LACLEDE GROUP LOGO


SECURITIES AND EXCHANGE COMMISSION
Washington, D. C.


FORM 10-K

ANNUAL REPORT

For the Fiscal Year Ended September 30, 2010



LACLEDE GAS LOGO




 
 
 



SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-K

[ X ]
ANNUAL REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934 For the Fiscal Year Ended September 30, 2010
OR
[     ]
TRANSITION REPORT PURSUANT TO SECTION 13 or 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934 For the Transition Period from ­__________ to __________
 
 

 
 
Commission File Number
 
 
Registrant
 
 
State of Incorporation
I.R.S.
Employer Identification
Number
1-16681
The Laclede Group, Inc.
Missouri
74-2976504
1-1822
Laclede Gas Company
Missouri
43-0368139

720 Olive Street
St. Louis, MO 63101
314-342-0500

Securities registered pursuant to Section 12(b) of the Act

 
Name of Registrant
 
Title of Each Class
Name of Each Exchange On Which Registered
The Laclede Group, Inc.
Common Stock $1.00 par value
New York Stock Exchange
The Laclede Group, Inc.
Preferred Share Purchase Rights
New York Stock Exchange
Laclede Gas Company
None
 

Securities registered pursuant to Section 12(g) of the Act: None.

Indicate by check mark if the registrant:

is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

The Laclede Group, Inc.:
Yes
[ X ]
No
[     ]
         
Laclede Gas Company:
Yes
[     ]
No
[ X ]

is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

The Laclede Group, Inc.:
Yes
[     ]
No
[ X ]
         
Laclede Gas Company:
Yes
[     ]
No
[ X ]

(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 report) and (2) has been subject to such filing requirements for the past 90 days.

The Laclede Group, Inc.:
Yes
[ X ]
No
[     ]
         
Laclede Gas Company:
Yes
[ X ]
No
[     ]


 
2
 

has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

The Laclede Group, Inc.:
Yes
[ X ]
No
[     ]
         
Laclede Gas Company:
Yes
[     ]
No
[     ]

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. (  )

Indicate by check mark whether the registrant:

is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act

The Laclede Group, Inc.:
       
           
 
Large accelerated filer
[ X ]
 
Accelerated filer
[     ]
 
Non-accelerated filer
[     ]
 
Smaller reporting company
[     ]
           
Laclede Gas Company:
       
           
 
Large accelerated filer
[     ]
 
Accelerated filer
[     ]
 
Non-accelerated filer
[ X ]
 
Smaller reporting company
[     ]

is a shell company (as defined in Rule 12b-2 of the Exchange Act).

The Laclede Group, Inc.:
Yes
[     ]
No
[ X ]
         
Laclede Gas Company:
Yes
[     ]
No
[ X ]

The aggregate market value of the voting stock held by non-affiliates of The Laclede Group, Inc.
amounted to $699,639,251 as of March 31, 2010.

Number of shares outstanding of each of the issuer’s classes of common stock as of the latest practicable date:

   
Shares Outstanding At
Registrant
Description of Common Stock
November 18, 2010
The Laclede Group, Inc.:
Common Stock ($1.00 Par Value)
22,296,998
Laclede Gas Company:
Common Stock ($1.00 Par Value)
11,674*

*  100% owned by The Laclede Group, Inc.

Document Incorporated by Reference:
    Portions of Proxy Statement dated December 17, 2010 Part III
Index to Exhibits is found on page 100.





 



 





 
3
 


This combined Form 10-K is separately filed by The Laclede Group, Inc. and Laclede Gas Company. Each registrant hereto is filing on its own behalf all of the information contained in this annual report that relates to such registrant. Each registrant hereto is not filing any information that does not relate to such registrant, and therefore makes no representation as to any such information.

Note: Laclede Gas Company Selected Financial Data, Management’s Discussion and Analysis of Financial Condition and Results of Operations, Financial Statements, Notes to Financial Statements, Management Report on Internal Control Over Financial Reporting, and Reports of Independent Registered Public Accounting Firm are included as Exhibit 99.1 .


Page No.
     
PART I
   
   
     
     
     
PART II
   
     
 
 
 
     
PART III
   
     
 
 
     
PART IV
   
     
     
 
     
     



 
4
 

Part I

FORWARD-LOOKING STATEMENTS

Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:

weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;
volatility in gas prices, particularly sudden and sustained changes in natural gas prices, including the related impact on margin deposits associated with the use of natural gas derivative instruments;
the impact of changes and volatility in natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;
changes in gas supply and pipeline availability, particularly those changes that impact supply for and access to the markets in which our subsidiaries transact business;
legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting
 
allowed rates of return
 
incentive regulation
 
industry structure
 
purchased gas adjustment provisions
 
rate design structure and implementation
 
regulatory assets
 
franchise renewals
 
environmental or safety matters, including the potential impact of legislative and regulatory actions related to climate change
 
taxes
 
pension and other postretirement benefit liabilities and funding obligations
 
accounting standards, including the effect of potential changes relative to adoption of or convergence with international accounting standards;
the results of litigation;
retention of, ability to attract, ability to collect from, and conservation efforts of, customers;
capital and energy commodity market conditions, including the ability to obtain funds with reasonable terms for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;
discovery of material weakness in internal controls; and
employee workforce issues.

Readers are urged to consider the risks, uncertainties, and other factors that could affect our business as described in this report. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. We do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement in light of future events.



