally incurred by a trustee or paying agent under instruments similar to the Indenture and the Tax Agreement.
"Owner" or "owner of Bonds" or "Bondholder" or "holder" means the Person or Persons in whose name or names a Bond shall be registered on books of the Issuer kept by the Registrar for that purpose in accordance with the terms of the Indenture.
"Person" means natural persons, firms, partnerships, associations, corporations, trusts, limited liability companies and public bodies.
"Prior Agreement" means the Financing Agreement, dated as of December 1, 1990, between the Issuer and the Company relating to the Prior Bonds.
"Prior Bonds" means the Issuer's Water Facilities Revenue Bonds (Sierra Pacific Power Company Project) Series 1990, currently outstanding in the aggregate principal amount of $80,000,000.
"Prior Bond Fund" means the fund established pursuant to Section 6.02 of the Prior Indenture.
"Prior Indenture" means the Indenture of Trust, dated as of December 1, 1990, between the Issuer, the Prior Trustee and Valley Bank of Nevada as Co-trustee, pursuant to which the Prior Bonds were issued.
"Prior Trustee" means The Bank of New York, as trustee under the Prior Indenture.
"Project" means the Project as defined in the Prior Agreement.
"Project Certificate" means the Company's Project and Refunding Certificate, delivered concurrently with the issuance of the Bonds, with respect to certain facts which are within the knowledge of the Company and certain reasonable assumptions of the Company, to enable Chapman and Cutler, as Bond Counsel, to determine that interest on the Bonds is not includable in the gross income of the Owners of the Bonds for federal income taxes purposes.
"Rebate Fund" means the Rebate Fund, if any, created and established pursuant to the Tax Agreement.
"Remarketing Agent" means the remarketing agent appointed in accordance with Section 4.08 of the Indenture and any permitted successor thereto.
"S&P" means Standard & Poor's Ratings Services, A division of The McGraw-Hill Companies, Inc., a corporation organized and existing under the laws of the State of New York, its successors and their assigns, and, if such division or corporation shall be dissolved or liquidated or shall no longer perform the functions of a securities rating agency, "S&P" shall be deemed to refer to any other nationally recognized securities rating agency designated by the Company and acceptable to the Remarketing Agent, with notice to the Trustee.
"State" means the State of Nevada.
"Tax Agreement" means the Tax Exemption Certificate and Agreement with respect to the Bonds, dated the date of delivery of the Bonds, among the Company, the Issuer and the Trustee, as from time to time amended and supplemented.
"Trust Estate" means the property conveyed to the Trustee pursuant to the Granting Clauses of the Indenture.
"Trustee" means The Bank of New York, as Trustee under the Indenture, and any successor Trustee appointed and qualified pursuant to Section 10.06 or 10.09 of the Indenture at the time serving as Trustee thereunder, and any separate or co-trustee serving as such thereunder.
All other terms used herein which are defined in the Indenture shall have the same meanings assigned them in the Indenture unless the context otherwise requires.
Article II
Representations
Section 2.1. Representations and Covenants by the Issuer. The Issuer makes the following representations and covenants as the basis for the undertakings on its part herein contained:
(a) The Issuer is a duly organized and existing political subdivision of the State of Nevada. Under the provisions of the Act, the Issuer is authorized to enter into the transactions contemplated by this Agreement, the Indenture and the Tax Agreement and to carry out its obligations hereunder and thereunder. The Issuer has duly authorized the execution and delivery of this Agreement, the Indenture and the Tax Agreement.
(b) The Bonds are to be issued under and secured by the Indenture, pursuant to which certain of the Issuer's interests in this Agreement and the Revenues derived by the Issuer pursuant to this Agreement will be pledged and assigned as security for payment of the principal of, premium, if any, and interest on, the Bonds.
(c) The Governing Body of the Issuer has found that the issuance of the Bonds will further the public purposes of the Act.
(d) The Issuer has not assigned and will not assign any of its interests in this Agreement other than pursuant to the Indenture.
(e) No member of the Governing Body of the Issuer, nor any other officer of the Issuer, has any interest, financial (other than ownership of less than one-tenth of one percent (.1%) of the publicly traded securities issued by the Company or its affiliated corporations), employment or other, in the Company or in the transactions contemplated hereby.
Section 2.2. Representations by the Company. The Company makes the following representations as the basis for the undertakings on its part herein contained:
(a) The Company is a corporation duly incorporated under the laws of the State and is in good standing in the State, is qualified to do business as a foreign corporation in all other states and jurisdictions wherein the nature of the business transacted by the Company or the nature of the property owned or leased by it makes such licensing or qualification necessary, has power to enter into and by proper corporate action has been duly authorized to execute and deliver this Agreement and the Tax Agreement.
(b) Neither the execution and delivery of this Agreement or the Tax Agreement, the consummation of the transactions contemplated hereby and thereby, nor the fulfillment of or compliance with the terms and conditions of this Agreement and the Tax Agreement, conflicts with or results in a breach of any of the terms, conditions or provisions of any corporate restriction or any agreement or instrument to which the Company is now a party or by which it is bound, or constitutes a default under any of the foregoing, or results in the creation or imposition of any lien, charge or encumbrance whatsoever upon any of the property or assets of the Company under the terms of any instrument or agreement other than the Indenture.
(c) The statements, information and descriptions contained in the Project Certificate and the Tax Agreement, as of the date hereof and at the time of the delivery of
the Bonds to the Underwriter, are and will be true, correct and complete, do not and will not contain any untrue statement or misleading statement of a material fact, and do not and will not omit to state a material fact required to be stated therein or necessary to make the statements, information and descriptions contained therein, in the light of the circumstances under which they were made, not misleading.
Article III
Issuance of the Bonds
Section 3.1. Agreement to Issue Bonds; Application of Bond Proceeds. In order to provide funds to lend to the Company to refund the Prior Bonds as provided in Section 4.1 hereof, the Issuer agrees that it will issue under the Indenture, sell and cause to be delivered to the Underwriter, its Bonds in the aggregate principal amount of $80,000,000, bearing interest and maturing as set forth in the Indenture. The Issuer will thereupon deposit the proceeds received from the sale of the Bonds as follows: (1) in the Bond Fund, a sum equal to any accrued interest, if any, paid by the Underwriter; and (2) $80,000,000 in the Prior Bonds Redemption Fund to be remitted by the Trustee to the Prior Trustee for deposit in the Prior Bond Fund to be used to pay to the owners thereof the principal of the Prior Bonds upon redemption thereof.
Section 3.2. Deposit of Additional Funds by Company; Redemption of Prior Bonds. The Company covenants that such additional amounts as may be required to redeem the Prior Bonds will be deposited with the Prior Trustee pursuant to the Prior Indenture for such purpose. Income derived from the investment of the proceeds of the Bonds deposited in the Prior Bonds Redemption Fund will be used to satisfy the obligations of the Company specified in this Section 3.2. The Company covenants that it will cause the Prior Bonds to be redeemed within 90 days after the issuance and delivery of the Bonds.
Section 3.3. Investment of Moneys in the Bond Fund and the Prior Bonds Redemption Fund. Except as otherwise herein provided, any moneys held as a part of the Bond Fund and the Prior Bonds Redemption Fund shall be invested or reinvested by the Trustee at the specific written direction of an Authorized Company Representative as to specific investments, to the extent permitted by law, in:
(a) bonds or other obligations of the United States of America;
(b) bonds or other obligations, the payment of the principal of and interest on which is unconditionally guaranteed by the United States of America;
(c) obligations issued or guaranteed as to principal and interest by any agency or person controlled or supervised by and acting as an instrumentality of the United States of America pursuant to authority granted by the Congress of the United States of America;
(d) obligations issued or guaranteed by any state of the United States of America, or any political subdivision of any such state, or in funds consisting of such obligations to the extent described in Treasury Regulation 1.148-8(e)(3)(iii);
(e) prime commercial paper;
(f) prime finance company paper;
(g) bankers' acceptances drawn on and accepted by commercial banks;
(h) repurchase agreements fully secured by obligations issued or guaranteed as to principal and interest by the United States of America or by any person controlled or supervised by and acting as an instrumentality of the United States of America pursuant to authority granted by the Congress of the United States of America;
(i) certificates of deposit issued by commercial banks, including banks domiciled outside of the United States of America; and
(j) units of taxable government money market portfolios composed of obligations guaranteed as to principal and interest by the United States of America or repurchase agreements fully collateralized by such obligations.
The investments so purchased shall be held by the Trustee and shall be deemed at all times a part of the fund for which they were made and the interest accruing thereon and any profit realized therefrom shall be credited to such fund, subject to the provisions of the Tax Agreement. The Company agrees that to the extent any moneys in the Bond Fund represent moneys held for the payment of particular Bonds or moneys held for the payment of the purchase price of Bonds pursuant to Article IV of the Indenture, such moneys shall not be invested.
Section 3.4. Tax Exempt Status of Bonds. The Company covenants and agrees that it has not taken or permitted and will not take or permit or fail to take any action which results in interest paid on the Bonds being included in gross income of the holders or Beneficial Owners of the Bonds for purposes of federal income taxation (other than a holder or Beneficial Owner who is a "substantial user" of the Project or a "related person" within the meaning of Section 147(a) of the Code). The Company covenants that none of the proceeds of the Bonds or the payments to be made under this Agreement, or any other funds which may be deemed to be proceeds of the Bonds pursuant to Section 148(a) of the Code, will be invested or used in such a way, and that no actions will be taken or not taken, as to cause the Bonds to be treated as "arbitrage bonds" within the meaning of Section 148(a) of the Code. Without limiting the generality of the foregoing, the Company covenants and agrees that it will comply with the provisions of the Tax Agreement and the Project Certificate.
Article IV
Loan and Provisions for Repayment
Section 4.1. Loan of Bond Proceeds. (a) The Issuer agrees, upon the terms and conditions in this Agreement, to lend to the Company the proceeds (exclusive of accrued interest, if any) received by the Issuer from the sale of the Bonds in order to refund the Prior Bonds and the Company agrees to apply the gross proceeds of such loan to the refunding of the Prior Bonds.
(b) The Issuer and the Company expressly reserve the right to enter into, to the extent permitted by law, an agreement or agreements other than this Agreement, with respect to the issuance by the Issuer, under an indenture or indentures other than the Indenture, of obligations to provide additional funds to refund all or any principal amount of the Bonds.
Section 4.2. Loan Repayments and Other Amounts Payable. (a) On each date
provided in or pursuant to the Indenture for the payment (whether at maturity or
upon redemption or acceleration) of principal of, and premium, if any, and
interest on, the Bonds, until the principal of, and premium, if any, and
interest on, the Bonds shall have been fully paid or provision for the payment
thereof shall have been made in accordance with the Indenture, the Company shall
pay to the Trustee in immediately available funds, for deposit in the Bond Fund,
as a repayment installment of the loan of the proceeds of the Bonds pursuant to
Section 4.1(a) hereof, a sum equal to the amount payable on such date (whether
at maturity or upon redemption or acceleration) as principal of, and premium, if
any, and interest on, the Bonds as provided in the Indenture; provided, however,
that the obligation of the Company to make any such repayment installment shall
be reduced by the amount of any moneys then on deposit in the Bond Fund and
available for such payment.
(b) The Company shall pay to the Trustee amounts equal to the amounts to be
paid by the Trustee for the purchase of Bonds pursuant to Article IV of the
Indenture. Such amounts shall be paid by the Company to the Trustee in
immediately available funds on the date such payments pursuant to Section 4.05
of the Indenture are to be made; provided, however, that the obligation of the
Company to make any such payment shall be deemed to be satisfied and discharged
to the extent moneys are available from the source described in clause (i) of
Section 4.05(a) of the Indenture.
(c) The Company agrees to pay to the Trustee (i) the fees of the Trustee for the Ordinary Services rendered by it and an amount equal to the Ordinary Expenses incurred by it under the Indenture and the Tax Agreement, as and when the same become due, and (ii) the reasonable fees, charges and expenses of the Trustee for reasonable Extraordinary Services and Extraordinary Expenses, as and when the same become due, incurred under the Indenture and the Tax Agreement. The Company agrees that the Trustee, its officers, agents, servants and employees, shall not be liable for, and agrees that it will at all times indemnify and hold harmless the Trustee, its officers, agents, servants and employees against, and pay all expenses of the Trustee, its officers, agents, servants and employees, relating to any lawsuit, proceeding or claim and resulting from any action or omission taken or made by or on behalf of the Trustee, its
officers, agents, servants and employees pursuant to this Agreement, the Indenture or the Tax Agreement, that may be occasioned by any cause (other than the negligence or willful misconduct of the Trustee, its officers, agents, servants and employees). In case any action shall be brought against the Trustee in respect of which indemnity may be sought against the Company, the Trustee shall promptly notify the Company in writing and the Company shall be entitled to assume control of the defense thereof, including the employment of Counsel and the payment of all expenses. The Trustee shall have the right to employ separate Counsel in any such action and participate in the defense thereof, but the fees and expenses of such Counsel shall be paid by the Trustee unless the employment of such Counsel has been authorized by the Company, which authorization shall not be unreasonably withheld. The Company shall not be liable for any settlement of any such action without its consent, but if any such action is settled with the consent of the Company or if there be final judgment for the plaintiff in any such action, the Company agrees to indemnify and hold harmless the Trustee from and against any loss or liability by reason of such settlement or final judgment. The Company agrees that the indemnification provided herein shall survive the termination of this Agreement or the Indenture or the resignation of the Trustee.
(d) The Company agrees to pay all costs incurred in connection with the issuance of the Bonds from sources other than Bond proceeds and the Issuer shall have no obligation with respect to such costs.
(e) The Company agrees to indemnify and hold harmless the Issuer and any member, officer, official or employee of the Issuer against any and all losses, costs, charges, expenses, judgments and liabilities created by or arising out of this Agreement, the Indenture, the Remarketing Agreement, the Auction Agreement, the Bond Purchase Agreement, any Broker-Dealer Agreement or the Tax Agreement or otherwise incurred in connection with the issuance of the Bonds. The Company agrees to pay the Issuer its Closing Fee in connection with the issuance of the Bonds in the amount of $10,000. The Issuer may submit to the Company periodic statements, not more frequently than monthly, for its Administrative Expenses and the Company shall make payment to the Issuer of the full amount of each such statement within 30 days after the Company receives such statement.
(f) The Company agrees to pay (i) to the Remarketing Agent the reasonable fees, charges and expenses of such Remarketing Agent and (ii) to the Auction Agent the reasonable fees, charges and expenses of such Auction Agent, and the Issuer shall have no obligation or liability with respect to the payment of any such fees, charges or expenses.
(g) In the event the Company shall fail to make any of the payments
required by (a) or (b) of this Section 4.2, the payment so in default shall
continue as an obligation of the Company until the amount in default shall have
been fully paid and the Company will pay interest to the extent permitted by
law, on any overdue amount at the rate of interest borne by the Bonds on the
date on which such amount became due and payable until paid. In the event that
the Company shall fail to make any of the payments required by (c), (d), (e) or
(f) of this Section 4.2, the payment so in default shall continue as an
obligation of the Company until the amount in default shall have been fully
paid, and the Company agrees to pay the same with interest thereon to the
extent permitted by law at a rate 1% above the rate of interest then charged by the Trustee on 90-day commercial loans to its prime commercial borrowers until paid.
Section 4.3. No Defense or Set-Off. The obligation of the Company to make the payments pursuant to this Agreement shall be absolute and unconditional without defense or set-off by reason of any default by the Issuer under this Agreement or under any other agreement between the Company and the Issuer or for any other reason, it being the intention of the parties that the payments required hereunder will be paid in full when due without any delay or diminution whatsoever.
Section 4.4. Payments Pledged and Assigned. It is understood and agreed that all payments required to be made by the Company pursuant to Section 4.2 hereof (except payments made to the Trustee pursuant to Section 4.2(c) hereof, to the Remarketing Agent and the Auction Agent pursuant to Section 4.2(f) hereof, to the Issuer pursuant to Section 4.2(e) hereof and to any or all the Issuer and the Trustee and the Remarketing Agent pursuant to Section 4.2(g) hereof) and certain rights of the Issuer hereunder are pledged and assigned by the Indenture. The Company consents to such pledge and assignment. The Issuer hereby directs the Company and the Company hereby agrees to pay or cause to be paid to the Trustee all said amounts except payments to be made to the Remarketing Agent and the Auction Agent pursuant to Section 4.2(f) hereof and payments to be made to the Issuer pursuant to Sections 4.2(e) and (g) hereof. The Project will not constitute any part of the security for the Bonds.
Section 4.5. Payment of the Bonds and Other Amounts. The Bonds and interest and premium, if any, thereon shall be payable solely from (i) payments made by the Company to the Trustee under Section 4.2(a) hereof and (ii) other moneys on deposit in the Bond Fund and available therefor.
Payments of principal of, and premium, if any, or interest on, the Bonds with moneys in the Bond Fund constituting proceeds from the sale of the Bonds or earnings on investments made under the provisions of the Indenture shall be credited against the obligation to pay required by Section 4.2(a) hereof.
Whenever any Bonds are redeemable in whole or in part at the option of the Company, the Trustee, on behalf of the Issuer, shall redeem the same upon the request of the Company and such redemption (unless conditional) shall be made from payments made by the Company to the Trustee under Section 4.2(a) hereof equal to the redemption price of such Bonds.
Whenever payment or provision therefor has been made in respect of the principal of, or premium, if any, or interest on, all or any portion of the Bonds in accordance with the Indenture (whether at maturity or upon redemption or acceleration or upon provision for payment in accordance with Article VIII of the Indenture), payments shall be deemed paid to the extent such payment or provision therefor has been made and is considered to be a payment of principal of, or premium, if any, or interest on, such Bonds. If such Bonds are thereby deemed paid in full, the Trustee shall notify the Company and the Issuer that such payment requirement has been satisfied. Subject to the foregoing, or unless the Company is entitled to a credit under this
Agreement or the Indenture, all payments shall be in the full amount required by
Section 4.2(a) hereof.
Article V
Special Covenants and Agreements
Section 5.1. Company to Maintain its Corporate Existence; Conditions Under
Which Exceptions Permitted. The Company agrees that during the term of this
Agreement, it will maintain its corporate existence and its good standing in the
State, will not dissolve or otherwise dispose of all or substantially all of its
assets and will not consolidate with or merge into another corporation unless
(a) the acquirer of its assets or the corporation with which it shall
consolidate or into which it shall merge shall (i) be a corporation organized
under the laws of one of the states of the United States of America, (ii) be
qualified to do business in the State, (iii) be a public utility, and (iv)
assume in writing all of the obligations of the Company under this Agreement and
the Tax Agreement.
Any transfer of all or substantially all of the Company's electric generation assets and/or water business shall not be deemed to constitute a "disposition of all or substantially all of the Company's assets" within the meaning of the preceding paragraph. Any such transfer of the Company's electric generation assets and/or water business shall not relieve the Company of any of its obligations under this Agreement.
Section 5.2. Annual Statement. The Company agrees to have an annual audit made by its regular independent certified public accountants and to furnish the Trustee (within 30 days after receipt by the Company) with a balance sheet and statement of income and surplus showing the financial condition of the Company and its consolidated subsidiaries, if any, at the close of each fiscal year and the results of operations of the Company and its consolidated subsidiaries, if any, for each fiscal year, accompanied by a report of said accountants that such statements have been prepared in accordance with generally accepted accounting principles. The Company's obligations under this Section 5.2 may be satisfied by delivering a copy of the Company's Annual Report to the Trustee at the same time that it is mailed to stockholders.
Delivery of such reports, information and documents to the Trustee is for informational purposes only and the Trustee's receipt of such shall not constitute constructive notice of any information contained therein or determinable from information contained therein, including the Company's compliance with any of its covenants hereunder (as to which the Trustee is entitled to rely exclusively on officer's certificates).
Section 5.3. Maintenance and Repair; Insurance; Taxes; Disposition. For so long as the Company shall own the Project, (i) the Company shall maintain or cause to be maintained the Project in good repair and keep it properly insured and shall promptly pay or cause to be paid all costs thereof, and (ii) the Company shall promptly pay or cause to be paid all installments of taxes, installments of special assessments, and all governmental, utility and other charges with respect to the Project, when due. The Company may, at its own expense and in its own name in
good faith contest or appeal any such taxes, assessments or other charges, or
installments thereof, but shall not permit any such taxes, assessments or other
charges, or installments thereof, to remain unpaid if such nonpayment shall
subject the Project or any part thereof to loss or forfeiture. The Company,
subject to the provisions of Section 3.4 hereof, is not required by this
Agreement to operate, or cause to be operated, any portion of the Project after
the Company shall deem in its discretion that such continued operation by the
Company is not advisable, and in such event the Company may sell, lease or
retire all or any such portion of the Project. Subject to the provisions of
Section 3.4 hereof, the net proceeds from such sale, lease or other disposition,
if any, shall belong to, and may be used for any lawful purpose by, the Company.
Upon disposition of the Project in its entirety by the Company in accordance
with this Section 5.3, the Company shall be discharged from its obligations to
operate, maintain, repair and insure the Project as set forth in this Section
5.3. Any such sale, lease or other disposition shall comply with the
requirements of the Tax Agreement. Under any and all circumstances, the Issuer
shall have no obligation whatsoever with respect to the operation, maintenance,
repair or insurance of the Project.
Section 5.4. Recordation and Other Instruments. The Company shall cause
such security agreements, financing statements and all supplements thereto and
other instruments as may be required from time to time to be kept, to be
recorded and filed in such manner and in such places as may be required by law
in order to fully preserve, protect and perfect the security of the Owners of
the Bonds and the rights of the Trustee, and to perfect the security interest
created by the Indenture. The Company agrees to abide by the provisions of
Section 5.11 of the Indenture to the extent applicable to the Company.
Section 5.5. No Warranty by the Issuer. The Issuer makes no warranty, either express or implied, as to the Project or that it will be suitable for the purposes of the Company or needs of the Company.
Section 5.6. Agreement as to Ownership of the Project. The Issuer and the Company agree that title to the Project shall not be in the Issuer, and that the Issuer shall have no interest in the Project.
Section 5.7. Company to Furnish Notice of Adjustments of Interest Rate Periods. The Company is hereby granted the option to designate from time to time changes in Rate Periods (and to rescind such changes) in the manner and to the extent set forth in Section 2.03 of the Indenture. In the event the Company elects to exercise any such option, the Company agrees that it shall cause notices of adjustments of Rate Periods (or rescissions thereof) to be given to the Issuer, the Trustee and the Remarketing Agent in accordance with Section 2.03(a), (b), (c), (d) or (e) of the Indenture, and a copy of each such notice shall also be given at such time to S&P and Moody's.
Section 5.8. Information Reporting, Etc.. The Issuer covenants and agrees that, upon the direction of the Company or Bond Counsel, it will mail or cause to be mailed to the Secretary of the Treasury (or his designee as prescribed by regulation, currently the Internal Revenue Service Center, Ogden, Utah) a statement setting forth the information required by Section 149(e) of the Code, which statement shall be in the form of the Information Return for
Tax-Exempt Private Activity Bond Issues (Form 8038) of the Internal Revenue Service (or any successor form) and which shall be completed by the Company and Bond Counsel based in part upon information supplied by the Company and Bond Counsel.
Section 5.9. Limited Liability of Issuer. Any obligation or liability of the Issuer created by or arising out of this Agreement or otherwise incurred in connection with the issuance of the Bonds (including without limitation any liability created by or arising out of the representations, warranties or covenants set forth herein or otherwise) shall not impose a debt or pecuniary liability upon the Issuer or the State or any political subdivision thereof, or a charge upon the general credit or taxing powers of any of the foregoing, but shall be payable solely out of the Revenues or other amounts payable by the Company to the Issuer hereunder or otherwise (including without limitation any amounts derived from indemnifications given by the Company).
Neither the issuance of the Bonds nor the delivery of this Agreement shall, directly or indirectly or contingently, obligate the Issuer or the State or any political subdivision thereof to levy any form of taxation therefor or to make any appropriation for their payment. Nothing in the Bonds or in the Indenture or this Agreement or the proceedings of the Issuer authorizing the Bonds or in the Act or in any other related document shall be construed to authorize the Issuer to create a debt of the Issuer or the State or any political subdivision thereof within the meaning of any constitutional or statutory provision of the State. The principal of, and premium, if any, and interest on, the Bonds shall be payable solely from the funds pledged for their payment in accordance with the Indenture and available therefor under this Agreement. Neither the State nor any political subdivision thereof shall in any event be liable for the payment of the principal of, premium, if any, or interest on, the Bonds or for the performance of any pledge, obligation or agreement of any kind whatsoever which may be undertaken by the Issuer. No breach of any such pledge, obligation or agreement may impose any pecuniary liability upon the Issuer or the State or any political subdivision thereof, or any charge upon the general credit or against the taxing power of the Issuer or the State or any political subdivision thereof.
Section 5.10. Inspection of Project. The Company agrees that the Issuer and the Trustee and their duly authorized representatives shall have the right at all reasonable times to enter upon and examine and inspect the Project property and shall also be permitted, at all reasonable times, to examine the books and records of the Company insofar as they relate to the Project; provided, however, neither the Issuer nor the Trustee shall have any duty to make any inquiry hereunder for the benefit of the owners of the Bonds or any other person or entity.
Article VI
Events of Default and Remedies
Section 6.1. Events of Default Defined. The following shall be "events of default" under this Agreement and the terms "event of default" or "default" shall mean, whenever they are used in this Agreement, any one or more of the following events:
(a) Failure by the Company to pay when due any amounts required to be paid under Section 4.2(a) hereof, which failure results in an event of default under subparagraph (a) or (b) of Section 9.01 of the Indenture; or
(b) Failure by the Company to pay or cause to be paid any payment required to be paid under Section 4.2(b) hereof, which failure results in an event of default under subparagraph (c) of Section 9.01 of the Indenture; or
(c) Failure by the Company to observe and perform any covenant, condition or agreement on its part to be observed or performed in this Agreement, other than as referred to in (a) and (b) above, for a period of 90 days after written notice, specifying such failure and requesting that it be remedied and stating that such notice is a "Notice of Default" hereunder, given to the Company by the Trustee or to the Company and the Trustee by the Issuer, unless the Issuer and the Trustee shall agree in writing to an extension of such time prior to its expiration; provided, however, if the failure stated in the notice cannot be corrected within the applicable period, the Issuer and the Trustee will not unreasonably withhold their consent to an extension of such time if corrective action is instituted within the applicable period and diligently pursued until the failure is corrected and such corrective action or diligent pursuit is evidenced to the Trustee by a certificate of an Authorized Company Representative; or
(d) A proceeding or case shall be commenced, without the application
or consent of the Company, in any court of competent jurisdiction seeking
(i) liquidation, reorganization, dissolution, winding-up or composition or
adjustment of debts, (ii) the appointment of a trustee, receiver,
custodian, liquidator or the like of the Company or of all or any
substantial part of its assets, or (iii) similar relief under any law
relating to bankruptcy, insolvency, reorganization, winding-up or
composition or adjustment of debts, and such proceeding or cause shall
continue undismissed, or an order, judgment, or decree approving or
ordering any of the foregoing shall be entered and shall continue in effect
for a period of 90 days; or an order for relief against the Company shall
be entered against the Company in an involuntary case under the Bankruptcy
Code (as now or hereafter in effect) or other applicable law; or
(e) The Company shall admit in writing its inability to pay its debts generally as they become due or shall file a petition in voluntary bankruptcy or shall make any general assignment for the benefit of its creditors, or shall consent to the appointment of a receiver or trustee of all or substantially all of its property, or shall commence a voluntary case under the Bankruptcy Code (as now or hereafter in effect), or shall file in any court of competent jurisdiction a petition seeking to take advantage of any other law relating to bankruptcy, insolvency, reorganization, winding-up or composition or adjustment of debts, or shall fail to controvert in a timely or appropriate manner, or acquiesce in writing to, any petition filed against it in an involuntary case under such Bankruptcy Code or other applicable law; or
(f) Dissolution or liquidation of the Company; provided that the term "dissolution or liquidation of the Company" shall not be construed to include the
cessation of the corporate existence of the Company resulting either from a merger or consolidation of the Company into or with another corporation or a dissolution or liquidation of the Company following a transfer of all or substantially all of its assets as an entirety, under the conditions permitting such actions contained in Section 5.1 hereof; or
(g) The occurrence of an "Event of Default" under the Indenture.
The foregoing provisions of Section 6.1(c) are subject to the following limitations: If by reason of Force Majeure the Company is unable in whole or in part to carry out its agreements on its part herein contained, other than the obligations on the part of the Company contained in Article IV and Sections 5.3 and 6.4 hereof, the Company shall not be deemed in default during the continuance of such inability. The Company agrees, however, to remedy with all reasonable dispatch the cause or causes preventing the Company from carrying out its agreements; provided that the settlement of strikes, lockouts and other industrial disturbances shall be entirely within the discretion of the Company and the Company shall not be required to make settlement of strikes, lockouts and other industrial disturbances by acceding to the demands of the opposing party or parties when such course is in the sole judgment of the Company unfavorable to the Company.
Section 6.2. Remedies on Default. Whenever any event of default referred to in Section 6.1 hereof shall have happened and be continuing, the Trustee, as assignee of the Issuer:
(a) shall, by notice in writing to the Company, declare the unpaid indebtedness under Section 4.2(a) hereof to be due and payable immediately, if concurrently with or prior to such notice the unpaid principal amount of the Bonds shall have been declared to be due and payable, and upon any such declaration the same (being an amount sufficient, together with other moneys available therefor in the Bond Fund, to pay the unpaid principal of, premium, if any, and interest accrued on, the Bonds) shall become and shall be immediately due and payable as liquidated damages; and
(b) may take whatever action at law or in equity as may appear necessary or desirable to collect the payments and other amounts then due and thereafter to become due hereunder or to enforce performance and observance of any obligation, agreement or covenant of the Company under this Agreement.
Any amounts collected pursuant to action taken under this Section 6.2 shall be paid into the Bond Fund (unless otherwise provided in this Agreement) and applied in accordance with the provisions of the Indenture. No action taken pursuant to this Section 6.2 shall relieve the Company from the Company's obligations pursuant to Section 4.2 hereof.
No recourse shall be had for any claim based on this Agreement against any officer, director or stockholder, past, present or future, of the Company as such, either directly or through the Company, under any constitutional provision, statute or rule of law, or by the enforcement of any assessment or by any legal or equitable proceeding or otherwise.
Nothing herein contained shall be construed to prevent the Issuer from enforcing directly any of its rights under Sections 4.2(e), 4.2(g), 5.3 and 6.4 hereof.
Section 6.3. No Remedy Exclusive. No remedy herein conferred upon or reserved to the Issuer is intended to be exclusive of any other available remedy or remedies, but each and every such remedy shall be cumulative and shall be in addition to every other remedy given under this Agreement or now or hereafter existing at law or in equity or by statute. No delay or omission to exercise any right or power accruing upon any default shall impair any such right or power or shall be construed to be a waiver thereof, but any such right and power may be exercised from time to time and as often as may be deemed expedient. In order to entitle the Issuer or the Trustee to exercise any remedy reserved to it in this Article, it shall not be necessary to give any notice, other than such notice as may be herein expressly required. Subject to the provisions of the Indenture and hereof, such rights and remedies as are given the Issuer hereunder shall also extend to the Trustee. The Owners of the Bonds, subject to the provisions of the Indenture, shall be entitled to the benefit of all covenants and agreements herein contained.
Section 6.4. Agreement to Pay Fees and Expenses of Counsel. In the event the Company should default under any of the provisions of this Agreement and the Issuer or the Trustee should employ Counsel or incur other expenses for the collection of the indebtedness hereunder or the enforcement of performance or observance of any obligation or agreement on the part of the Company herein contained, the Company agrees that it will on demand therefor pay to the Trustee, the Issuer or, if so directed by the Issuer, to the Counsel for the Issuer, the reasonable fees and expenses of such Counsel and such other expenses so incurred by or on behalf of the Issuer or the Trustee.