Item 1 . Business

Overview

The Laclede Group, Inc. (Laclede Group or the Company) is a public utility holding company formed through a corporate restructuring that became effective October 1, 2001. Laclede Group is committed to providing reliable natural gas service through its regulated core utility operations while engaging in non-regulated activities that provide sustainable growth. All of Laclede Group’s subsidiaries are wholly owned. The Regulated Gas Distribution segment includes the regulated operations of Laclede Gas Company (Laclede Gas or the Utility), Laclede Group’s largest subsidiary and core business unit. Laclede Gas is a public utility engaged in the retail distribution and sale of natural gas. Laclede Gas is the largest natural gas distribution utility in Missouri, serving approximately 630,000 residential, commercial, and industrial customers in the City of St. Louis and parts of ten counties in eastern Missouri. The Non-Regulated Gas Marketing segment includes Laclede Energy Resources, Inc. (LER), a wholly-owned subsidiary engaged in the marketing of natural gas and related activities on a non-regulated basis. LER markets natural gas to both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service territory, including large retail and wholesale customers. As such, LER’s operations and customer base are more subject to fluctuations in market conditions than the Utility. Other subsidiaries provide less than 10% of consolidated revenues. As of September 30, 2010, Laclede Group had 1,697 employees, including 14 part-time employees.

On March 31, 2008, the Company completed the sale of 100% of its interest in its wholly-owned subsidiary SM&P Utility Resources, Inc. (SM&P) to Stripe Acquisition, Inc. (an affiliate of Kohlberg Management VI, LLC) for $85 million in cash, subject to certain closing and post-closing adjustments. SM&P was an underground facilities locating and marking business that formerly comprised Laclede Group’s Non-Regulated Services operating segment. The sales agreement included representations, warranties, and indemnification provisions customary for such transactions and was filed as an exhibit to the March 31, 2008 Form 10-Q. In accordance with generally accepted accounting principles, the results of operations for SM&P are reported as discontinued operations in the Statements of Consolidated Income.

Operating Revenues (from continuing operations) contributed by each segment for the last three fiscal years are presented below. For more detailed financial information regarding the segments, see Note 15 of the Notes to Consolidated Financial Statements.
 
(Thousands)
 
2010
 
2009
 
2008
 
Regulated Gas Distribution
 
$
864,297
 
$
1,053,993
 
$
1,128,287
 
Non-Regulated Gas Marketing
   
858,782
   
836,865
   
1,075,845
 
Other
   
11,950
   
4,340
   
4,841
 
Total Operating Revenues
 
$
1,735,029
 
$
1,895,198
 
$
2,208,973
 

The consolidated financial statements included in this report present the consolidated financial position, results of operations, and cash flows of Laclede Group. The financial statements, notes to financial statements, and management’s discussion and analysis for Laclede Gas are included in this report as Exhibit 99.1 .



The following chart illustrates the organization structure of The Laclede Group, Inc. at September 30, 2010:
 
Organization Structure
 
         
 
The Laclede
Group, Inc.
 
       
                       
                       
Laclede Gas
Company
 
Laclede
 Investment
 LLC
   
Laclede
 Development
Company
 
Laclede
Pipeline
Company
                       
     
Laclede
Energy
 Resources,
 Inc.
   
 
Laclede
 Venture Corp.
     
                       
     
Laclede Gas
 Family
 Services,
 Inc.
             
                       
 
Laclede Group common stock is listed on The New York Stock Exchange and trades under the ticker symbol “LG.”

During fiscal year 2010, Laclede Group issued 42,733 shares of common stock under its Dividend Reinvestment and Stock Purchase Plan and 81,951 shares of common stock (including 69,451 shares of restricted stock) under its Equity Incentive Plan. During fiscal year 2009, Laclede Group issued 47,037 shares of common stock under its Dividend Reinvestment and Stock Purchase Plan and 127,610 shares of common stock (including 73,485 shares of restricted stock) under its Equity Incentive Plan.

The information we file or furnish to the Securities and Exchange Commission (SEC), including annual reports on Form 10-K, quarterly reports on Form 10-Q, and current reports on Form 8-K and their amendments, are available on our website, www.thelacledegroup.com , in the Investor Services section under SEC Filings as soon as reasonably practical after the information is filed or furnished to the SEC.


REGULATED GAS DISTRIBUTION

NATURAL GAS SUPPLY

The Utility focuses its gas supply portfolio around a number of large natural gas suppliers with equity ownership or control of assets strategically situated to complement Laclede’s regionally diverse firm transportation arrangements.

Laclede Gas’ fundamental gas supply strategy is to meet the two-fold objective of 1) ensuring that the gas supplies it acquires are dependable and will be delivered when needed and 2) insofar as is compatible with that dependability, purchasing gas that is economically priced. In structuring its natural gas supply portfolio, Laclede Gas continues to focus on natural gas assets that are strategically positioned to meet the Utility’s primary objectives. Laclede Gas utilizes both Mid-Continent and Gulf Coast gas sources to provide a level of supply diversity that facilitates the optimization of pricing differentials as well as protecting against the potential of regional supply disruptions.



In fiscal year 2010, Laclede Gas purchased natural gas from 30 different suppliers to meet current gas sales and storage injection requirements. In addition to working with major producers, the Utility has entered into agreements with suppliers that are taking advantage of improved drilling techniques and advancing technologies, which allow Laclede Gas to be flexible in meeting the needs of its customers. Natural gas purchased by Laclede Gas for delivery to our utility service area through the Mississippi River Transmission Corporation (MRT) system totaled 62.2 billion cubic feet (Bcf). The Utility also holds firm transportation on several other interstate pipeline systems that provide access to gas supplies upstream of MRT. In addition to deliveries from MRT, 7.9 Bcf of gas was purchased on the Panhandle Eastern Pipe Line Company system, and 10.1 Bcf on the Southern Star Central Pipeline system. Some of the Utility’s commercial and industrial customers purchased their own gas with Laclede Gas transporting 15.0 Bcf to them through the Utility’s distribution system.

The fiscal year 2010 peak day sendout of natural gas to utility customers, including transportation customers, occurred on January 7, 2010, when the average temperature was 11 degrees Fahrenheit. On that day, our customers consumed 0.920 Bcf of natural gas. About 81% of this peak day demand was met with natural gas transported to St. Louis through the MRT, Panhandle, and Southern Star transportation systems, and the other 19% was met from the Utility’s on-system storage and peak shaving resources.

UNDERGROUND NATURAL GAS STORAGE

Laclede Gas has a contractual right to store 23.1 Bcf of gas in MRT’s storage facility located in Unionville, Louisiana. MRT’s tariffs allow injections into storage from May 16 through November 15 and require the withdrawal from storage of all but 2.2 Bcf from November 16 through May 15.

In addition, Laclede Gas supplements flowing pipeline gas with natural gas withdrawn from its own underground storage field located in St. Louis and St. Charles Counties in Missouri. The field is designed to provide 0.30 Bcf of natural gas withdrawals on a peak day and annual withdrawals of approximately 4 Bcf of gas based on the inventory level that Laclede plans to maintain.

REGULATORY MATTERS

There were several significant regulatory developments over the past year. For more details, please see the Regulatory and Other Matters discussion in the Management’s Discussion and Analysis of Financial Condition and Results of Operations, on page 35 of this Form 10-K.

OTHER PERTINENT MATTERS

The business of Laclede Gas has monopoly characteristics in that it is the only distributor of natural gas within its franchised service area. The principal competition is the local electric company. Other competitors in Laclede Gas’ service area include suppliers of fuel oil, coal, propane in outlying areas, natural gas pipelines which can directly connect to large volume customers, and in a portion of downtown St. Louis, a district steam system.

Laclede Gas’ residential, commercial, and small industrial markets represent more than 90% of the Utility’s Regulated Gas Distribution operating revenue. Given the current adequate level of natural gas supply and market conditions, Laclede believes that the relative comparison of natural gas equipment and operating costs with those of competitive fuels will not change significantly in the foreseeable future, and that these markets will continue to be supplied by natural gas. In the new multi-family and commercial rental markets, Laclede Gas’ competitive exposure is presently limited to space and water heating applications. Certain alternative heating systems can be cost competitive in traditional markets, but the performance and reliability of natural gas systems have contained the growth of these alternatives.



Coal is price competitive as a fuel source for very large boiler plant loads, but environmental requirements for coal have shifted the economic advantage to natural gas. Oil and propane can be used to fuel boiler loads and certain direct-fired process applications, but these fuels require on-site storage, thus limiting their competitiveness. In certain cases, district steam has been competitive with gas for downtown St. Louis area heating users. Laclede Gas offers gas transportation service to its large user industrial and commercial customers. The tariff approved for that type of service produces a margin similar to that which Laclede Gas would have received under its regular sales rates.

*****

Laclede Gas is subject to various environmental laws and regulations that, to date, have not materially affected the Company’s financial position and results of operations. For a detailed discussion of environmental matters, see Note 16 of the Notes to Consolidated Financial Statements on page 88.

*****

Laclede Gas has labor agreements with Locals 11-6 and 11-194 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union, which represent approximately 63% of Laclede Gas’ employees. The agreements expire at midnight on July 31, 2012.

The Missouri Natural Division of Laclede Gas has labor agreements with Local 884 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union, which represents approximately 5% of Laclede Gas’ employees. The agreements expire at midnight on April 14, 2013.

*****

The business of Laclede Gas is subject to seasonal fluctuations with the peak period occurring in the winter season.



Revenues, therms sold and transported, and customers of Laclede Gas for the last three fiscal years are as follows:

Regulated Gas Distribution Operating Revenues
 
               
(Thousands)
 
2010
 
2009
 
2008
 
Residential
 
$
589,350
 
$
684,533
 
$
696,919
 
Commercial & Industrial
   
208,953
   
255,912
   
267,639
 
Interruptible
   
4,246
   
5,301
   
4,704
 
Transportation
   
13,378
   
14,394
   
16,008
 
Off-System and Capacity Release
   
38,988
   
85,822
   
132,145
 
Provision for Refunds and Other
   
9,382
   
8,031
   
10,872
 
     Total
 
$
864,297
 
$
1,053,993
 
$
1,128,287
 
                     
Regulated Gas Distribution Therms Sold and Transported
     
                     
(Thousands)
 
2010
 
2009
 
2008
 
Residential
   
506,576
   
509,025
   
514,450
 
Commercial & Industrial
   
231,292
   
238,675
   
242,122
 
Interruptible
   
6,267
   
5,678
   
5,020
 
Transportation
   
150,386
   
154,603
   
172,985
 
     System Therms Sold and Transported
   
894,521
   
907,981
   
934,577
 
Off-System
   
70,966
   
163,020
   
143,686
 
     Total Therms Sold and Transported
   
965,487
   
1,071,001
   
1,078,263
 
                     
Regulated Gas Distribution Customers (End of Period)
       
                     
     
2010
   
2009
   
2008
 
Residential
   
586,974
   
588,792
   
588,228
 
Commercial & Industrial
   
40,264
   
40,608
   
40,801
 
Interruptible
   
18
   
17
   
17
 
Transportation
   
137
   
146
   
144
 
     Total Customers
   
627,393
   
629,563
   
629,190
 

*****

Laclede Gas has franchises in the more than 90 communities where it provides service with terms varying from five years to an indefinite duration. Generally, a franchise allows Laclede Gas, among other things, to install pipes and construct other facilities in the community. The franchise in Clayton, Missouri expired in 2008 and since that time Laclede Gas has continued to provide service in that community without a formal franchise. All of the franchises are free from unduly burdensome restrictions and are adequate for the conduct of Laclede Gas’ current public utility business in the State of Missouri.


NON-REGULATED GAS MARKETING

LER, a wholly-owned subsidiary of Laclede Investment, LLC, and Laclede Group’s primary non-regulated business, is engaged in the marketing of natural gas and providing energy services to both on-system utility transportation customers and customers outside of Laclede Gas’ traditional service area. During fiscal year 2010, LER utilized 13 interstate pipelines and approximately 80 suppliers to market natural gas to its customers, including large retail and wholesale customers primarily in the Midwest. Furthermore, LER served more than 150 retail customers and approximately 100 wholesale customers. Through its retail operations, LER offers natural gas marketing services to large industrial customers, while its wholesale business consists of buying and selling natural gas to other marketers, producers, utilities, power generators, pipelines, and municipalities.