Section 6.5. No Additional Waiver Implied by One Waiver; Consents to
Waivers. In the event any agreement contained in this Agreement should be
breached by either party and thereafter waived by the other party, such waiver
shall be limited to the particular breach so waived and shall not be deemed to
waive any other breach hereunder. No waiver shall be effective unless in writing
and signed by the party making the waiver. The Issuer shall have no power to
waive any default hereunder by the Company without the consent of the Trustee to
such waiver. The Trustee shall have the power to waive any default by the
Company hereunder, except a default under Section 3.4, 4.2(e), 4.2(g), 5.3 or
6.4 hereof, in so far as it pertains to the Issuer, without the prior written
concurrence of the Issuer. Notwithstanding the foregoing, if, after the
acceleration of the maturity of the outstanding Bonds by the Trustee pursuant to
Section 9.02 of the Indenture, (i) all arrears of principal of and interest on
the outstanding Bonds and interest on overdue principal and (to the extent
permitted by law) on overdue installments of interest at the rate of interest
borne by the Bonds on the date on which such principal or interest became due
and payable and the premium, if any, on all Bonds then Outstanding which have
become due and payable otherwise than by acceleration, and all other sums
payable under the Indenture, except the principal of and the interest on such
Bonds which by such acceleration shall have become due and payable, shall have
been paid, (ii) all other things shall have been performed in respect of which
there was a default, (iii) there shall have been paid the reasonable fees and
expenses of the Issuer, the Trustee and the Owners of such Bonds, including
reasonable attorneys' fees paid or incurred and (iv) such event of default under
the Indenture shall be waived in accordance with Section 9.09 of the Indenture
with the consequence that such acceleration
under Section 9.02 of the Indenture is rescinded, then the Company's default hereunder shall be deemed to have been waived and its consequences rescinded and no further action or consent by the Trustee or the Issuer shall be required; provided that there has been furnished an opinion of Bond Counsel to the effect that such waiver will not adversely affect the exemption from federal income taxes of interest on the Bonds.
Article VII
Options and Obligations of Company;
Prepayments; Redemption of Bonds
Section 7.1. Option to Prepay. The Company shall have, and is hereby granted, the option to prepay the payments due hereunder in whole or in part at any time or from time to time (a) to provide for the redemption of Bonds pursuant to the provisions of Section 3.01(A) of the Indenture or (b) to provide for the defeasance of the Bonds pursuant to Article VIII of the Indenture. In the event the Company elects to provide for the redemption of Bonds as permitted by this Section, the Company shall notify and instruct the Trustee in accordance with Section 7.3 hereof to redeem all or any portion of the Bonds in advance of maturity. If the Company so elects, any redemption of Bonds pursuant to Section 3.01(A) of the Indenture may be made conditional.
Section 7.2. Obligation to Prepay. The Company covenants and agrees that if all or any part of the Bonds are unconditionally called for redemption in accordance with the Indenture or become subject to mandatory redemption, it will prepay the indebtedness hereunder in whole or in part, prior to the date on which notice of such redemption is given to the owners of such Bonds, in an amount sufficient to redeem such Bonds on the date fixed for the redemption of the Bonds.
Section 7.3. Notice of Prepayment. Upon the exercise of the option granted to the Company in Section 7.1 hereof, or upon the Company having knowledge of the occurrence of any event requiring mandatory redemption of the Bonds in accordance with Section 3.01(B) of the Indenture, the Company shall give written notice to the Issuer, the Remarketing Agent, the Auction Agent and the Trustee. The notice shall provide for the date of the application of the prepayment made by the Company hereunder to the retirement of the Bonds in whole or in part pursuant to call for redemption and shall be given by the Company not less than 45 days prior to the date of the redemption which is to occur as a result of such prepayment (or such later date as is acceptable to the Trustee and the Issuer), and in the case of a redemption of Bonds pursuant to Section 3.01(B) of the Indenture shall be given on a date which will permit the redemption of the Bonds within the time required by Section 3.01(B) of the Indenture.
Article VIII
Miscellaneous
Section 8.1. Notices. Except as otherwise provided herein, all notices,
certificates or other communications hereunder shall be sufficiently given if in
writing and shall be deemed given when mailed by first class mail, postage
prepaid, or by qualified overnight courier service, courier charges prepaid, or
by facsimile (receipt of which is orally confirmed) addressed as follows: if to
the Issuer, at 1001 E. 9th Street, P.O. Box 11130, Reno, Nevada 89520, or to
telecopy number (775) 328-2037, Attention: County Manager; if to the Company, at
P.O. Box 10100, 6100 Neil Road, Reno, Nevada 89520, or to telecopy number (775)
834-5462, Attention: Treasurer; if to the Trustee, at 101 Barclay Street - 8W,
New York, New York 10286, or to telecopy number (212) 815-5096, Attention:
Corporate Trust Trustee Administration; if to the Remarketing Agent, at Lehman
Brothers, Inc., 200 Vesey Street, New York, New York 10285, Attention: Steve
Peters, or to telecopy number (212) 526-3738; and if to the Auction Agent, at
The Bank of New York, 100 Church Street, 14th Floor, New York, New York, 10286,
Attention: Dealing & Trading Group, Auction Desk, or to telecopy number (212)
437-7255. In case by reason of the suspension of regular mail service, it shall
be impracticable to give notice by first class mail of any event to the Issuer,
to the Company, to the Remarketing Agent, to the Auction Agent when such notice
is required to be given pursuant to any provisions of this Agreement, then any
manner of giving such notice as shall be satisfactory to the Trustee shall be
deemed to be sufficient giving of such notice. The Issuer, the Company, the
Trustee, the Remarketing Agent and the Auction Agent may, by notice pursuant to
this Section 8.1, designate any different addresses to which subsequent notices,
certificates or other communications shall be sent.
Section 8.2. Assignments. This Agreement may not be assigned by either party without consent of the other and the Trustee, except that the Issuer shall assign to the Trustee its rights under this Agreement (except under Sections 4.2(e), 4.2(g), 5.3, and 6.4 hereof) as provided by Section 4.4 hereof, and the Company may assign its rights under this Agreement to any transferee or any surviving or resulting corporation as provided by Section 5.1 hereof.
Section 8.3. Severability. If any provision of this Agreement shall be held or deemed to be or shall, in fact, be illegal, inoperative or unenforceable, the same shall not affect any other provision or provisions herein contained or render the same invalid, inoperative, or unenforceable to any extent whatever.
Section 8.4. Execution of Counterparts. This Agreement may be simultaneously executed in several counterparts, each of which shall be an original and all of which shall constitute but one and the same instrument.
Section 8.5. Amounts Remaining in Bond Fund. It is agreed by the parties
hereto that after payment in full of (i) the Bonds (or provision for payment
thereof having been made in accordance with the provisions of the Indenture),
(ii) the fees, charges and expenses of the Trustee in accordance with the
Indenture, (iii) the Administrative Expenses, (iv) the fees and expenses of the
Remarketing Agent, the Auction Agent and the Issuer and (v) all other amounts
required to be paid under this Agreement and the Indenture, any amounts remaining in the Bond Fund shall belong to and be paid to the Company by the Trustee.
Section 8.6. Amendments, Changes and Modifications. This Agreement may be amended, changed, modified, altered or terminated only by written instrument executed by the Issuer and the Company, and only if the written consent of the Trustee thereto is obtained. Subject to the written consent of the Trustee, the Issuer and the Company agree to enter into such amendments, changes and modifications to this Agreement (i) as may be required by the provisions of this Agreement or the Indenture, (ii) for the purpose of curing any ambiguity, formal defect or omission in this Agreement, (iii) so as to add additional rights acquired in accordance with the provisions of this Agreement, (iv) to preserve the exemption from federal income taxes of interest on the Bonds, or any of them, or (v) in connection with any other change herein which is not to the prejudice of the Trustee or the Owners of the Bonds; provided, however, that the Issuer shall not thereby incur any monetary obligation or liability (except only to the extent that the same shall be payable solely and only out of funds provided or to be provided by the Company) or surrender or abdicate in whole or in part any of its essential governmental functions or powers or any of its discretion in exercising the same.
Section 8.7. Governing Law. This Agreement shall be governed exclusively by and construed in accordance with the applicable laws of the State.
Section 8.8. Authorized Issuer and Company Representatives. Whenever under the provisions of this Agreement the approval of the Issuer or the Company is required to take some action at the request of the other, such approval of such request shall be given for the Issuer by the Authorized Issuer Representative and for the Company by the Authorized Company Representative, and the other party hereto and the Trustee shall be authorized to act on any such approval or request and neither party hereto shall have any complaint against the other or against the Trustee as a result of any such action taken.
Section 8.9. Term of the Agreement. This Agreement shall be in full force and effect from its date to and including such date as all of the Bonds issued under the Indenture shall have been fully paid or retired (or provision for such payment shall have been made as provided in the Indenture), provided that all representations and certifications by the Company as to all matters affecting the tax-exempt status of the Bonds and the covenants of the Company in Sections 4.2(c), 4.2(d), 4.2(e), 4.2(f) and 4.2(g) hereof shall survive the termination of this Agreement.
Section 8.10. Cancellation at Expiration of Term. At the acceleration, termination or expiration of the term of this Agreement and following full payment of the Bonds or provision for payment thereof and of all other fees and charges having been made in accordance with the provisions of this Agreement and the Indenture, the Issuer shall deliver to the Company any documents and take or cause the Trustee to take such actions as may be necessary to effectuate the cancellation and evidence the termination of this Agreement.
In Witness Whereof, the Issuer and the Company have caused this Agreement to be executed in their respective corporate names and their respective corporate seals to be hereunto affixed and attested by their duly authorized officers, all as of the date first above written.
Washoe County, Nevada
By
Chairman
Board of County Commissioners
(SEAL)
Attest:
Sierra Pacific Power Company
Attest:
Exhibit 10(P)
Amendatory Agreement No. 1
Contract No. DE-MS79-88BP92436
01/26/95
AMENDATORY AGREEMENT
executed by the
UNITED STATES OF AMERICA
DEPARTMENT OF ENERGY
acting by and through
BONNEVILLE POWER ADMINISTRATION
and
SIERRA PACIFIC POWER COMPANY
Index to Section
1. Amendment Term ................................................. 2 2. Exhibits ....................................................... 2 3. Provisions Relating to Delivery ................................ 2 4. Planning Information ........................................... 4 5. Scheduling Provisions .......................................... 5 6. Purchase Displacement Cost ..................................... 5 7. Points of Delivery ............................................. 5 8. System and Communication Upgrades .............................. 6 9. Power Factor ................................................... 7 10. FERC Application ............................................... 8 11. Status of Amendment ............................................ 8 12. Multiple Originals ............................................. 8 Exhibits revised, replaced, or added: Exhibit B (Points of Delivery and Points of Replacement) ...... 2 Exhibit C (Transfer Charges and Loss Factors) ................. 2 Exhibit E (Special Charges) ................................... 2 Exhibit F (Monthly Local Facility Charge for Carlin Area Upgrades) ...................................... 2 Exhibit G (Transmission Reservation) .......................... 2 Exhibit H (Termination Charge Methodology) .................... 2 Exhibit I (Determination of Local Facility Charge) ............ 2 Exhibit J (Sample Calculations of Annual Charges for Reduction in Service) .......................... 2 Exhibit K (Sample Calculations of Transmission Reservation Termination) ....................... 2 |
This AMENDATORY AGREEMENT, executed April 11, 1995, is entered into by the UNITED STATES OF AMERICA (Government), Department of Energy, acting by and through the Bonneville Power Administration (Bonneville), and SIERRA PACIFIC POWER COMPANY (Company), a corporation of the State of Nevada. Bonneville and Company are sometimes referred to collectively as "Parties."
WITNESSETH:
WHEREAS the Parties entered into a General Transfer Agreement (GTA), Contract No. DE-MS79-88BP92436, dated February 25, 1988, which provides, among other matters, for the transfer of electric power and energy to Wells Rural Electric Company (Wells). The Company is currently providing up to 45 MW of transfer service under the GTA. Bonneville delivers this electric power and energy at the Midpoint Point of Replacement; and
WHEREAS Bonneville has requested the Company provide additional firm transfer service to Bonneville's Wells load and the Company has expressed a desire to provide such additional transfer service. However, any additional transmission service which is provided by the Company is subject to the same terms and conditions as the existing 45MW of transfer service under the GTA until the time that system improvement s are completed that result in an increase of 200 MW or more to the Company's net import capability (System Improvements); and
WHEREAS the Company is undertaking local system additions and improvements required to serve the Carlin Area Customer loads, hereinafter referred to as the Carlin Area Upgrades, and Wells worked with the Company to choose the best plan of service at the lowest possible cost; and
WHEREAS Bonneville and the Company have agreed to undertake and participate in joint engineering studies to develop a long-range plan of service designed to address and resolve service limitations facing the Company's system; and
WHEREAS the Company and Idaho Power Company (Idaho) jointly own the North Valmy Electric Generation Station (Valmy), located near Battle Mountain, Nevada; and
WHEREAS Bonneville intends to provide, or arrange to provide, scheduled delivery of Valmy Generation to Carlin and Maggie Creek Subsidiaries; and
WHEREAS Bonneville and the Company have agreed that the northbound/Valmy schedules may be interrupted if the 345 kV line between Midpoint and Humboldt (Line No. 3419) is unavailable;
NOW, THEREFORE, in consideration of the promise and covenants contained herein, the Parties agree to amend the GTA as follows:
1. AMENDMENT TERM
This Amendment shall be effective after Rural Electrification Administration approval of Revision No. 1 to Exhibit L of the Power Sales Contract (Contract No. DEMS79-81BP90571) between Bonneville and Wells and upon Federal Energy Regulatory Commission (FERC) acceptance of this Amendment in its entirety and without change ("Amendment Effective Date") and shall continue in effect concurrent with the term specified in section 1 of the GTA. If FERC does not accept this Amendment in its entirety and without change, the Parties shall determine whether both Parties are willing and able to modify this Amendment to comply with such FERC order. If the Parties are unable to reach an acceptable modification within a 30-day period, the Parties shall exercise best efforts to negotiate alternative arrangements to meet the same goals.
2. EXHIBITS
Section 3 of the GTA is amended to read as follows:
"Exhibits A through J and any revisions thereto are made a part of this Agreement. The Company shall be the Transferor and Bonneville's Customer shall be the Transferee mentioned in Exhibit A."
3. PROVISIONS RELATING TO DELIVERY
Section 4(a) of the GTA is amended to read as follows:
"(a) Electric power and energy shall be made available by the Company at all times during the term hereof at the points of delivery described in Exhibit B (Points of Delivery), in the amount of Bonneville's Customer's requirements at such points and the approximate voltages specified therein; provided however, that Bonneville shall make available, pursuant to section 5, electric power and energy at the Points of Replacement specified in Exhibit B; provided, further, that the Transfer Trip load as defined in section 4(f), may be interrupted:
(1) in the event of an outage on the Midpoint-Humboldt-Coyote Creek 345 kV transmission lines which reduces the Company's import capability, or
(2) in the event of an outage on the Company's 120 kV transmission system serving the Carlin area and the Company is unable to serve both the Company's customer loads and Bonneville's Customer loads, in which case interruption of the loads will be shared equitably between the Parties, or
(3) in the event of Loss of Line No. 3419 and the Company is unable to provide service to Bonneville's loads from inside the Company's import boundary.
In no event shall the Company be obligated to import electric power and energy hereunder at a demand level in excess of the import demand limit specified in Exhibit B, except where otherwise agreed. If any of Bonneville's Customer's load is interrupted, the Company may provide service pursuant to section 6 of the GTA.
In the event insufficient import capability to the Company's system exists, Bonneville shall provide power in excess of the demand limit from inside the Company's import boundary in a manner specified by the Company, or reduce deliveries accordingly. The Company will give priority to residential customers and other critical loads in its use of Valmy Generation."
4. PLANNING INFORMATION
Section 4(c) of the GTA is amended to read as follows:
"(c) Bonneville shall submit, within 45 days following acceptance by FERC for filing (Filing Date), a one-time 10-year forecast listing peak demands, by Point of Delivery, for each calendar month of the 10-year period. This forecast shall be incorporated in Exhibit G. Then, beginning in year 6 of this Amendment and continuing for the term of this Agreement, Bonneville shall submit, by July 1 of each year, a 5-year forecast of peak demands by Points of Delivery, for each calendar month of the 5-year period. Exhibit G attached hereto shall be modified each July 1 to incorporate the fifth year of such 5-year forecast. Such information shall be relied upon by the Company for system and marketing planning.
In the event Bonneville desires to increase forecast demands for a month or months for which a forecast peak demand has been previously established, the Company shall, at its sole discretion, determine whether such incremental capacity can be made available to Bonneville. In the event the Company is unable to serve the incremental demand requested by Bonneville, it shall provide notice of its inability to do so within 60 days of Bonneville's increased Exhibit G forecast submittal. The Company may, but shall not be obligated under this Agreement to, provide import capacity in excess of the amounts established pursuant to Exhibit G of this Agreement.
In the event Bonneville desires to reduce the forecast demands of this Agreement, the Company shall made a reasonable effort to market the resulting excess capacity reserved for Bonneville; however, if this excess capacity becomes unused, Bonneville will be subject to a Charge for Reduction of Service as shown in Exhibits E and G."
5. SCHEDULING PROVISIONS
Section 8(a) of the GTA is amended to read as follows:
"(a) Bonneville shall provide, or arrange to have provided, a separate schedule to the Company for each hour, to the Points of Replacement or to other mutually agreeable points of replacement, for the following:
(1) in accordance with section 5 of the GTA, electric power and energy which the Company will deliver to Bonneville's Customers at the Points of Delivery; and
(2) in accordance with section 6 of the GTA, any emergency power requested for such hour by the Company which Bonneville determined can be made available."
6. PURCHASE DISPLACEMENT COST
Section 9(h) shall become section 9(e) and the previous sections 9(e), 9(f) and 9(g) of the GTA are deleted in their entirety.
7. POINTS OF DELIVERY
Section 11(b) of the GTA is amended to read as follows:
"(b) If Bonneville desires the Company to provide transfer service to new points of delivery, add additional capacity at existing Points of Delivery, or increase demand limits as specified in Exhibit B to serve Bonneville's load growth or new loads within Well's service territory, then Bonneville shall make a written request to the Company as early as possible prior to the date Bonneville requests such change to be effective. Bonneville's written request shall include the transfer capacity requirement and required energization date. The Company shall respond in writing to Bonneville's request within 60 days of such request.
In the event of any disputes regarding the Company's response, Bonneville retains any rights it otherwise has to resolve the dispute."
8. SYSTEM AND COMMUNICATION UPGRADES
This section shall be added and designated as section 23 of the GTA and shall read as follows:
"23. SYSTEM AND COMMUNICATION UPGRADES
(a) The Company intends to provide and operate Carlin Area Upgrades sufficient to serve approximately 300 MW of load which will accommodate 350 to 385 MVA of fault duty at the Maggie Creek substation 120 kV bus. Such equipment shall be in service prior to an agreed-upon date. The Bonneville share of the Carlin Area Upgrades shall consist of thirty-three percent (33%) of the new Bell Creek Switch Station, fifty percent (50%) of the Coyote Creek Substation expansion, one hundred percent (100%) of the Maggie Creek Switch Station expansion, and one hundred percent (100%) of the new Bell Creek to Maggie Creek 120 kV transmission line. The Bonneville share of the Carlin Area Upgrades is estimated as $9,258,000. This amount shall be adjusted upward or downward in the event the Company's actual cost of construction, rounded to the nearest thousand, varies from the estimate. Bonneville shall be allowed 2 years from the completion of the construction to perform an audit of the final construction expenditures and to dispute payment of expenditures based upon the audit. The Company shall bear its pro-rata share of any increase or decrease in the costs resulting from Bonneville's audit. Bonneville and the Company agree to act in good faith to resolve any conflicts or disagreements regarding costs, cost allocations, overheads, or any other direct assignments affecting the Local Facility Charge. Bonneville shall pay the Company for its share of the Carlin Area Upgrades as specified in Exhibits E and F. Prior to the
installation of the System Improvements, any transfer service shall be designated as Transfer Trip Load.
(b) The Company, at Bonneville's expense, shall design and install selective/redundant transfer trip and communication equipment to accommodate Bonneville's request for an increase in transfer services. Such equipment shall be in service prior to an agreed upon date of any increase in the transfer services as provided for in section 23(a). The Company shall provide to Bonneville an itemized statement of the expenses incurred for such equipment. Bonneville shall pay the Company within 30 calendar days following the Amendment Effective Date, including related taxes incurred by the Company, if required."
9. POWER FACTOR
This section shall be added and designated as section 25 of the GTA and shall read as follows:
"25. POWER FACTOR
The on-peak power factor at the Points of Delivery specified in Exhibit B shall be within ninety-eight percent (98%) leading or lagging. The power factor for all other hours shall be within ninety-five percent (95%) leading or lagging.
The on-peak hours shall be defined as follows:
Months On-Peak Hours October through May 5:01 p.m. to 10:00 p.m. daily June through September 10:01 a.m. to 10:00 p.m. daily |
Bonneville shall provide the Company with access to Bonneville's meters associated with Bonneville's Points of Delivery specified in Exhibit B."
10. FERC APPLICATION
Section 13(d) of the GTA is added and shall read as follows:
"(d) Nothing herein is intended to limit the rights of Bonneville
to make application to FERC for a change in rates under
Section 206 of the Federal Power Act and pursuant to FERC's
Rules and Regulations promulgated thereunder."
11. STATUS OF AMENDMENT
It is expressly understood and agreed by the Parties that all the terms, conditions, and provisions of this Agreement are made part of the GTA upon the Amendment Effective Date as though the GTA were expressly rewritten to incorporate and include the contents of this Amendment. None of the terms or conditions in this Amendment shall be considered a precedent for any future agreement between the Parties.
12. MULTIPLE ORIGINALS
Two (2) copies of this Amendment have been executed by the Parties. Each executed copy shall be deemed an original.
IN WITNESS WHEREOF, the Parties hereto have executed this Amendment.
UNITED STATES OF AMERICA
Department of Energy
Bonneville Power Administration
SIERRA PACIFIC POWER COMPANY
Exhibit 10(Q)
Amendatory Agreement No. 2
Contract No. DE-MS79-88BP92436
Effective at 2400 Hours on the
Amendment Effective Date
AMENDATORY AGREEMENT
executed by the
UNITED STATES OF AMERICA
DEPARTMENT OF ENERGY
acting by and through
BONNEVILLE POWER ADMINISTRATION
and
SIERRA PACIFIC POWER COMPANY
1. Amendment Transfer Service....................................... 2
2. Amendment Term................................................... 2
3. Provisions Relating to Delivery.................................. 2
4. Payment for Transfer of Power.................................... 3
5. Status of Amendment.............................................. 3
6. Multiple Originals............................................... 3
Exhibits revised
Exhibit B (Points of Delivery and Points of Replacement)........ 1
Exhibit C (Transfer Charges and Loss Factors)................... 1
This AMENDATORY AGREEMENT, executed July 5, 2000, is entered into by the UNITED STATES OF AMERICA (Government), Department of Energy, acting by and through the Bonneville Power Administration (Bonneville), and SIERRA PACIFIC POWER COMPANY (Company), a corporation of the State of Nevada. Bonneville and Company are sometimes referred to collectively as "Parties."
WITNESSETH:
WHEREAS, the Parties entered into a General Transfer Agreement (GTA), Contract No. DE-MS79-88BP92436, dated February 25, 1988 and amended April 11, 1995, which provides, among other matters, for the transfer of electric power and energy to Wells Rural Electric Company (Wells). The Company is currently providing up to 65 MW of transfer service under the GTA. Bonneville delivers this electric power and energy at the Hilltop Point of Replacement (POR); and
WHEREAS, the Company has completed construction on a 345 kilovolt (kV) transmission line between the Company's North Valley Road Substation in Reno, Nevada and the Company's Hilltop Substation near Alturas, California (Reno-Alturas Transmission Project); and
WHEREAS, the Reno-Alturas Transmission Project is interconnected to Bonneville's Malin-Warner 230 kV Line (Malin-Warner Line); and
WHEREAS, Bonneville has by letter dated August 3, 1998 exercised its option to transfer its POR from Midpoint to Hilltop;
NOW, THEREFORE, in consideration of the promises and covenants contained herein, the Parties agree to amend the GTA as follows:
1. AMENDMENT TRANSFER SERVICE
Exhibit B of the GTA is amended pursuant to the following:
"Company shall provide service under the GTA up to a total demand limit of 110 MW, including service delivered pursuant to Contract Number DE-MS79-79BP90000, to include Maggie Creek, Carlin, McNabb, Jiggs Lee, and Winnemucca. Point of Replacement shall be at the Hilltop Point of Interconnection.
2. AMENDMENT TERM
Subject to the approval of the Federal Energy Regulatory Commission, this Amendment shall be effective at 2400 hours on the date of execution (Amendment Effective Date).
3. PROVISIONS RELATING TO DELIVERY
Section 4(a) of the GTA is amended to read as follows:
"(a) Electric power and energy shall be made available by the Company at all times during the term hereof at the points of delivery described in Exhibit B (Points of Delivery), in the amount of Bonneville's Customer requirements at such points and at the approximate voltages specified therein; provided, however, that Bonneville shall make available, pursuant to section 5, electric power and energy at the Points of Replacement specified in Exhibit B; provided, however, that in the event of an outage on the Company's 120 kV transmission system serving the Carlin area and the company is unable to serve both the Company's customer loads and Bonneville's Customer loads, in which case, to the extent possible, interruption of the loads will be shared equitably between the Parties.
In no event shall the Company be obligated to import electric power and energy hereunder at a demand level in excess of the import demand limit specified in Exhibit B, except where otherwise agreed. If any of Bonneville's Customer load is interrupted, the Company may provide service pursuant to section 6 of the GTA.
In the event insufficient import capability to the Company's system exists, Bonneville shall provide power in excess of the demand limit from inside the Company's import boundary in a manner specified by the Company, or reduce deliveries accordingly. The Company will give priority to residential customers and other critical loads in its use of Valmy Generation."
4. PAYMENT FOR TRANSFER OF POWER
Section 9(a) of the GTA is amended to read as follows:
"(a) For the use of Company services and facilities in transferring electric power and energy hereunder, Bonneville shall pay the Company each month in the term hereof an amount equal to the sum for all Points of Delivery of the greater of (1), (2) or (3) below for each point of delivery; provided however, that certain Points of Delivery shall be coincidentally combined as specified in Exhibit B".
Section 9(a)(3) of the GTA is amended to read as follows:
"(3) The product of [1] the Transmission Reservation shown in Exhibit G for the current month and [2] the Transfer Charge."
5. STATUS OF AMENDMENT
It is expressly understood and agreed by the Parties that all the terms, conditions, and provisions of this Amendment are made part of the GTA upon the Amendment Effective Date as though the GTA were expressly rewritten to incorporate and include the contents of this Amendment. None of the terms or conditions in this Amendment shall be considered a precedent for any future agreement between the Parties.
6. MULTIPLE ORIGINALS
Two (2) copies of this Amendment have been executed by the Parties. Each executed copy shall be deemed an original.
IN WITNESS WHEREOF, the Parties hereto have executed this Amendment.
SIERRA PACIFIC POWER COMPANY UNITED STATES OF AMERICA Department of Energy Bonneville Power Administration By: By: ---------------------------------------- ------------------------------- Name: Gary Porter Name: Patrick McRae Title: Executive Director of Transmission Title: Manager, Transmission & Reserve Services - PBL Date: 6/30/00 Date: 7/5/00 |
Amendatory Agreement No. 2 Exhibit B, Page 1 of 4 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
POINTS OF DELIVERY AND POINTS OF REPLACEMENT
A. Carlin Substation Point of Delivery - Not to exceed 10MW without prior notification and approval by Company
Bonneville Customer: Wells.
Location: The point near Wells Carlin Substation where the 115 kV facilities of the Company and Wells are connected.
Voltage: 120kV.
Metering: Coincidentally with the Maggie Creek Point of Delivery, Jiggs Lee Point of Delivery, and McNabb Point of Delivery, at the following locations:
(1) Carlin Point of Metering: In Wells' Carlin Substation in the 25kV circuit over which such electric power and energy flows.
(2) Rain Point of Metering: In the Rain Point of Delivery located on Wells' Pine Valley 14.4 / 24.9 kV distribution line where Wells delivers power and energy to the Company's load.
(3) Sprint Point of Metering: In the U.S. Sprint Point of Delivery on Wells' Pine Valley 14.4 / 24.9 kV distribution line where Wells delivers power and energy to the Company's load.
Demand Limit: Service to this Point of Delivery shall not exceed 10 MW without prior notification and approval by the Company. Service to this Point of Delivery, the Maggie Creek Point of Delivery, the McNabb Point of Delivery, the Jiggs Lee Point of Delivery, and the demand pursuant to Contract Number DE-MS-79-79BP90000, shall not exceed 110 MW, plus losses as specified in Exhibit C.
Adjustment: There shall be an adjustment for losses between the Points of Metering and the Point of Delivery.
Amount of Power Delivered: The amount of electric energy and reactive power delivered hereunder and each of the Integrated Demands for any hour during the term hereof shall be the sum of the following:
Amendatory Agreement No. 2 Exhibit B, Page 2 of 4 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
(1) the amount metered at the Carlin Point of Metering, after adjusting losses as specified in the GTA, less the sum of the amount metered at the Rain Point of Metering, after adjusting for losses as specified above, and the U.S. Sprint Point of Metering, after adjusting for losses as specified above;
(2) the amount metered at the Maggie Creek Point of Metering, as described below, after adjusting for losses as specified above;
(3) the amount metered at the McNabb Point of Metering, as described below, after adjusting for losses as specified above;
(4) the amount metered at the Jiggs Lee Point of Metering, as described below, after adjusting for losses as specified above; and
(5) the amount metered under Contract Number DE-MS79-79BP9000 for the Harney Winnemucca Point of Metering.
B. Maggie Creek Point of Delivery - Not to exceed 85 MW without prior notification and approval by SPPCo.
Bonneville Customer: Wells.
Location: The point in the Company's Eightmile Creek-Maggie Creek 120 kV transmission line where the tap to Wells' Gold Quarry Substation is connected.
Voltage: 120kV.
Metering: Coincidentally with the Carlin Substation, Jiggs Lee Point of Delivery, and McNabb Points of Delivery, in Maggie Creek Substation on the 120 kV line to Gold Quarry.
Demand Limit: Service to this Point of Delivery shall not exceed 85 MW without prior notification and approval by Company. Service to this Point of Delivery, the Carlin Substation Point of Delivery, the McNabb Point of Delivery, the Jiggs Lee Point of Delivery, and the demand pursuant to Contract Number DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as specified in Exhibit C.
Amount of Power Delivered: The amount of electric power and energy delivered shall be determined coincidentally with the Carlin Substation Point of Delivery, the Jiggs Lee Point of Delivery, and the McNabb Point of Delivery as specified in the GTA, as well as
Amendatory Agreement No. 2 Exhibit B, Page 3 of 4 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
the amount metered under Contract Number DE-MS79-79BP9000 for the Harney Winnemucca Point of Metering.
Adjustment: There shall be an adjustment for losses between the Point of Metering and the Point of Delivery.
C. McNabb Point of Delivery - Not to exceed 500 kW without prior notification and approval by the Company.
Bonneville Customer: Wells.
Location: The point in the Company's Tonkin Springs-Cortez Tap 60 kV transmission line where the tap to Wells' McNabb substation is located.
Voltage: 60 kV.
Metering: Coincidentally with the Carlin Substation, Jiggs Lee Point of Delivery, and Maggie Creek Points of Delivery, in McNabb Substation on the 14.40 kV side of the 60 / 14.4 kV transformer.
Demand Limit: Service to this Point of Delivery shall not exceed 500 kW without prior notification and approval by Company. Service to this Point of Delivery, the Carlin Substation Point of Delivery, the Maggie Creek Point of Delivery, Jiggs Lee Point of Delivery, and the demand pursuant to Contract Number DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as specified in Exhibit C.
Amount of Power Delivered: The amount of electric power and energy delivered shall be determined coincidentally with the Carlin Substation Point of Delivery, the Jiggs Lee Point of Delivery, and the Maggie Creek Point of Delivery as specified in the GTA, as well as the amount metered under Contract Number DE-MS79-79BP9000 for the Harney Winnemucca Point of Metering.
Adjustment: There shall be an adjustment for losses between the Point of Metering and the Point of Delivery.
D. Jiggs Lee Point of Delivery - Not to exceed 2 MW without prior notification and approval by Company.
Bonneville Customer: Wells.
Amendatory Agreement No. 2 Exhibit B, Page 4 of 4 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
Location: The point in the Company's 208 Distribution line where Company connects to Wells distribution line. The point in the Company's 208 Distribution line where the Service territory starts.
Voltage: 24.9 kV.
Metering: The point in the Company's 208 Distribution line where Company connects to Wells distribution line where the Service territory starts.
Demand Limit: Service to this Point of Delivery shall not exceed 2MW without prior notification and approval by Company. Service to this Point of Delivery, the Carlin Substation Point of Delivery, the Maggie Creek Point of Delivery, the McNabb Point of Delivery, and the demand pursuant to Contract No. DE-MS79-79BP90000, shall not exceed 110 MW, plus losses as specified in Exhibit C.
Amount of Power Delivered: The amount of electric power and energy delivered shall be determined coincidentally with the Carlin Substation Point of Delivery and the Maggie Creek Point of Delivery as specified in the GTA, as well as the amount metered under Contract Number DE-MS79-79BP9000 for the Harney Winnemucca Point of Metering.