During the past several years, LER has been successful in growing its geographic footprint by significantly expanding its wholesale business, which currently represents approximately 85% of LER’s operating revenues. While LER reported record earnings in fiscal 2009, new pipeline infrastructure brought online across the country during 2009, along with a growing surplus of natural gas supplies, impacted the pricing dynamics of the marketplace resulting in an industry-wide narrowing of regional price differentials. Despite an increasingly challenging environment, LER succeeded in increasing its sales volumes in fiscal 2010. Although per unit sales margins declined compared to fiscal 2009, LER remained profitable and expanded its market base of industrial customers, customers located in the eastern United States, and power plants that use natural gas to generate electricity. Natural gas has become a popular fuel for generating electricity, and LER remains committed to acquiring the resources necessary to serve this growing market. Natural gas commodity price risk associated with LER’s business is closely measured and managed as it seeks new growth opportunities. LER’s revenues and sales volumes for the last three fiscal years are as follows:

               
(Thousands)
 
2010
 
2009
 
2008
 
Non-Regulated Gas Marketing Revenues
 
$
858,782
 
$
836,865
 
$
1,075,845
 
Non-Regulated Gas Marketing Therms Sold
   
1,864,104
   
1,826,465
   
1,229,221
 


OTHER SUBSIDIARIES

Laclede Pipeline Company, a wholly-owned subsidiary of Laclede Group, operates a pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction. This pipeline connects the propane storage and vaporization facilities of Laclede Gas to third-party propane supply terminal facilities located in Illinois, which allows Laclede Gas to receive propane that is vaporized to supplement its natural gas supply and meet peak demands on its distribution system. Laclede Pipeline Company also provides transportation services to third parties.

Laclede Investment LLC, a wholly-owned subsidiary of Laclede Group, invests in other enterprises and has made loans to several joint ventures engaged in real estate development.

Laclede Gas Family Services, Inc., a wholly-owned subsidiary of Laclede Energy Resources, Inc., is a registered insurance agency in the State of Missouri.

Laclede Development Company, a wholly-owned subsidiary of Laclede Group, participates in real estate development, primarily through joint ventures.

Laclede Venture Corp., a wholly-owned subsidiary of Laclede Development Company, offers services for the compression of natural gas to third parties who desire to use or to sell compressed natural gas for use in vehicles.

The lines of business that constitute the Other activities of the corporate family are not considered separately reportable operating segments as defined by current accounting standards.


Item 1A. Risk Factors

Laclede Group’s business and financial results are subject to a number of risks and uncertainties, including those set forth below. The risks described below are those the Company considers to be material.

RISKS AND UNCERTAINTIES THAT RELATE TO THE BUSINESS AND FINANCIAL RESULTS OF LACLEDE GROUP AND ITS SUBSIDIARIES

As a holding company, Laclede Group depends on its operating subsidiaries to meet its financial obligations.

Laclede Group is a holding company with no significant assets other than cash investments and the stock of its operating subsidiaries. Laclede Group, and Laclede Gas prior to Laclede Group’s formation, have paid dividends continuously since 1946. However, Laclede Group relies exclusively on dividends from its subsidiaries, on intercompany loans from its non-utility subsidiaries, and on the repayments of principal and interest from intercompany loans made to its subsidiaries for its cash flows. Laclede Group’s ability to pay dividends to its shareholders is dependent on the ability of its subsidiaries to generate sufficient net income and cash flows to pay upstream dividends and make loans or loan repayments to Laclede Group. Laclede Group’s cash flows for fiscal year 2008 included proceeds from the sale of its wholly-owned subsidiary, SM&P.

A downgrade in Laclede Group’s credit ratings could negatively affect its ability to access capital.

Currently, Laclede Group’s corporate ratings are A by Standard & Poor’s and A- by Fitch. Laclede Group has working capital lines of credit to meet the short-term liquidity needs of its subsidiaries. If the rating agencies lowered Laclede Group’s credit rating, particularly below investment grade, it might significantly limit its ability to borrow and would increase its costs of borrowing. Laclede Group’s ability to borrow and costs of borrowing have a direct impact on its subsidiaries’ ability to execute operating strategies.

Risk of unexpected losses may adversely affect Laclede Group’s financial condition and results of operations.

As with most businesses, there are operations and business risks inherent in the activities of Laclede Group’s subsidiaries. If, in the normal course of business, Laclede Group becomes a party to litigation, such litigation could result in substantial monetary judgments, fines, or penalties or be resolved on unfavorable terms. In accordance with customary practice, Laclede Group and its subsidiaries maintain insurance against a significant portion of, but not all, risks and losses. To the extent a loss is not fully covered by insurance, that loss could adversely affect the Company’s financial condition and results of operations.

Changes in accounting standards may adversely impact Laclede Group’s financial condition and results of operations.

The SEC is currently considering whether issuers in the United States of America (U.S.) should be required to prepare financial statements in accordance with International Financial Reporting Standards (IFRS) instead of U.S. Generally Accepted Accounting Principles (GAAP). IFRS is a comprehensive set of accounting standards promulgated by the International Accounting Standards Board (IASB), which are rapidly gaining worldwide acceptance. The SEC has indicated that it will decide in 2011 whether IFRS will be required for U.S. issuers. If the SEC decides to require IFRS, it expects that U.S. issuers would first report under the new standards beginning in approximately 2015 or 2016. Unlike U.S. GAAP, IFRS does not currently address the accounting for rate-regulated activities, such as those of Laclede Gas. As such, if IFRS were adopted in its current state, Laclede Gas may be precluded from applying regulatory accounting principles, including the recognition of regulatory assets and regulatory liabilities. Although the IASB currently has a project on its agenda to examine the accounting for rate-regulated activities, there is no assurance that such project will result in the issuance of a final standard or that such a standard would be comparable to current U.S. GAAP. The potential issues associated with rate-regulated accounting, along with other potential changes associated with the adoption of IFRS, may adversely impact Laclede Group’s and Laclede Gas’ financial condition and results of operations, should adoption of IFRS be required. Also, the U.S. Financial Accounting Standards Board is considering various changes to U.S. GAAP, some of which may be significant, as a part of a joint effort with the IASB to converge accounting standards. If approved, adoption of these changes may adversely impact Laclede Group’s and Laclede Gas’ financial condition and results of operations.