Adjustment: There shall be an adjustment for losses between the Point of Metering and the Point of Delivery.
E. Points of Replacement
Hilltop Point of Replacement
Location: The 230 kV bus at the Hilltop Substation where the Company has a right to accept deliveries of power and energy from Bonneville.
Voltage: 230/345 kV.
Valmy Point of Replacement
Location: The 345 kV bus at the Company's Valmy Substation. This Point of Replacement is to be used for amounts scheduled from Valmy.
Voltage: 345 kV.
Amendatory Agreement No. 2 Exhibit C, Page 1 of 1 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
TRANSFER CHARGES AND LOSS FACTORS
Transfer Charge/1/ Transfer Trip Load Loss Factor/2/ Point of Delivery ($/kW-mo) (MW) (%) Carlin Substation 3.40 0 4.0 Maggie Creek 3.40 0 4.0 McNabb 3.40 0 4.0 Jiggs Lee 3.40 0 4.0 ---------- |
/1/ Transfer charge at the FERC-approved rate.
/2/ Based on Company average incremental transmission losses, from Schedule RT, section T-1, Transmission Service, which is reviewed and adjusted as necessary.
Amendatory Agreement No. 2 Exhibit G, Page 1 of 1 Contract No. DE-MS79-88BP92436 Sierra Pacific Power Company Effective at 2400 Hours on the Amendment Effective Date
TRANSMISSION RESERVATION
1. The forecast monthly peak ("Transmission Reservation") given below, in megawatts, shall be the basis for calculating the minimum monthly reservation fee, ie: Transmission Reservation* $3.40kW mo.
2. For the period of August 1995 through July 2000, the annual Transmission Reservation, as applied in Exhibit E, shall be no less than 100 percent of the forecast monthly peak demand given below.
3. For the period of August 2000 through July 2005, the annual Transmission Reservation shall be no less than 85 percent of the forecast monthly peak demand given below, in megawatts.
-------------------------------------------------------------------------------------- 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 -------------------------------------------------------------------------------------- Jan 70.61 71.61 71.61 70.0 70.0 70.1 70.2 70.3 70.3 70.4 -------------------------------------------------------------------------------------- Feb 70.51 71.51 71.51 70.1 70.2 70.3 70.3 70.4 70.5 70.6 -------------------------------------------------------------------------------------- Mar 69.80 70.80 70.80 69.3 69.3 69.4 69.4 69.5 69.6 69.6 -------------------------------------------------------------------------------------- Apr 69.29 70.26 70.26 69.2 69.2 69.3 69.3 69.4 69.5 69.5 -------------------------------------------------------------------------------------- May 69.71 70.71 70.71 68.6 68.6 68.7 68.7 68.8 68.8 68.9 -------------------------------------------------------------------------------------- Jun 71.56 72.56 72.56 68.2 68.2 68.3 68.3 68.4 68.4 68.5 -------------------------------------------------------------------------------------- Jul 69.64 69.64 70.64 69.64 68.6 68.7 68.7 68.8 68.8 68.9 69.0 -------------------------------------------------------------------------------------- Aug 69.71 69.71 70.71 69.71 68.3 68.4 68.4 68.5 68.5 68.6 68.6 -------------------------------------------------------------------------------------- Sep 69.29 69.29 70.29 69.29 68.6 68.6 68.7 68.7 68.8 68.9 68.9 -------------------------------------------------------------------------------------- Oct 69.76 69.76 70.76 69.76 68.4 68.4 68.5 68.5 68.6 68.6 68.7 -------------------------------------------------------------------------------------- Nov 70.22 70.22 71.22 70.22 69.5 69.6 69.6 69.7 69.8 69.9 69.9 -------------------------------------------------------------------------------------- Dec 70.48 70.48 71.48 70.48 70.0 70.1 70.1 70.2 70.3 70.4 70.5 -------------------------------------------------------------------------------------- |
4. Transmission Reservations for years after July 5, 2004, through 2010 shall be subject to a Charge for Reduction of Service based on 85 percent of the Forecasted Monthly Peak Demand.
AMENDMENT TERM
Subject to the approval of the Federal Energy Regulatory Commission, this Amendment shall be effective at 2400 hours on the date of execution (Amendment Effective Date) with no adjustments for prior periods under the terms and conditions of Amendment.
Exhibit 10(R)
COAL SALES AGREEMENT
THIS AGREEMENT, effective the 1st day of January, 2002, by and between SIERRA PACIFIC POWER COMPANY, a Nevada Corporation, ("BUYER") with its principal place of business at 6100 Neil Road, Reno, Nevada and ARCH COAL SALES COMPANY, INC., a Delaware corporation, individually and as Agent for Canyon Fuel Company, LLC and the independent operating subsidiaries of Arch Coal, Inc., a Delaware corporation (collectively as "SELLER") with its principal place of business at CityPlace One, Suite 350, St. Louis, Missouri.
WHEREAS, BUYER is a Nevada Public Utility Corporation engaged in the generation, transmission and distribution of electric power and owns and operates the North Valmy Generation Station near Battle Mountain, Nevada ("Station"), with Idaho Power Company ("IPC") owning fifty percent (50%) of the Station; and
WHEREAS, SELLER represents and warrants it is capable of supplying coal to BUYER in accordance with the specifications and terms and conditions set forth herein ("Coal"); and
WHEREAS, the operation of the Station is subject to stringent air quality and other regulations and BUYER and IPC desire to achieve operational efficiencies, the Coal must meet the specifications set forth herein.
NOW, THEREFORE, in consideration of the mutual covenants contained herein, and intending to be legally bound hereby, BUYER and SELLER agree as follows:
I. TERM
Unless sooner terminated or canceled, the term of this Agreement ("Term") shall be five (5) years commencing January 1, 2002 and ending December 31, 2006.
II. SOURCE MINES
A. The Coal supplied hereunder shall be produced from SELLER's Sufco, Skyline and Dugout Canyon ("Dugout") mines located in Emery and Sevier Counties, Utah (collectively the "Mines"). SELLER represents and warrants that it has dedicated the Mines to the performance of this Agreement subject to ARTICLE X. QUALITY SPECIFICATIONS, Section F below. SELLER shall have the right to direct which of the Mines will originate shipments in accordance with ARTICLE IV. ORDERING. SELLER shall use reasonable efforts to maximize shipments from Sufco, and in no event, shall shipments from Sufco be less than 350,000 tons during the period July 1, 2003 through December 31, 2003 and 700,000 tons per year in 2004 through 2006. Additionally, shipments from Dugout shall be no more than 500,000 tons in any calendar year during the Term of this Agreement. Currently, no shipments are anticipated to come from Sufco during calendar year 2002.
B. SELLER represents and warrants that the Mines contain a sufficient quantity of economically recoverable coal that meets the quality specifications and quantity requirements of this Agreement. SELLER further warrants that the title to all Coal delivered under this Agreement shall be good and that such Coal shall be delivered free from any claim, lien or other encumbrance. SELLER shall indemnify BUYER against any and all expenses, damages, and liabilities resulting from breach of this warranty.
C. Subject to the prior written approval of BUYER, SELLER shall have the right to supply coal from sources other than the Mines ("Substitute Coal"), subject to all other terms and conditions of this
Agreement, provided that any Substitute Coal shall not result in a higher delivered price to BUYER calculated in dollars per million Btu F.O.B. the Station than the price in effect for Skyline under this Agreement at the time of shipment of the Substitute Coal, and provided further that Substitute Coal shipments shall not reduce coal deliveries from Sufco below the levels set forth in ARTICLE II. SOURCE MINES, Section A.
D. BUYER shall have the right to divert shipments to the following generating stations:
Pinon Pine, Sparks, Nevada
Reid Gardner, Moapa, Nevada
Jim Bridger, Point of Rocks, Wyoming
Boardman, Castle, Oregon
III. QUANTITY
A. The quantity of Coal to be delivered and purchased hereunder on an annual basis shall be the base tonnage specified in the table below ("Base Tons"). At the BUYER'S sole option, the annual Base Tons may be decreased by the amount specified in the table below ("Reduced Tonnage Option"). The BUYER'S Reduced Tonnage Option shall only be valid with respect to the specified calendar year and the annual Reduced Tonnage Option volumes shall not carry over to the next calendar year.
Base Tons Reduced Tonnage --------- --------------- January 1 - December 31, 2002 1,030,000 0 January 1 - December 31, 2003 1,200,000 0 January 1 - December 31, 2004 1,600,000 75,000 January 1 - December 31, 2005 1,600,000 75,000 January 1 - December 31, 2006 1,600,000 75,000 |
B. As BUYER intends to take delivery in unit trains, actual tonnage delivered during any calendar year may differ slightly from the Base Tons (less any Reduced Tonnage) in order to accommodate deliveries in unit train lots. Provided, however, that the amount of over-shipment or under-shipment in any calendar year shall be no more than 10,000 Tons of Coal. Differences resulting from truing up of actual deliveries (but not including variances in deliveries due to an event of force majeure) with Base Tons (less any Reduced Tonnage) during any calendar year will be carried over into the following contract year such that the Base Tons for the following year would be decreased or increased by an amount which takes these differences into account. Additionally, BUYER and SELLER agree that up to 50,000 tons of coal per year may be carried into the next calendar year, and shall be delivered by SELLER to BUYER during the first calendar quarter of such calendar year under a mutually agreeable shipment schedule and at the price in effect for the calendar year in which the Coal was originally scheduled for delivery. BUYER and SELLER agree that the Term of this Agreement may be extended for up to three months to allow for the delivery of such Coal.
C. BUYER shall have the right to resell the Base Tons in any calendar year to a third party, provided however, that SELLER shall have the right, but not the obligation to purchase said amount of Coal from BUYER at the price BUYER could otherwise resell the Coal to the third party. In such cases, BUYER will notify SELLER of its intent to resell any coal sold hereunder, specifying the price, volume, and term, and unless otherwise agreed, SELLER shall then have three business days to exercise its right to repurchase said Coal. BUYER agrees to identify the amount of Coal intended for resale as part of the shipment scheduling requirements set forth in ARTICLE IV. ORDERING, Section B. Additionally, all terms and conditions contained in this Agreement between BUYER and SELLER shall apply to all Coal resold in accordance with this ARTICLE III. QUANTITY, Section C.
IV. ORDERING
A. Shipments utilizing one unit train set will be scheduled on an approximate ratable basis. Further, the parties recognize that BUYER will schedule a second unit train set from time to time and that the operation of the second train set will cause total monthly shipments to be substantially in excess of the approximate ratable basis utilizing one trainset.
B. BUYER shall notify SELLER on or before the fifteenth day of each month of the quantity of Coal to be shipped during the following month. (ie, BUYER will notify SELLER on or before January 15th of the amount of Coal to be shipped during February.) In addition, BUYER shall provide SELLER with its best estimate of the quantity of Coal to be shipped during the following eleven months. Within five days of receipt of BUYER's notice, SELLER shall respond in writing, or by facsimile or electronic mail, to BUYER confirming BUYER's schedule and specifying the source of each of the following month's shipments among Sufco, Skyline and Dugout. In addition, SELLER's response shall also include its best estimate of the sources of the projected quantities of Coal for the following eleven months.
In the event SELLER is required to estimate future Coal deliveries beyond the twelve-month period, then the following percentage amounts shall be used as an estimate of Coal deliveries from SELLER'S Mines, and shall become effective in the first month following the twelve month forecast period described hereunder:
Sufco Skyline Dugout ----- ------- ------ 2003 29% 56% 15% 2004-2006 44% 46% 10% |
V. DELIVERY
SELLER shall at its own expense transport to and load the Coal into rail cars F.O.B. at the following loading facilities ("Loading Facilities"):
Sufco - Levan (Sharp), Utah
Skyline - Skyline, Utah
Dugout - Savage Coal Terminal, Wellington, Utah
VI. SHIPMENTS
A. SELLER shall load the Coal in quantities suitable for unit train loading, consisting of approximately 85 rail cars in accordance with the provisions of ARTICLE IX. SAMPLING AND ANALYSIS. SELLER shall load the Coal in compliance with the rules and regulations as published in the Union Pacific Railroad Company's Circular UP 6602, General Rules for Loading and Handling Coal Trains Originating in Colorado and Utah ("Circular UP 6602"), as amended from time to time, except that Free Time for loading trains at Sharp, Utah shall be four hours. SELLER shall be liable for all demurrage or related charges assessed due to SELLER's failure to comply with the requirements in Circular UP 6602. BUYER shall have the right to increase the number of rail cars in each unit train. However, in no event shall SELLER be required to load more than 11,000 tons in three hours or load unit trains greater than 105 railcars.
B. SELLER shall have the obligation to conform to restrictions on maximum allowable weights as specified in Circular UP 6602, as amended from time to time. SELLER shall be responsible for performing and bearing all costs of removal of excess Coal and all related charges assessed by the railroad for overloading, including but not limited to set out and storage charges.
C. SELLER shall be liable for any incremental transportation charges assessed to BUYER as a result of SELLER's failure to load cars to a minimum car weight of 113 net tons for railcars in a trainload consisting of aluminum 286,000 gross net weight in pounds railcars, and 98 net tons for railcars in a trainload consisting of steel/aluminum 263,000 gross net weight in pounds railcars. BUYER shall have the right to specify new and revised minimum railcar weights from time to time.
D. Rail transportation shall be ordered by BUYER and shall be paid for by "BUYER except when shipments are rejected or acceptance of shipments is revoked by BUYER, which, in such event rail transportation costs will be borne by SELLER. SELLER shall make reasonable efforts to make the necessary arrangements with the railroad for the placement of railcars at the Loading Facility in accordance with the rail transportation arrangements made by BUYER.
E. Upon arrival of each train at SELLER's Loading Facility and prior to commencing loading, SELLER shall make reasonable efforts to check each car for the presence of foreign material and check that each car door is closed and locked.
F. Upon the loading of each train for shipment, SELLER shall promptly fax a shipping notice to: North Valmy Generation Station; Attention: North Valmy Plant Administration; (FAX #: 775-834-3164). The shipping notice shall include the shipment date, shipment number, car initials and numbers, tonnages and the trainload identification numbers.
VII. TITLE AND RISK OF LOSS
Title and risk of loss of the Coal shall pass from SELLER to BUYER as the Coal is progressively loaded into railcars to be provided by BUYER.
VIII. WEIGHING
A. For billing and all other purposes under this Agreement, the weight of the Coal delivered hereunder shall be determined by certified weighing systems at the Loading Facilities when the Coal is loaded. At its expense, SELLER shall directly (or, in the case of Savage Coal Terminal cause the Loading Facility Operator to) inspect, test and calibrate the weighing and measuring devices at least semiannually in accordance with accepted methods. SELLER shall provide copies of the scale certification reports to BUYER. SELLER shall notify BUYER at least seven days prior to such testing and BUYER shall have the right to have a representative present to observe such weighing inspections or tests.
B. If SELLER's scales are determined to be in error in excess of two-tenths of one percent (.2%) as determined by such inspection and certification, an appropriate adjustment shall be made to the Coal's weight and related invoices and payments. Such adjustment shall be retroactive to the time of the error if such time can be factually ascertained. If the time of error cannot be ascertained, it will be deemed to be one-half the time between the last certification of such scales and the time the error in weighing was corrected.
IX. SAMPLING AND ANALYSIS
A. SELLER warrants that Coal samples will be taken in accordance with ASTM standards at the Loading Facilities.
B. For the purposes of determining conformance of each shipment of Coal to ARTICLE X. QUALITY SPECIFICATIONS, or any other provision of this Agreement, a representative sample of the Coal shall be collected, as set forth in Section C of this ARTICLE IX. SAMPLING AND ANALYSIS, below, in accordance with ASTM standard methods at the Loading Facility as Coal is loaded into
each unit train. BUYER may, at its own risk and expense, have a representative present to observe such sampling. The presence of BUYER's representative at the time SELLER samples the Coal does not relieve the SELLER of its obligations to sample and analyze the Coal in conformance with the terms and conditions of this ARTICLE IX. SAMPLING AND ANALYSIS.
C. SELLER shall cause a representative sample to be taken in accordance with ASTM standards at the Loading Facility as Coal is loaded into each unit train. The sample shall be taken by an ASTM mechanical sampler. SELLER shall divide each sample into three parts in accordance with ASTM standards and shall place the parts in suitable airtight containers each of which shall be sealed, documented and controlled for security purposes.