RISKS THAT RELATE TO THE REGULATED GAS DISTRIBUTION SEGMENT

Risks related to the regulation of the Utility business could impact rates it is able to charge, costs, and profitability.

The Missouri Public Service Commission (MoPSC or Commission) regulates many aspects of the Utility’s distribution operations, including construction and maintenance of facilities, operations, safety, the rates that the Utility may charge customers, the terms of service to its customers, and the rate of return that it is allowed to realize; as well as the accounting treatment for certain aspects of its operations. For further discussion of these accounting matters, see Critical Accounting Policies pertaining to Laclede Gas, beginning on page 32. Laclede Gas’ ability to obtain and timely implement rate increases and rate supplements to maintain the current rate of return depends upon regulatory discretion. There can be no assurance that it will be able to obtain rate increases or rate supplements or continue earning the current authorized rates of return.

Laclede Gas’ liquidity could be adversely affected by delays in recovery of its costs, due to regulation.

In the normal course of business, there may be a lag between when the Utility incurs increases in certain of its costs and the time in which those costs are considered for recovery in the ratemaking process. Cash requirements for increased operating costs, increased funding levels of defined benefit pension and postretirement costs, capital expenditures, and other increases in the costs of doing business may require outlays of cash prior to the authorization of increases in rates charged to customers, as approved by the MoPSC. Accordingly, the Utility’s liquidity may be adversely impacted to the extent higher costs are not timely recovered from its customers.

Laclede Gas’ ability to meet its customers’ natural gas requirements may be impaired if contracted gas supplies, interstate pipeline and/or storage services are not available or delivered in a timely manner.

In order to meet its customers’ annual and seasonal natural gas demands, the Utility must obtain sufficient supplies, interstate pipeline capacity, and storage capacity. If it is unable to obtain these, either from its suppliers’ inability to deliver the contracted commodity or the inability to secure replacement quantities, Laclede Gas’ financial condition and results of operations may be adversely impacted.

Laclede Gas’ liquidity and, in certain circumstances, its results of operations could be adversely affected by the cost of purchasing natural gas during periods in which natural gas prices are rising significantly.

Laclede Gas’ tariff rate schedules contain Purchased Gas Adjustment (PGA) Clauses that permit the Utility to file for rate adjustments to recover the cost of purchased gas. Changes in the cost of purchased gas are flowed through to customers and may affect uncollectible amounts and cash flows and can therefore impact the amount of capital resources. Currently, Laclede Gas is allowed to adjust the gas cost component of its rates up to four times each year. The Utility must make a mandatory gas cost adjustment at the beginning of the winter, in November, and during the next twelve months it may make up to three additional discretionary gas cost adjustments, so long as each of these adjustments is separated by at least two months.

The MoPSC typically approves the Utility’s PGA changes on an interim basis, subject to refund and the outcome of a subsequent audit and prudence review. Due to such review process, there is a risk of a disallowance of full recovery of these costs. Any material disallowance of purchased gas costs would adversely affect revenues. Increases in the prices the Utility charges for gas may also adversely affect revenues because they could lead customers to reduce usage and cause some customers to have trouble paying the resulting higher bills. These higher prices may increase bad debt expenses and ultimately reduce earnings. Laclede Gas has used short-term borrowings in the past to finance storage inventories and purchased gas costs, and expects to do so in the future. Rapid increases in the price of purchased gas may result in an increase in short-term debt because Laclede Gas must pay suppliers for gas in advance of when its customers pay for that gas.

To lower financial exposure to commodity price fluctuations, Laclede Gas enters into contracts to hedge the forward commodity price of its natural gas supplies. As part of this strategy, the Utility may use fixed-price, forward, physical purchase contracts, futures, and option contracts. However, the Utility does not hedge the entire exposure of energy assets or positions to market price volatility, and the coverage will vary over time. Any costs, gains, or losses experienced through hedging procedures, including carrying costs, generally flow through the PGA Clause, thereby limiting the Utility’s exposure to earnings volatility. However, variations in the timing of collections of such gas costs under the PGA Clause and the effect of cash payments for margin deposits associated with the Utility’s use of natural gas derivative instruments may cause short-term cash requirements to vary. These procedures remain subject to prudence review by the MoPSC.



Laclede Gas may be adversely affected by economic conditions.

Periods of slowed economic activity, such as that currently being experienced, generally result in decreased energy consumption, particularly by industrial and large commercial companies. As a consequence, national or regional recessions or other downturns in economic activity could adversely affect Laclede Gas’ revenues and cash flows or restrict its future growth. Economic conditions in its service territory may also adversely impact the Utility’s ability to collect its accounts receivable resulting in an increase to bad debt expenses.

Laclede Gas is dependent on bank lines of credit and continued access to capital markets to successfully execute its operating strategies.

In addition to longer-term debt that is issued to the public by the Utility under its mortgage and deed of trust dated February 1, 1945, Laclede Gas has relied, and continues to rely, upon shorter term bank borrowings or commercial paper supported by bank lines of credit to finance the execution of a portion of its operating strategies. The Utility is dependent on these capital sources to purchase its natural gas supply and maintain its properties. The availability and cost of these credit sources is cyclical and these capital sources may not remain available to the Utility, or it may not be able to obtain funds at a reasonable cost in the future. Laclede Gas’ ability to borrow under its existing lines of credit depends on its compliance with the Utility’s obligations under the lines of credit. If the Utility were to breach any of the financial or other covenants under these agreements, its debt repayment obligations under them could be accelerated. Laclede Gas’ ability to issue commercial paper supported by its lines of credit, to issue long-term bonds, or to obtain new lines of credit also depends on current conditions in the credit markets.