1. (a) SELLER shall analyze the first part ("Original Sample") on a
preliminary basis for Total Moisture, Ash, BTU/lb., and Sulfur
(Sulfur to be stated in pounds of sulfur dioxide per million Btu)
("Preliminary Analysis") in accordance with ASTM standards. If
the Preliminary Analysis shows that the Coal fails to meet any
one of the Rejection Coal Specifications as set forth in ARTICLE
X. QUALITY SPECIFICATIONS, BUYER may, at its option, exercise any
of its rights set forth in ARTICLE XI. COAL QUALITY
PENALTY/REFUSABLE COAL. SELLER shall fax a copy the Preliminary
Analysis to BUYER within twelve (12) hours of collecting the
Original Sample. BUYER shall designate an agent to receive such
results after normal business hours.
(b) In addition, SELLER shall analyze the Original Sample for Total
Moisture, Ash, BTU/lb., Ash Fusion Temperature (H=W) and Sulfur
(Sulfur to be stated in pounds of sulfur dioxide per million Btu)
in accordance with ASTM Methods ("Final Analysis"). SELLER shall
fax a copy of the Final Analysis to BUYER within 72 hours after
collecting the Original Sample.
(c) BUYER may, at its sole option and expense, require that the Final
Analysis include further testing in accordance with ASTM
standards for any or all of those characteristics in ARTICLE X.
QUALITY SPECIFICATIONS which were not described in ARTICLE IX.
SAMPLING AND ANALYSIS, Section C.1(b). If this analysis shows
that the Coal fails to meet any one of the suspension limits set
forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A, BUYER may,
at its option, exercise any of its rights set forth in ARTICLE
XII. NONCONFORMING COAL.
2. (a) The second part of the representative sample ("Duplicate Sample") shall be held by SELLER for at least thirty (30) days. BUYER, at its sole expense, may have the Duplicate Sample analyzed in accordance with ASTM standards for any or all of the characteristics in ARTICLE X. QUALITY SPECIFICATIONS ("BUYER's Analysis"). Except as provided in ARTICLE IX. SAMPLING AND ANALYSIS, Section 2(c) , a copy of BUYER's Analysis shall be made available to SELLER within ten (10) days of receipt of the results of BUYER's Analysis.
(b) If the results of BUYER'S Analysis are within the ASTM allowable reproducibility limits from the result of SELLER's Final Analysis, then SELLER's Final Analysis shall control for purposes of determining compliance with ARTICLE X. QUALITY SPECIFICATIONS, or any other term of this Agreement.
(c) If SELLER's Final Analysis and BUYER's Analysis results vary by more than the ASTM allowable reproducibility limits, then:
(i) A copy of BUYER's Analysis shall immediately be made available to SELLER; and
(ii) SELLER shall cause the Referee Sample (referred to in Sub-section (3) of this ARTICLE, below) to immediately be analyzed as provided in Sub-section (3), below, and the results shall immediately be made available to both SELLER and BUYER.
3. (a) The third part of the representative sample ("Referee Sample") shall be held by SELLER for at least forty-five (45) days for analysis by an independent laboratory as set forth below.
(b) If SELLER's Final Analysis and BUYER's Analysis results vary by more than the ASTM allowable reproducibility limits, then the Referee Sample shall be analyzed in accordance with ASTM standards by a mutually acceptable independent laboratory. The results of the Referee Sample analysis shall be furnished to both SELLER and BUYER and shall control for purposes of determining compliance with ARTICLE X. QUALITY SPECIFICATIONS and any other term of this Agreement. The cost of the Referee Sample analysis shall be paid equally by BUYER and SELLER.
D. SELLER shall, at its own cost, cause the mechanical sampler to be dynamically bias tested by an independent third party at least every 24 months during the Term of this Agreement. SELLER shall provide copies of the sampler test reports to BUYER. BUYER shall have the right to have a representative present during the sampler tests.
X. QUALITY SPECIFICATIONS
A. All Coal to be delivered under this Agreement shall substantially conform to the following Typical Coal Specifications:
as Received Sufco ----- Typical Suspension Rejection -------- ---------- --------- Size (ASTM #D4749) 2" x 0 Total Moisture % 9.8 12.5 13.0 Ash % 8.5 12.0 13.0 Heat Content (BTU/1b) 11,400 10,950 10,500 Ash Fusion (ST H=W) 2100(0)F Sulfur (Lbs. S02/MMBtu) 0.80 1.0 1.10 Grindability (HGI) 45 Iron Oxide % (Fe203) 5.5 Sodium Oxide % (Na20) 3.8 Fines %* 43 6 |
Skyline ------- Typical Suspension Rejection ------- ---------- --------- Size (ASTM #D4749) 2" x 0 Total Moisture % 8.5 12.0 13.0 Ash % 9.0 12.0 13.0 Heat Content (BTU/lb) 11,710 11,255 10,800 Ash Fusion (ST H=W) 2150(0)F Sulfur (Lbs. S02/NEvlBtu) 0.74 1.0 1.10 Grindability (HGI) 46 Iron Oxide % (Fe203) 6.0 Sodium Oxide % (NaZO) 1.2 Fines %* 50 Dugout ------ Typical Suspension Rejection ------- ---------- --------- Size (ASTM #D4749) 2" x 0 Total Moisture % 6.2 10.0 11.0 Ash % 10.5 12.0 13.5 Heat Content (BTU/lb) 11,960 11,380 10,800 Ash Fusion (ST H=W) 2400(0)F Sulfur (Lbs. S02/MMBtu 1.04 1.10 1.10 Grindability (HGI) 43 Iron Oxide % (Fe203) 3.5 Sodium Oxide % (NaiO) 0.8 Fines %* 45 |
* Fines in weight % measured through a 1/4 inch square screen. Wire size for sieve as listed in ASTM Specification E-11.
B. SELLER agrees to permit and/or make all necessary arrangements for access during normal business hours by BUYER, at BUYER's risk and expense to any properties, equipment or facilities related to SELLER'S performance under this Agreement.
C. The Coal shall be mixed thoroughly so that the quality thereof after being loaded into the rail cars shall be consistent within each car of the unit train and that the Coal shall be prepared substantially free of impurities.
D. BUYER, through its agents, representatives or employees, shall have the right to inspect the Coal at BUYER's risk and expense at any time prior to unloading at the Station and to inspect any properties, equipment or facilities during normal business hours related to SELLER's performance under this Agreement, including, but not limited to, SELLER's reserves, mining operations, hauling operations, storage operations or loading operations. BUYER's inspection pursuant to this ARTICLE X. QUALITY SPECIFICATIONS, Section D, does not relieve SELLER of its obligations to deliver Coal to BUYER in conformance with the quality specifications set forth in this ARTICLE X. QUALITY SPECIFICATIONS.
E. BUYER shall be entitled to randomly sample the Coal using ASTM standards during any such inspection ("Inspection Sample") and analyze the Inspection Sample using ASTM standard methods.
F. Because BUYER has not utilized Coal from Dugout at the Station, BUYER requires that a test burn be conducted. The test burn will require up to 50,000 tons of representative quality Coal from Dugout and would be conducted on a schedule mutually agreeable between BUYER and SELLER. If, as a result of the test bum, BUYER, in its sole reasonable judgment, determines that Coal from Dugout is not suitable for use at the Station, BUYER shall so notify SELLER in writing no later than thirty (30) days after completion of the test burn. SELLER agrees to terminate shipments from Dugout upon receipt of SELLER's notice. BUYER and SELLER agree to meet thereafter to discuss the reasons for the unsuitability and what, if anything, can be done to make Coal from Dugout suitable. BUYER and SELLER agree that SELLER intends to utilize Coal from Dugout to supply a portion of the annual volumes set forth in ARTICLE III. QUANTITY, Section A. If BUYER determines the Coal from Dugout is unsuitable, SELLER may elect to reduce the annual volumes set forth in ARTICLE III. QUANTITY, Section A, by 15% for the remainder of 2002-2003 and by 10% for 2004-2006. SELLER shall notify BUYER in writing of its election to reduce volumes no later than seven days after receipt of BUYER's notice of Dugout's unsuitability for use at the Station.
G. BUYER AGREES THAT SELLER MAKES NO EXPRESS WARRANTIES OTHER THAN THOSE SET FORTH IN THIS AGREEMENT. SELLER MAKES NO WARRANTY CONCERNING THE SUITABILITY OF COAL DELIVERED HEREUNDER FOR USE IN BUYER'S PLANT, OR OTHER ELECTRIC GENERATION STATIONS. ALL WARRANTIES OF MERCHANTABILITY OR OF FITNESS FOR A PARTICULAR PURPOSE OR ARISING FROM A COURSE OF DEALING OR USAGE OF TRADE ARE SPECIFICALLY EXCLUDED.
H. If, at any time after the date deliveries commence under this Agreement,
BUYER reasonably and in good faith determines a material inability to burn
the Coal purchased under this Agreement, BUYER may, at its option and upon
notice confirmed in writing and sent to SELLER by certified mail,
facsimile, or other electronic methods, suspend future shipments except
shipments already loaded into railcars from the Mine(s) which produce the
unacceptable Coal. SELLER may, within thirty (30) days of receipt of
BUYER's notice, provide BUYER with reasonable assurances that subsequent
monthly deliveries of Coal shall improve the combustion characteristics of
the Coal. If SELLER fails to provide such assurances within said thirty day
period, or if SELLER provides assurance but is unable to cure BUYER's
inability to burn the Coal, BUYER may terminate shipments from the affected
Mine(s) by giving written notice of such termination within five (5) days
from the end of such thirty day period. In the event BUYER exercises its
right under this Section, and terminates deliveries from the affected
Mine(s), then SELLER shall continue to supply Coal from the unaffected
Mine(s) and the shortfall created by the unburnable Coal would be
determined in accordance with the forecast schedule set forth in ARTICLE
IV. ORDERING, Section B. Additionally, both parties shall be relieved from
any further rights, duties, obligations or liabilities under this Agreement
for that portion of deliveries that would have been delivered from the
affected Mine(s), except for payment of any sums due and owing for
deliveries made under this Agreement prior to the termination of deliveries
from the affected Mine(s).
I. In the event that certain Coal quality parameters create combustion related problems at the Station, BUYER may, upon notice confirmed in writing and sent to SELLER by certified mail, facsimile, or other electronic method, suspend future shipments except shipments already loaded into railcars. SELLER shall, within thirty (30) days of receipt of BUYER's notice, provide BUYER with reasonable assurances that subsequent monthly deliveries of Coal shall improve the combustion characteristics of the Coal. If SELLER fails to provide such assurances within said thirty (30) day period, or if SELLER provides assurance but is unable to change the certain Coal quality parameters which created such combustion related problems, BUYER may terminate shipments from the affected Mine by giving written notice of such termination within five (5) days from the end of the thirty (30) day period. Additionally, SELLER shall continue to supply Coal from the unaffected Mines and the shortfall created by the non-conforming Coal would be determined in accordance with the forecast
schedule set forth in ARTICLE IV. ORDERING, Section B. A waiver of this
right for any one period by BUYER shall not constitute a waiver for
subsequent periods. If SELLER provides such assurances to BUYER, shipments
hereunder shall resume and any tonnage deficiencies resulting from
suspension may be made up subject to the mutual agreement of BUYER and
SELLER. BUYER shall not unreasonably withhold its acceptance of SELLER'S
assurances, or delay the resumption of shipments. The parties recognize
that BUYER, in accordance with ARTICLE XI. COAL QUALITY PENALTY/REFUSABLE
COAL, has the right to reject shipments that do not conform with the
rejection limits set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section
A., for Total Moisture, Ash, Sulfur (Sulfur to be stated in pounds of
sulfur dioxide per million Btu), and Btu/lb. This Section I. is intended to
apply to all constituents and properties of the Coal shipped hereunder
(except for Total Moisture, Ash, Btu/1b., and Sulfur, with Sulfur to be
stated in pounds of sulfur dioxide per million Btu) that individually or in
combination cause the Coal to be unburnable as defined herein.
XI. COAL QUALITY PENALTY/REFUSABLE COAL
A. If the quality of any trainload of Coal hereunder based upon the Preliminary Analysis authorized under ARTICLE IX. SAMPLING AND ANALYSIS exceeds the rejection limits set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A, by an amount that causes it to be unburnable in the sole discretion of the BUYER, BUYER may refuse to accept delivery of the trainload, all expenses to be paid by SELLER. BUYER may stop any train in route all expenses to be paid by the SELLER. BUYER shall-give SELLER such notice by telephone as soon as is reasonably possible and shall provide written notice no more than two business days after such selection is made by BUYER. BUYER must reject such Coal within twenty-four (24) hours of receipt of the Preliminary Analysis or such right to reject is waived.
When a train is rejected, SELLER shall have twenty-four (24) hours from the time BUYER notifies SELLER of the rejection to make arrangements to dispose of the Coal. BUYER may, at its discretion, lease the train to SELLER at prevailing lease rates in order to transport rejected Coal to a new destination. The train will be returned to BUYER at any of SELLER's Loading Facilities within 6 days of the rejection notice. SELLER agrees not to hold BUYER responsible for missing any loading dates or volumes due to SELLER's use of train for transporting rejected Coal.
B. If the quality of any trainload of Coal hereunder exceeds the reject limits set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A, and BUYER intends to utilize the Coal, that shipment shall be subject to a $1.00 per ton penalty that shall be credited to BUYER. This penalty shall be in addition to the price adjustments set forth in ARTICLE XV. HEAT CONTENT ADJUSTMENT, and ARTICLE XVI. S02 ADJUSTMENTS.
XII. NON-CONFORMING COAL
A. Should the weighted monthly average of all shipments from each Mine based upon the Final Analysis or Referee Sample Analysis of all monthly shipments, fail to meet any one or more of the suspension limits (except BTU/1b) set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A., or should SELLER deliver three (3) trains in a six (6) month period that fail to meet the rejection limits set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A., BUYER may upon notice confirmed in writing and sent to SELLER by certified mail, facsimile, or other electronic method, suspend future shipments with the exception of any shipments already loaded into railcars. SELLER shall, within thirty (30) days of receipt of BUYER's notice, provide BUYER with reasonable assurances that subsequent monthly deliveries of Coal shall meet or exceed the suspension limits (except BTU/1b) set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A. If SELLER fails to provide such assurances within said thirty (30) day period, BUYER may terminate shipments
from the affected Mine by giving written notice of such termination at the end of the thirty (30) day period. Additionally, SELLER shall continue to supply Coal from the unaffected Mines and the shortfall created by the non-conforming Coal would be determined in accordance with the forecast schedule set forth in ARTICLE IV. ORDERING, Section B. A waiver of this right for any one period by BUYER shall not constitute a waiver for subsequent periods. If SELLER provides such assurances to BUYER, shipments hereunder shall resume and any tonnage deficiencies resulting from suspension may be made up subject to the mutual agreement of BUYER and SELLER. BUYER shall not unreasonably withhold its acceptance of SELLER'S assurances, or delay the resumption of shipments.
B. All costs,.expenses or damages incurred by BUYER in the course of SELLER assuring BUYER of SELLER's ability to conform to the quality specifications, after giving notice to SELLER of SELLER's failure to meet any one or more of such suspension limits, shall be paid to BUYER by SELLER. Nothing herein shall limit the remedies available to BUYER under the Uniform Commercial Code as enacted in the State of Nevada (UCC).
XIII. DEFAULT EVENTSIREMEDIES
A. A default event shall mean any of the following:
1. SELLER fails to supply Coal subject to:
(a) The quality specifications set forth under the suspension and
rejection limits of ARTICLE X. QUALITY SPECIFICATIONS, Section
A., and
(b) The quantity specifications set forth under ARTICLE III. QUANTITY. Sections A. and B., unless otherwise excused under ARTICLE XVIII. FORCE MAJEURE.
2. SELLER fails to provide assurances as required in ARTICLE XII.
NON-CONFORMING COAL, Section A.
3. SELLER, having given adequate assurances, fails to commence delivery of Coal conforming to the Typical Coal Specifications set forth in ARTICLE X. QUALITY SPECIFICATIONS, Section A., within thirty (30) days after the date of SELLER providing assurances to BUYER as required in ARTICLE XII. NON-CONFORMING COAL, Section A.
4. SELLER delivers within three (3) months after the date of SELLER'S
resumption of shipments under ARTICLE XII. NON-CONFORMING COAL,
Section A, three shipments of Coal which fail to meet any one or more
of the reject limits set forth in ARTICLE X. QUALITY SPECIFICATIONS,
Section A.
5. Either party commits a material breach of its obligations under this Agreement and the breaching party fails to cure such material breach within thirty (30) days after receipt of written notice from the non-breaching party describing the breach.