A downgrade in the Utility’s credit rating could negatively affect its ability to access capital.

Standard & Poor’s rating group, Moody’s Investors Service, and Fitch Ratings from time to time implement new requirements for various ratings levels. To maintain its current credit ratings in light of any new requirements, Laclede Gas may find it necessary to take steps to change its business plans in ways that may affect its results of operations.

The following table shows the current ratings assigned by S&P, Moody’s, and Fitch to certain of our outstanding debt:

Type of Facility
S&P
Moody’s
Fitch
Laclede Gas First Mortgage Bonds
A
A2
A+
Laclede Gas Commercial Paper
A-1
P-2
F1

If the rating agencies lowered the Utility’s ratings, particularly below investment grade, it could significantly limit its access to the commercial paper market and would increase its costs of short-term borrowing. In addition, Laclede Gas would likely be required to pay a higher interest rate in future long-term financings and the Utility’s potential pool of investors and funding sources would likely decrease. Credit ratings are an independent assessment of the Utility’s ability to pay its obligations. Consequently, real or anticipated changes in credit ratings will generally affect the market value of the specific debt instruments that are rated.

Numerous environmental laws and regulations may require significant expenditures or increase operating costs.

Laclede Gas is subject to federal and state environmental laws and regulations affecting many aspects of its present and future operations. These laws and regulations require Laclede Gas to obtain and comply with a wide variety of environmental licenses, permits, inspections, and approvals. The discovery of presently unknown environmental conditions could give rise to expenditures and liabilities including fines or penalties, which could be material. To the extent such costs are not fully covered by insurance or recovered in rates from Utility customers, those costs may have an adverse effect on the financial condition and results of operations of Laclede Gas.



Laclede Gas is subject to pipeline safety and system integrity laws and regulations that may require significant expenditures or significant increases in operating costs.

Such laws and regulations affect various aspects of Laclede Gas’ present and future operations. These laws and regulations require the Utility to maintain pipeline safety and system integrity by identifying and reducing pipeline risks. Compliance with these laws and regulations may result in increased capital, operating and other costs which may not be recoverable in a timely manner from customers in rates. Failure to comply may result in fines, penalties, or injunctive measures that would not be recoverable from customers in rates and could result in a material adverse effect on Laclede Gas’ financial condition and results of operations.

Transporting, distributing, and storing natural gas involves numerous risks that may result in accidents and other operating risks and costs.

There are inherent in gas distribution activities a variety of hazards and operations risks, such as leaks, accidental explosions, and mechanical problems, which could cause substantial financial losses. In addition, these risks could result in loss of human life, significant damage to property, environmental pollution, impairment of operations, and substantial losses to Laclede Gas. The location of pipelines and storage facilities near populated areas, including residential areas, commercial business centers, and industrial sites, could increase the level of damages resulting from these risks. These activities may subject the Utility to litigation or administrative proceedings from time to time. Such litigation or proceedings could result in substantial monetary judgments, fines, or penalties against the Utility or be resolved on unfavorable terms. In accordance with customary industry practices, Laclede Gas maintains insurance against a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these events is not fully covered by insurance, it could adversely affect the Utility’s financial condition and results of operations.

Increases in the wholesale costs of purchased natural gas supplies may adversely impact the Utility’s competitive position compared with alternative energy sources.

Laclede Gas is the only distributor of natural gas within its franchised service area. Nevertheless, rising wholesale natural gas prices compared with prices for electricity, fuel oil, coal, propane, or other energy sources may affect the Utility’s retention of natural gas customers and adversely impact its financial condition and results of operations.

Significantly warmer-than-normal weather conditions, the effects of global warming and climate change, and other factors that influence customer usage may affect the Utility’s sale of heating energy and adversely impact its financial position and results of operations.

Laclede Gas’ earnings are primarily generated by the sale of heating energy. The Utility has a weather mitigation rate design, approved by the MoPSC, which provides better assurance of the recovery of the Utility’s fixed costs and margins during winter months despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage. However, significantly warmer-than-normal weather conditions in the Utility’s service area and other factors, such as global warming and climate change, may result in reduced profitability and decreased cash flows attributable to lower gas sales levels. Furthermore, continuation of the weather mitigation rate design is subject to regulatory discretion. In addition, the promulgation of regulations by the U.S. Environmental Protection Agency or the potential enactment of Congressional legislation addressing global warming and climate change may result in future additional compliance costs that could impact the Utility’s financial condition and results of operations.

Regional supply/demand fluctuations and changes in national pipeline infrastructure, as well as regulatory discretion, may adversely affect Laclede Gas’ ability to profit from off-system sales and capacity release.

Laclede Gas’ income from off-system sales and capacity release is subject to fluctuations in market conditions and changing supply and demand conditions in areas the Utility holds pipeline capacity rights. Specific factors impacting the Utility’s income from off-system sales and capacity release include the availability of attractively-priced natural gas supply, availability of pipeline capacity, and market demand. Income from off-system sales and capacity release is shared with customers. The Utility is allowed to retain 15% to 25% of the first $6 million in annual income earned (depending on the level of income earned) and 30% of income exceeding $6 million annually. The Utility’s ability to retain such income in the future is subject to regulatory discretion in a base rate proceeding.



Workforce risks could affect Laclede Gas’ financial results.

Laclede Gas is subject to various workforce risks, including, but not limited to, the risk that it will be unable to attract and retain qualified personnel; that it will be unable to effectively transfer the knowledge and expertise of an aging workforce to new personnel as those workers retire; and that it will be unable to reach collective bargaining arrangements with the unions that represent certain of its workers, which could result in work stoppages.

Catastrophic events could adversely affect Laclede Gas’ facilities and operations.

Catastrophic events such as fires, earthquakes, explosions, floods, tornados, terrorists acts, or other similar occurrences could adversely affect Laclede Gas’ facilities, operations, financial condition, and results of operations. The availability of insurance covering catastrophic events may be limited or may result in higher deductibles, higher premiums and more restrictive policy terms.


RISKS THAT RELATE TO THE NON-REGULATED GAS MARKETING SEGMENT

Risks of increased competition, regional fluctuations in natural gas commodity prices, and pipeline infrastructure projects may adversely impact LER’s future profitability.

Competition in the marketplace and regional fluctuations in natural gas commodity prices have a direct impact on LER’s business. Changing market conditions may adversely impact LER’s sales margins or affect LER’s ability to serve certain wholesale customers, thereby reducing wholesale sales profitability and/or increasing certain credit requirements caused by reductions in netting capability. Although the FERC regulates the interstate transportation of natural gas and establishes the general terms and conditions under which LER may use interstate gas pipeline capacity to purchase and transport natural gas, LER must occasionally renegotiate its transportation agreements with a concentrated group of pipeline companies. Renegotiated terms of new agreements may impact LER’s future profitability. Profitability may also be adversely impacted if the pipeline capacity secured by LER is not fully utilized and/or its costs are not fully recovered.

Risks of reduced access to credit and/or capital markets may prevent LER from executing operating strategies.

LER relies on its cash flows, netting capability, parental guarantees, and access to Laclede Group’s liquidity resources to satisfy its credit and working capital requirements. LER’s ability to rely on parental guarantees is dependent upon Laclede Group’s financial condition and credit ratings. If the rating agencies lowered Laclede Group’s credit ratings, particularly below investment grade, counterparty acceptance of parental guarantees may diminish, resulting in decreased availability of credit. Additionally, under such circumstances, certain counterparties may require LER to provide prepayments or cash deposits, amounts of which would be dependent upon natural gas market conditions. Reduced access to credit or increased credit requirements, which may also be caused by factors such as higher overall natural gas prices, may limit LER’s ability to enter into certain transactions. In addition, LER has concentrations of counterparty credit risk in that a significant portion of its transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. LER also has concentrations of credit risk in certain individually significant counterparties. LER closely monitors its credit exposure and, although uncollectible amounts have not been significant, increased counterparty defaults are possible and may result in financial losses and/or capital limitations.



Risk management policies, including the use of derivative instruments, may not fully protect LER’s sales and results of operations from volatility and may result in financial losses.

In the course of its business, LER enters into contracts to purchase and sell natural gas at fixed prices and index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed price commitments. LER manages the commodity price risk associated with fixed-price commitments for the purchase or sale of natural gas by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of natural gas futures and swap contracts traded on or cleared through the New York Mercantile Exchange (NYMEX) to lock in margins. These exchange-traded/cleared contracts are generally designated as cash flow hedges of forecasted transactions. However, market conditions and regional price changes may cause ineffective portions of matched positions to result in financial losses. Additionally, to the extent that LER’s natural gas commitments do not qualify for the normal purchases or normal sales designation (or the designation is not elected), the contracts are recorded as derivatives at fair value each period. Accordingly, the associated gains and losses are reported directly in earnings and may cause volatility in results of operations.

LER’s ability to meet its customers’ natural gas requirements may be impaired if contracted gas supplies and interstate pipeline services are not available or delivered in a timely manner.

LER’s ability to deliver natural gas to its customers is contingent upon the ability of natural gas producers, other gas marketers, and interstate pipelines to fulfill their delivery obligations to LER under firm contracts. If these counterparties fail to perform, they have a contractual obligation to reimburse LER for any adverse consequences. LER will attempt to use such reimbursements to obtain the necessary supplies so that LER may fulfill its customer obligations. To the extent that it is unable to obtain the necessary supplies, LER’s financial position and results of operations may be adversely impacted.

The energy industry is subject to regulatory and legislative developments.

LER’s business is non-regulated in that the rates it charges its customers are not established by or subject to approval by any regulatory body. However, LER is subject to various laws and regulations affecting the energy industry. New regulatory and legislative actions may adversely impact LER’s results of operations, financial condition, and cash flows by potentially reducing customer growth opportunities and/or increasing the costs of doing business.



Item 1B. Unresolved Staff Comments

None.


Item 2. Properties

The principal utility properties of Laclede Gas consist of more than 16,000 miles of gas main and related service pipes, meters, and regulators. Other physical properties include regional office buildings and a holder station. Extensive underground natural gas and propane storage facilities and equipment are located in an area in North St. Louis County extending under the Missouri River into St. Charles County. Substantially all of Laclede Gas’ utility plant is subject to the liens of its mortgage.

All of the utility properties of Laclede Gas are held in fee, or by easement, or under lease agreements. The principal lease agreements include underground storage rights that are of indefinite duration and the headquarters office building. The current lease on the headquarters office building extends through February 2015 with the option to renew for up to five additional years.

For further information on Laclede Gas’ leases see Note 16 of the Notes to Consolidated Financial Statements on page 88.

Other properties of Laclede Group, including LER, do not constitute a significant portion of its properties.


Item 3. Legal Proceedings

For a description of environmental matters, see Note 16 of the Notes to Consolidated Financial Statements on page 88. For a description of pending regulatory matters of Laclede Gas, see the Regulatory and Other Matters discussion in the Management’s Discussion and Analysis of Financial Condition and Results of Operations, on page 35.

Laclede Group and its subsidiaries are involved in litigation, claims, and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes the final outcome will not have a material adverse effect on the consolidated financial position or results of operations reflected in the consolidated financial statements presented herein.






EXECUTIVE OFFICERS OF THE REGISTRANTS – Listed below are executive officers as defined by the SEC for Laclede Group. Their ages, at September 30, 2010, and positions are listed below along with their business experience during the past five years.