6. BUYER or SELLER fails to pay any payment required by the Agreement when due and such failure is not remedied within fourteen (14) days after written notice thereof, provided however, that the payment is not subject to ARTICLE XVII. PAYMENT.
7. BUYER or SELLER files a petition or otherwise commences, authorizes, or acquiesces in the commencement of a proceeding or cause of action under any bankruptcy or similar
law for the protection of creditors; has such petition filed or a proceeding commenced against it, otherwise becomes bankrupt or insolvent (however evidenced); fails or is unable generally to pay its debts as they become due; or seeks or becomes subject to the appointment of an administrator, provisional liquidator, conservator, receiver, trustee, custodian or other similar official for all or substantially all of its assets.
B. In the event either party is in default, the other party may, in addition to and not in limitation of other rights provided for in this Agreement, do one or more of the following:
1. Cancel this Agreement.
2. Exercise all remedies available to either BUYER or SELLER under the entire UCC or any provision thereof.
XIV. COAL PRICE
A. The price per ton (2000 pounds) to be paid by BUYER to SELLER for the Coal delivered hereunder shall be fixed for each calendar year for the duration of the agreement at the prices indicated below F.O.B. rail cars at SELLER'S Loading Facility for each Mine. This price includes all taxes, costs of compliance with all laws and regulations, royalties and other fees applicable to the production and sale of Coal under this Agreement, except that State of Nevada Use Tax shall be to BUYER's account.
Sufco Skyline Dugout ------ ------- ------ Effective January 1, 2002 $18.50 $19.00 $19.30 Effective January 1, 2003 $19.05 $19.57 $19.88 Effective January 1, 2004 $19.63 $20.15 $20.48 Effective January 1, 2005 $20.22 $20.76 $21.09 Effective January 1, 2006 $20.82 $21.38 $21.72 |
B. SELLER represents that the cost of compliance with all governmental laws and regulations in effect as of November 15, 2001 is included in the initial Coal prices. Subsequent to such date new laws or regulations, changes in the interpretation or enforcement practices concerning existing laws as well as changes in presently existing federal, state, and local laws, rules and regulations that impose additional costs, or reduce such costs being imposed to mine, process, transport, or sell Coal and which were not being incurred as of November 15, 2001, (collectively "Change in Governmental Imposition") shall be passed through to BUYER or SELLER, as the case may be, pursuant to Sections C through H below. SELLER and BUYER agree that cost changes due to changes in percentage depletion allowance shall not qualify as a Change in Governmental Imposition.
C. There are two categories of Change in Governmental Imposition:
1. Any Change in Governmental Imposition that is directly assessed against SELLER as a dollar per ton, a dollar per million Btu or as a percent of sales price shall be passed in its entirety to BUYER as an adjustment to the base prices, subject to the limitations in Section E below. Examples include, but are not limited to, regulations impacting Btu, carbon, mercury, sodium dioxide, Federal Black Lung, Federal Reclamation Fee, Severance Tax, and Federal Coal Royalty.
2. Any other Change in Governmental Imposition not described by ARTICLE
XIV. COAL PRICE, Section C.(1) shall be calculated as follows:
(a) The total Change in Governmental Imposition shall be calculated for each Mine as each such change is incurred.
(b) The total amount calculated pursuant to Subsection (a) above shall be divided by the total number of tons produced by the respective Mine for the applicable time period involved to yield the dollar per ton impact.
(c) Every Change in Governmental Imposition pursuant to this Subsection (2) will first be rounded to the nearest thousandth of a cent and then reduced by $0.10 per ton. If the Change in Governmental Imposition is less than $0.10 per ton then there shall be no change to the Coal prices.
D. The following procedure applies when SELLER claims that there has been a Change in Governmental Imposition that is eligible to impact Coal prices, but the cumulative Coal price increase for the life of this Agreement in the Governmental Imposition category is less than or equal to $2.00 per ton each in either Subsection C.(1) or Subsection C.(2).
1. SELLER shall notify BUYER within sixty days of the effective date of any Change in Governmental Imposition. Such notification shall include SELLER's non-binding indication of whether the Change in Governmental Imposition is significant.
2. As soon as possible after such notification, SELLER shall provide BUYER with written cost per ton calculations and satisfactory evidence of the pertinent Change in Governmental Imposition. Such calculations, together with supporting documentation and workpapers will be sufficient to allow a knowledgeable person to determine the reasonableness and accuracy of SELLER's calculations.
3. BUYER shall have ninety (90) days to review the materials provided by SELLER pursuant to Subsection (2) above and provide SELLER with notice of acceptance or dispute of such Change in Governmental Imposition and resulting Coal price adjustments.
4. If BUYER accepts SELLER's calculation of the Change in Governmental Imposition, the Coal prices will be adjusted retroactively for a period beginning (i) on the effective date of such Change in Governmental Imposition if SELLER's notice of the same was within the sixty day deadline referenced in Subsection (1) above; or (ii) sixty days prior to the date of SELLER's initial notification if SELLER failed to comply with such deadline. BUYER or SELLER as the case may be shall make payment of a Change in Governmental Imposition that is retroactive within 20 days of SELLER's invoice or credit memorandum, and the per ton impact shall be reflected in the revised Coal prices for subsequent deliveries.
5. If BUYER or SELLER disputes such calculations, then BUYER and SELLER
shall have up to sixty days from the notice of dispute to resolve the
dispute. If the dispute cannot be resolved within the sixty day
period, then the dispute shall be arbitrated as set forth in ARTICLE
XXIII. DISPUTE RESOLUTION, as modified by this Subsection. The sole
questions for the arbitrator to decide will be the correct amount of
Change in Governmental Imposition and the corresponding change in Coal
prices. If BUYER or SELLER elect to arbitrate a dispute arising from a
Change in Governmental Impositions, then BUYER and SELLER agree to be
bound by the arbitrators' ruling and apply it retroactively to the
effective date of such Change in Governmental Imposition pursuant to
Paragraph 4 of this Section (D) and this Agreement shall not be
terminated as a result of the arbitrators' ruling.
E. When the Changes in Governmental Impositions described by ARTICLE XIV. COAL PRICE, Section C.(I) reach a cumulative amount exceeding $2.00 per ton, then these additional procedures will apply following the ninety day review period referenced in Section (D)(3).
1. If BUYER accepts the validity of the charge, BUYER and SELLER agree to meet to discuss which, if either party, agrees to absorb the amount of the ARTICLE XIV. Section C.(1) cost that exceeds $2.00 per ton. Such meeting shall take place within 5 days of BUYER's notice of acceptance as provided for in this ARTICLE XIV. COAL PRICE, Section D.(3). If either party agrees to absorb such amount, then this Agreement shall remain in full force and effect. If neither party agrees to absorb such amount, then this Agreement shall terminate 90 days from the meeting date. During the final ninety day period, the Coal prices shall be adjusted to reflect fifty percent (50%) of the subject ARTICLE XIV. COAL PRICE, Section C.(1) charge and shall not be subject to any other adjustments for a Change in Governmental Imposition for as long as this Agreement remains in effect.
2. If BUYER disputes the validity of the charge, such dispute shall be resolved pursuant to ARTICLE XIV. COAL PRICE, Section D(5).
F. When the Change in Governmental Impositions described in ARTICLE XIV. COAL PRICE, SECTION C.(2) reach a cumulative amount exceeding $2.00 per ton, then these additional procedures will apply following the ninety day review period referenced in Section (D)(3).
1. If the BUYER accepts the validity of the charge, BUYER and SELLER agree to meet to discuss which, if either party, agrees to absorb the amount of this ARTICLE XIV. COAL PRICE, Section C.(2) cost that exceeds $2.00 per ton. Such meeting shall take place within 5 days of BUYER's notice of acceptance as provided for in this ARTICLE XIV. COAL PRICE, Section D.(3). If either party agrees to absorb such amount, then this Agreement shall remain in full force and effect. If neither party agrees to absorb such amount, then this Agreement shall terminate ninety (90) ~ days from the meeting date. During the final ninety day period, the Coal prices shall be adjusted to reflect fifty percent (50%) of the subject ARTICLE XIV. COAL PRICE(C)(2) charge and shall not be subject to any other adjustments for a Change in Governmental Imposition for as long as this Agreement remains in effect.
2. If BUYER disputes the validity of the charge, such dispute shall be resolved pursuant to this ARTICLE XIV. COAL PRICE, Section D.(5).
G. In the event that BUYER contends that SELLER has failed to claim and calculate an available Change in Governmental Imposition, the parties agree as follows:
1. BUYER will give SELLER notice within sixty (60) days of the effective date that it believes that a Change in Governmental Imposition has provided a cost saving opportunity that should be passed through retroactively as of the effective date of such Change in Governmental Imposition to BUYER by an adjustment to the Coal prices. If BUYER fails to notify SELLER of a Change in Governmental Imposition within the required sixty day period, then the effective date of the Change in Governmental Imposition would then become sixty days prior to the date of BUYER's initial notification, unless the discovery of a Change in Governmental Imposition occurs during annual audit by BUYER as set forth in ARTICLE XIX. AUDIT/INSPECTION when the effective date of any change in Coal prices shall be the effective date of the Change in Governmental Imposition.
2. SELLER will then calculate the available cost changes related to such Change in Governmental Imposition as soon as possible and calculate the related adjustment to the Coal prices. SELLER shall provide BUYER with its calculations and related documentation sufficient to allow a knowledgeable person to determine the reasonableness and accuracy of the possible cost change on a dollar per ton basis.
3. BUYER shall have ninety (90) days after receiving such documentation, to give SELLER notice of acceptance or dispute of such calculations. If BUYER disputes such calculations, then such dispute will be resolved pursuant to this ARTICLE XIV. COAL PRICE, Section D.(5).
H. BUYER and SELLER mutually agree that time is of the essence as it relates to the obligations of the parties under this ARTICLE XIV. COAL PRICE.
XV. HEAT CONTENT ADJUSTMENT
In the event the weighted average heat content of all Coal shipped in any
calendar month is less than the guaranteed Btu/lb as specified in this ARTICLE
XV. HEAT CONTENT ADJUSTMENT, then a Heat Content Penalty in an amount determined
by the following formula, shall apply. Heat content adjustments shall be
calculated separately for each Mine from which Coal was shipped hereunder
In the event the weighted average heat content of all Coal shipped in any calendar month is greater than the guaranteed Btu/lb as specified in this ARTICLE XV. HEAT CONTENT ADJUSTMENT, then a Heat Content Premium in an amount determined by the following formula shall apply:
Btu l Where: "Price Per Ton" = The price set forth in ARTICLE XIV. COAL PRICE for the Mine in dollars per ton; "Btu l" = The guaranteed heat content in Btu/lb (as received basis) as follows: Sufco - 11,400, Skyline - 11,710, Dugout -- 11,960; "Btu2" = The weighted average as received heat content (as determined in accordance with ARTICLE IX. SAMPLING AND ANALYSIS) for all Coal shipped for the month from the Mine; "Tons Shipped" = The total number of tons of Coal received for the contract month. |
There shall be no Heat Content Premium or Penalty for the month if the weighted average Btu content of all Coal shipped from the Mine in that month is greater than or equal to [Btu1 - 50 Btu/lb.], but less than or equal to [Btu1 + 50 Btu/1b.].
BUYER shall send SELLER a written calculation of the Heat Content Penalty or Premium by Mine within thirty (30) days after the end of each month. Payment or credit shall be made within fifteen (15) days of receipt of the written calculation.
XVI. S02 ADJUSTMENTS
If the weighted average pounds of S02 per million BTU (lbs S02/MMBTU) on an as received basis of all shipments accepted by BUYER in a calendar month from a Mine differs from the base lbs S02/MMBTU for that Mine, then a S02 adjustment in an amount determined by the following formula shall apply
1,000,000 Where: "Base S02" = The specification in lbs S02/MMBTU (as received basis) for the Mine as follows: Sufco - 0.80, Skyline - 0.74, Dugout -1.04; "Actual S02" = The weighted average lbs S02/MhlBTU (as received basis) for that Mine (as determined in accordance with ARTICLE IX. SAMPLING AND ANALYSIS) for all Coal shipped for the month from the Mine; "Btu2" = The weighted average as received heat content (as determined in accordance with ARTICLE IX. SAMPLING AND ANALYSIS) for all Coal shipped for the month from the Mine; "Value S02" = The average price of S02 allowances for the month in dollars per ton of S02 determined by summing the "Air Daily Market Price Indices" during the month divided by the number of indices published in "Air Daily" during the month. |
Lbs S02/MMBTU shall be calculated as follows:
BUYER shall send SELLER a written calculation of the S02 adjustment by Mine within thirty (30) days after the end of each month. Payment shall be mailed by SELLER within twenty (20) days of receipt of the written calculation. If an additional payment is due SELLER, BUYER shall make payment within twenty (20) days of SELLER's review of BUYER's written calculations.
XVII. PAYMENT
By the tenth day of the month, SELLER shall send BUYER an invoice for all Coal received in the previous month. The invoice shall include train numbers, tonnage per train, price per ton, Mine, and Loading Facility. Invoices should be sent to:
Fuels Accountant, General Accounting Department
Sierra Pacific Power Company
P.O. Box 98910
Las Vegas, NV 89151
Payment for the Coal shall be made by BUYER within twenty (20) days of receipt of the invoice.
XVIII. FORCE MAJEURE
A. Definition of Force Majeure. The term "force majeure" as used in this Agreement shall mean any causes beyond the control and not caused by the fault or negligence of the affected party that the affected party is unable to overcome or mitigate, such as Acts of God, acts of the public enemy, insurrections, riots, strikes, or labor disputes, power, labor or material shortages, fires, explosions, floods, breakdowns of or damage to plants, mines, equipment or facilities, interruptions to or contingencies of transportation, embargoes, court or commission orders, inability to obtain necessary permits, licenses, and governmental approvals after applying for same with reasonable diligence, unforeseen mining conditions, unforeseen geologic faults, or other causes of a similar nature that wholly or partially prevent the mining, loading, and/or delivery of Coal by SELLER from the Mines, or the receiving, unloading or consuming of Coal by BUYER in the generation of electricity at any of units at the Station or other generating stations then receiving Coal under this Agreement, or the transmission of electricity; provided, however, that the excuse of force majeure shall not be available to SELLER if the delay or failure in its performance arises from a defect in the rights entitling SELLER to mine and remove Coal at the Mines. Failure to prevent or settle any strike or labor trouble shall be considered beyond the control of the party claiming such excuse for nonperformance. The party claiming force majeure shall give prompt notice by telephone as soon as possible after the occurrence of the event of force majeure and shall promptly give the other party written notice describing the nature of the occurrence and its probable duration.
B. Suspension of Obligations. Neither party shall be under any obligation nor subject to any liability (except payment of invoices for Coal already delivered) for failure to perform any of its obligations under this Agreement as the result of a force majeure event, and the obligations of the party claiming force majeure shall be suspended to the extent made necessary by such force majeure and during its continuance. Should the situation of a total force majeure at one or more Mine(s) exceed twelve months, the party not claiming force majeure shall have the option to terminate the Mine source(s) under this Agreement upon sixty days written notice.
C. Full or Partial Force Majeure Tonnage Allocation. During the period that an event of force majeure causes a complete reduction in the total quantity of Coal SELLER can deliver from one or more Mines, deliveries shall cease from the affected Mine(s) and shall continue from the unaffected Mine(s) in accordance with the schedule set forth in ARTICLE IV. ORDERING, Section B., from the unaffected Mine(s). During the period that an event of force majeure causes a partial reduction in the total quantity of Coal SELLER can deliver from the affected Mine(s), SELLER first shall continue to deliver Coal from the unaffected Mine(s) in accordance with the schedule set forth in ARTICLE IV. ORDERING, Section B., and then curtail any spot deliveries from the affected Mine(s) that SELLER is not committed to sell. If necessary, SELLER shall apportion the Coal that it is able to deliver from the affected Mine(s) pro rata among the BUYER and all other customers supplied Coal from the affected Mine(s) under existing agreements. During the period that an event of force majeure causes a partial reduction in the total quantity of Coal that BUYER can consume at the Station , BUYER shall apportion its Coal requirements pro rata among SELLER and any other parties with whom BUYER has contracted to supply Coal to the Station. The party not invoking force majeure shall have the right to require the make-up of deliveries suspended during the force majeure, subject to a mutually acceptable scheduling of such make-up deliveries. The price for make-up of such force majeure tonnage shall be as follows:
. If the force majeure was declared by the SELLER, then the price shall be the price in effect at the time the force majeure was declared by the SELLER.
. If the force majeure was declared by the BUYER, then the price shall be the price in effect at the time the Coal deliveries are made up.
XIX. AUDIT/ INSPECTION
BUYER, and its authorized agents which have signed appropriate confidentiality agreements with SELLER, at BUYER's risk and expense, shall have the right to make inspections of the properties and related operations of SELLER insofar as may be reasonably required to verify SELLER'S representations and claims relating to the performance of its obligations hereunder. In addition, BUYER or SELLER, upon request, shall furnish the other party and its agents with all information which may be reasonably required to verify quality specifications and to calculate any prices hereunder including verification of any and all passthrough costs. BUYER, upon request to SELLER, at BUYER's risk and expense, shall have the right to verify by audit all information regarding quantity requirements, quality specifications and prices charged hereunder. SELLER shall maintain all such records for a period of twenty-four (24) months from the creation of the records.
XX. NOTICES
Unless otherwise provided in this Agreement, all notices under this Agreement shall be in writing and shall be sufficient in all respects if delivered in person or sent by overnight mail service to:
BUYER:
Fuels Department
Sierra Pacific Power Company
P.O. Box 98910
Las Vegas, NV 89151
SELLER:
J. Thomas Dilley
Vice President Administration
Arch Coal Sales Company, Inc.
CityPlace One, Suite 350
St. Louis, MO 63141
XXI. FREEZE CONDITIONING & DUST SUPPRESSION
SELLER shall allow BUYER or its representatives to use BUYER's own equipment or SELLER's equipment to apply freeze conditioning or dust suppressant agents to the Coal supplied herein. The cost of the chemicals used in any such treatment shall be borne by BUYER. At BUYER's option, SELLER shall apply a freeze conditioning or dust suppression agent(s) at a rate (pints per ton) to be specified by the BUYER as the Coal purchased and sold hereunder is loaded into railcars. Such agents shall be approved by BUYER. As full compensation for applying the agents, BUYER shall pay the direct cost of purchasing the agent applied to the Coal purchased and sold hereunder. SELLER shall submit invoices for the agents monthly, which shall be accompanied by documentation satisfactory to BUYER. For billing purposes, SELLER agrees to deduct the weight of any freeze and/or dust conditioning agent from the total weight of each Coal railcar if these chemicals are added prior to weighing the loaded railcar. Specific procedures for determining and administering these weight adjustments will be coordinated among BUYER's Joint Facility Accounting Department, the freeze and/or dust conditioning agent supplier, and SELLER. BUYER will pay invoices within twenty (20) days of receipt of invoices.
XXII. CAPTIONS AND SEVERABILITY
All ARTICLE captions are inserted for convenience and shall not affect the interpretation of this Agreement. Any provision of the Agreement which is prohibited or unenforceable shall be ineffective to the extent of such prohibition or unenforceability without invalidating the remaining provisions hereof.
XXIII. DISPUTE RESOLUTION
A. The parties will attempt in good faith to resolve any controversy or disagreement arising out of or relating to this Agreement, including the breach or termination thereof, (hereinafter collectively referred to as "Dispute") promptly by negotiation between senior executives of the parties who have authority to settle the controversy.
B. The disputing party shall give the other party written notice of the
Dispute. Within ten (10) days after receipt of said notice, the receiving
party shall submit to the other a written response. The notice and response
shall include (a) a statement of the respective position of each party and
a summary of the evidence and arguments supporting its position, and (b)
the name and title of the executive who will represent the party. The
executives shall meet at a mutually acceptable time and place within twenty
(20) days of the disputing party's notice and thereafter as often as they
reasonably deem necessary to exchange relevant information and to attempt
to resolve the Dispute.
C. If the parties are unable to resolve the Dispute through negotiation, then the Dispute shall be subject to arbitration as hereafter set forth. This Agreement, so to arbitrate, and any other agreement or consent to arbitrate entered into in accordance herewith, will be specifically enforceable under the prevailing law of any court located in Nevada having jurisdiction.
D. Notice of the demand for arbitration must be filed in writing with the other party to the Agreement. The demand must be made within a reasonable time, not to exceed sixty (60) days, after the Dispute has arisen.
E. Unless the parties otherwise agree in writing, all arbitrations shall be heard by a panel of three (3) arbitrators experienced in the coal or electric generating utilities industries. Each party shall have the right to appoint, at its sole discretion, one arbitrator. The two party-appointed arbitrators shall select a third arbitrator, who shall act as the Chairperson of the Panel. In the event the party appointed arbitrators are unable or unwilling to agree upon a third arbitrator, the Chief Judge of the Federal District Court of the State of Nevada shall select the third arbitrator.
F. Once the full Panel has been appointed, the parties shall be entitled to review and copy records within the control or custody of the other party which would be discoverable under the Federal Rules of Civil Procedure. Depositions shall only be allowed at the discretion of two members of the Panel.
G. The award rendered by a majority of the arbitrators will be final and binding upon the parties. Judgment may be entered upon the arbitration award in any court having jurisdiction thereof, and will not be subject to modification or appeal except to the extent permitted by Sections 10 and 1 I of the Federal Arbitration Act (9 U.S.C. ss.ss.10,11).
H. Pending resolution of any dispute or disagreement between the parties under this Agreement, both parties shall diligently proceed with their performance under this Agreement in accordance with BUYER's interpretation thereof, and neither BUYER's or SELLER's legal rights shall be prejudiced because they continue to perform. BUYER shall continue to pay the price for Coal calculated pursuant to ARTICLE XIV. COAL PRICE, as that provision and the calculation of the price, or any damages, costs, expenses, etc., are determined by BUYER.
I. Interest on any amounts not paid in full, withheld by BUYER or to be paid by either party for any reason shall be calculated by reference to the prime interest rate as listed in the Wall Street Journal, Money Rate section, as of the date such amount was due or incurred.
XXIV. INDEPENDENT CONTRACTOR
This is an agreement for the purchase and sale of Coal in which the parties recognize and agree that SELLER is not an agent or employee of BUYER but is an independent contractor.
XXV. 1NDEMVIFICATION
SELLER indemnifies and holds BUYER harmless from and against all claims and liabilities (including, without limitation, attorneys' fees and expenses), from whatever source, related to or deriving from SELLER's mining, processing, trucking, and loading activities, or its sale and delivery of Coal to BUYER.
BUYER indemnifies and holds SELLER harmless from and against all claims and liabilities (including, without limitation, attorney's fees and expenses), from whatever source, related to or deriving from BUYER's rail transportation, except as otherwise provided for in this Agreement, and utilization of the Coal sold hereunder.
XXVI. WAIVER/FAILURE TO INSIST ON STRICT COMPLIANCE
The failure of either party at any time or from time to time to insist upon strict compliance with any provision of this Agreement, or to exercise any right hereunder shall not be construed as a waiver of any provision or right.
XXVII. ENTIRE AGREEMENT
This Agreement contains the entire agreement between the parties and there are no representations, understandings or agreements, oral or written which are not included herein. This Agreement cannot be modified except in writing by duly authorized representatives of the parties.
XXVIII. ASSIGNMENTS
The Agreement may not be assigned wholly or in part by either party without the written consent of the other party, which consent shall not be unreasonably withheld; provided however, that either party, without the written consent of the other, may assign this Agreement to a successor in interest of any party by way of a merger or consolidation, or to a company controlled by, or under common control with SELLER or, in the case of BUYER, the sale of all or a substantial portion of its coal-fired generation assets. Any party making an assignment under this ARTICLE XXVIII. ASSIGNMENTS, shall give notice thereof to the other party within a reasonable time prior to the effective date of the assignment. The assignee shall become liable for all terms and conditions as if such party was signatory to the Agreement. Notwithstanding the foregoing, any party may, without the need for consent from the other party (and without relieving itself from liability hereunder), transfer, sell, pledge, encumber or assign this Agreement or the accounts, revenues or proceeds hereof or thereof in connection with any bank financing or security arrangements, provided, however, that no such assignment shall in any way relieve the assignor from liability for full performance under this Agreement. Any such assignee shall assume and agree to be bound by the terms and conditions of this Agreement.
XXIX. NON-DISCLOSURE
The Agreement, the terms and conditions (including but not limited to pricing) set forth in this Agreement and the information exchanged during the negotiation of this Agreement are considered by both BUYER and SELLER to be confidential and proprietary. Neither BUYER nor SELLER shall disclose any of the terms and conditions hereof or any such information to any third party without the prior written consent of the other, except when such disclosure is required (a) by statute; (b) in connection with a judicial or administrative proceeding; or (c) by order of a government agency having jurisdiction over BUYER or SELLER or the subject matter of this Agreement, in which the party intending to make such disclosure shall notify the other in writing in advance and shall cooperate to the extent practicable to minimize the disclosure of any such information. BUYER may disclose the terms and conditions of this Agreement (including pricing) to IPC. For the purposes of this ARTICLE XXIX. NON-DISCLOSURE, the term "third party" shall not include a parent, subsidiary or affiliate of either party hereto.
XXX. CHOICE OF LAW - JURISDICTION
This Agreement and any matter arising out of or related thereto shall be governed, construed, enforced and performed in accordance with the laws of the State of Nevada. Venue for any cause of action arising under this Agreement shall be brought in Clark County, Nevada.
XXXI. LIMITATION OF LIABILITY
In no event shall either party have any liability to the other party for any special, incidental or consequential damages, including lost profits, for any reason arising out of, or in connection with this Agreement.
IN WITNESS WHEREOF, the undersigned hereby causes this Agreement to be duly executed this 28th day of February, 2002.
BUYER: SIERRA PACIFIC POWER COMPANY
SELLER: ARCH COAL SALES COMPANY
Exhibit 12 (A)
SIERRA PACIFIC RESOURCES
RATIOS OF EARNINGS TO FIXED CHARGES
Year Ended December 31, ------------------------------------------------------------ Amounts in 000's 2001 2000 1999 1998 1997 EARNINGS AS DEFINED: Income (Loss) From Continuing Operations After Interest Charges $ 52,336 $(27,001) $ 67,152 $ 94,686 $ 90,472 Income Taxes 15,531 (28,936) 26,570 45,471 45,225 ------------------------------------------------------------ Income (Loss) From Continuing Operations before Income Taxes 67,867 (55,937) 93,722 140,157 135,697 Fixed Charges 244,022 210,368 133,515 81,238 63,139 Capitalized Interest (2,801) (10,634) (8,000) (6,080) (2,579) Preference Security Dividend Requirements (24,462) (24,297) (20,127) (11,013) (7,256) ------------------------------------------------------------ Total $284,626 $119,500 $199,110 $204,302 $189,001 ============================================================ FIXED CHARGES AS DEFINED: Interest Expensed and Capitalized $219,560 $186,071 $113,388 $ 70,225 $ 55,883 Preference Security Dividend Requirements 24,462 24,297 20,127 11,013 7,256 ------------------------------------------------------------ Total $244,022 $210,368 $133,515 $ 81,238 $ 63,139 ============================================================ RATIO OF EARNINGS TO FIXED CHARGES 1.17 0.57 1.49 2.51 2.99 DEFICIENCY $ - $ 90,868 $ - $ - $ - |
For the purpose of calculating the ratios of earnings to fixed charges, "Fixed Charges" represent the aggregate of interest charges on short-term and long-term debt and distributions on preferred securities of consolidated subsidiaries, allowance for borrowed funds used during construction (AFUDC) and capitalized interest, the portion of rental expense deemed to be attributable to interest, and the pre-tax preferred stock dividend requirements of consolidated subsidiaries. "Earnings" represent the aggregate of income (or loss) from continuing operations before obligated mandatorily redeemable preferred securities, income taxes, and fixed charges, less AFUDC and capitalized interest, and pre-tax preferred stock dividend requirements of consolidated subsidiaries.
Exhibit 12 (B)
NEVADA POWER COMPANY
RATIOS OF EARNINGS TO FIXED CHARGES
Year Ended December 31, ------------------------------------------------------------ Amounts in 000's 2001 2000 1999 1998 1997 EARNINGS AS DEFINED: Income (Loss) From Continuing Operations After Interest Charges (1) $ 78,577 $ 7,244 $ 53,959 $ 94,686 $ 90,472 Income Taxes 32,783 (9,386) 21,213 45,471 45,225 ------------------------------------------------------------ Income (Loss) From Continuing Operations before Income Taxes 111,360 (2,142) 75,172 140,157 135,697 Fixed Charges 114,015 103,933 97,734 81,238 63,139 Capitalized Interest (2,141) (7,855) (8,356) (6,080) (2,579) Preference Security Dividend Requirements of Consolidated Subsidiaries (15,172) (15,172) (15,172) (11,013) (7,256) ------------------------------------------------------------ Total $208,062 $ 78,764 $149,378 $204,302 $189,001 ============================================================ FIXED CHARGES AS DEFINED: Interest Expensed and Capitalized $ 98,843 $ 88,761 $ 82,562 $ 70,225 $ 55,883 Preference Security Dividend Requirements of Consolidated Subsidiaries 15,172 15,172 15,172 11,013 7,256 ------------------------------------------------------------ Total $114,015 $103,933 $ 97,734 $ 81,238 $ 63,139 ============================================================ RATIO OF EARNINGS TO FIXED CHARGES 1.82 0.76 1.53 2.51 2.99 DEFICIENCY $ - $ 25,169 $ - $ - $ - |
(1) Does not include equity in (losses) earnings of Sierra Pacific Resources in 2001, 2000 and 1999
For the purpose of calculating the ratios of earnings to fixed charges, "Fixed charges" represent the aggregate of interest charges on short-term and long-term debt and distributions on preferred securities of consolidated subsidiaries, allowance for borrowed funds used during construction (AFUDC) and capitalized interest, and the portion of rental expense deemed to be attributable to interest. "Earnings" represent the aggregate of income (or loss) from operations before obligated mandatorily redeemable preferred securities, income taxes, and fixed charges, less AFUDC and capitalized interest.
Exhibit 12 (C)
SIERRA PACIFIC POWER COMPANY
RATIOS OF EARNINGS TO FIXED CHARGES
Year Ended December 31, ------------------------------------------------------------------------ Amounts in 000's 2001 2000 1999 1998 1997 EARNINGS AS DEFINED: Income (Loss) From Continuing Operations After Interest Charges $ 26,341 $ (335) $ 68,364 $ 88,646 $ 86,132 Income Taxes 10,260 (1,362) 33,489 39,561 36,454 ----------------------------------------------------------------------- Income (Loss) From Continuing Operations before Income Taxes 36,601 (1,697) 101,853 128,207 122,586 Fixed Charges 68,965 56,753 48,503 47,526 45,611 Capitalized Interest (660) (2,779) (141) (6,000) (4,718) Preference Security Dividend Requirements of Consolidated Subsidiaries (3,598) (3,742) (3,749) (4,171) (4,171) ----------------------------------------------------------------------- Total $ 101,308 $ 48,535 $146,466 $ 165,562 $ 159,308 ======================================================================= FIXED CHARGES AS DEFINED: Interest Expensed and Capitalized $ 65,367 $ 53,011 $ 44,754 $ 43,355 $ 41,440 Preference Security Dividend Requirements of Consolidated Subsidiaries 3,598 3,742 3,749 4,171 4,171 ----------------------------------------------------------------------- Total $ 68,965 $ 56,753 $ 48,503 $ 47,526 $ 45,611 ======================================================================= RATIO OF EARNINGS TO FIXED CHARGES 1.47 0.86 3.02 3.48 3.49 DEFICIENCY $ - $ 8,218 $ - $ - $ - |
For the purpose of calculating the ratios of earnings to fixed charges, "Fixed charges" represent the aggregate of interest charges on short-term and long-term debt and distributions on preferred securities of consolidated subsidiaries, allowance for borrowed funds used during construction (AFUDC) and capitalized interest, and the portion of rental expense deemed to be attributable to interest. "Earnings" represent the aggregate of income (or loss) from continuing operations before obligated mandatorily redeemable preferred securities, income taxes, and fixed charges, less AFUDC and capitalized interest.
INDEPENDENT AUDITORS' CONSENT
We consent to the incorporation by reference in Registration Statement No. 33-92651 of Sierra Pacific Resources on Form S-8, Registration Statement No. 333-77523 of Sierra Pacific Resources on Form S-8, Registration Statement No. 333-80149 of Sierra Pacific Resources on Form S-3, Registration Statement No. 333-72160 of Sierra Pacific Resources on Form S-3, and Registration Statement No. 333-64438 of Sierra Pacific Resources on Form S-3 of our reports dated February 22, 2002, appearing in this Annual Report on Form 10-K of Sierra Pacific Resources for the year ended December 31, 2001.
Deloitte & Touche LLP
Reno, Nevada
March 18, 2002