Name, Age, and Position with Company *
Appointed (1)
       
D. H. Yaeger, Age 61
 
       
 
Laclede Group
   
 
Chairman, President and Chief Executive Officer
October 2000
       
 
Laclede Gas
   
 
Chairman, President and Chief Executive Officer
January 1999
       
 
LER
   
 
President
 
January 1999
       
M. D. Waltermire, Age 52
 
       
 
Laclede Group
   
 
Chief Financial Officer
October 2007
       
 
Laclede Gas
   
 
Senior Vice President and Chief Financial Officer
October 2007
 
Vice President – Operations & Marketing
April 2003
       
 
LER
   
 
Vice President
October 2007
       
M. C. Darrell, Age 52
 
       
 
Laclede Group
   
 
General Counsel
May 2004
       
 
Laclede Gas
   
 
Senior Vice President and General Counsel
October 2007
 
General Counsel
May 2004
       
R. A. Skau, Age 53
 
       
 
Laclede Gas
   
 
Senior Vice President – Human Resources
October 2007
 
Vice President – Human Resources
February 2004
       
M. R. Spotanski, Age 50
 
       
 
Laclede Gas
   
 
Senior Vice President – Operations and Marketing
October 2007
 
Vice President – Finance
January 2001
       
M. C. Kullman, Age 50
 
       
 
Laclede Group
   
 
Chief Governance Officer and Corporate Secretary
February 2004
       
 
Laclede Gas
   
 
Chief Governance Officer and Corporate Secretary
February 2004
       
 
LER
   
 
Secretary
February 1998




D. P. Abernathy, Age 49
 
       
 
Laclede Gas
   
 
Vice President and Associate General Counsel –
  Industrial Relations and Claims Management
October 2007
     
 
Vice President – Associate General Counsel
September 2004
       
M. C. Geiselhart, Age 51
 
       
 
Laclede Group
   
 
Vice President – Strategic Development and Planning (2)
August 2006
       
 
Laclede Gas
   
 
Vice President – Strategic Development and Planning
August 2006
       
S. F. Mathews, Age 52
 
       
 
Laclede Gas
   
 
Vice President – Gas Supply
February 2003
       
M. C. Pendergast, Age 54
 
       
 
Laclede Gas
   
 
Vice President – Associate General Counsel
January 2002
       
S. P. Rasche, Age 50
 
       
 
Laclede Gas
   
 
Vice President – Finance (3)
November 2009
       
J. A. Fallert, Age 55
 
       
 
Laclede Gas
   
 
Controller
 
February 1998
       
S. E. Jaskowiak, Age 48
 
       
 
LER
   
 
Vice President and General Manager
February 2005
       


*
The information provided relates to the Company and its principal subsidiaries. Many of the executive officers have served or currently serve as officers or directors for other subsidiaries of the Company.

(1)
Officers of Laclede are normally reappointed at the Annual Meeting of the Board of Directors in January of each year to serve at the pleasure of the Board of Directors for the ensuing year and until their successors are elected and qualify.
(2)
Mr. Geiselhart served as the Corporate Finance Consultant for Callaway Partners, LLC since 2003. During that time, he also served as Chief Financial Officer for both TowerLink Corporation, Inc. and Transcender Telecom Acquisition Corporation, Inc.
(3)
Mr. Rasche served as the Chief Financial Officer for TLCVision Corporation since 2004.

Mr. Kenneth J. Neises, former Executive Vice President, retired from Laclede Gas Company October 1, 2010.


Part II

Item 5 . Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities

Laclede Group’s common stock trades on The New York Stock Exchange under the symbol “LG.” The high and the low sales price for the common stock for each quarter in the two most recent fiscal years are:

 
Fiscal 2010
Fiscal 2009
 
High
Low
High
Low
1st Quarter
$
34.92
$
30.17
$
55.81
$
33.55
2nd Quarter
 
34.63
 
30.81
 
48.33
 
35.23
3rd Quarter
 
35.89
 
31.65
 
39.90
 
29.26
4th Quarter
 
35.92
 
32.50
 
35.24
 
30.85

The number of holders of record as of September 30, 2010 was 4,676.

Dividends declared on the common stock for the two most recent fiscal years were:

 
Fiscal 2010
Fiscal 2009
1st Quarter
$
0.395
      $
0.385
2nd Quarter
 
0.395
 
0.385
3rd Quarter
 
0.395
 
0.385
4th Quarter
 
0.395
 
0.385


Disclosures relating to securities authorized for issuance under equity compensation plans is incorporated by reference from our proxy statement dated December 17, 2010.

Laclede Group periodically purchases common stock of Laclede Gas with the price set at the book value of Laclede Gas common stock as of the most recently completed fiscal quarter. The details on sales of common stock of Laclede Gas to Laclede Group during the past three fiscal years are set forth below:

   
Aggregate
     
   
Purchase Price
 
Number
 
Date of Sale
 
(millions)
 
of Shares
 
             
FY 2008
           
December 20, 2007
 
$
1.0
   
30
   
February 14, 2008
   
1.0
   
28
   
May 12, 2008
   
0.9
   
26
   
August 18, 2008
   
0.9
   
25
   
                 
FY 2009
               
November 20, 2008
   
40.0
   
1,161
   
December 18, 2008
   
0.9
   
26
   
February 10, 2009
   
0.4
   
11
   
May 20, 2009
   
0.3
   
9
   
August 14, 2009
   
0.4
   
11
   
                 
FY 2010
               
December 15, 2009
   
0.3
   
10
   
February 8, 2010
   
0.4
   
10
   
May 7, 2010
   
0.4
   
10
   
August 11, 2010
   
0.4
   
10
   

The proceeds from Laclede Gas’ sales of stock were used to reduce its short-term borrowings. Exemption from registration was claimed under Section 4(2) of the Securities Act of 1933.



Item 6 . Selected Financial Data

The Laclede Group, Inc.

   
Fiscal Years Ended September 30
 
(Thousands, Except Per Share Amounts)
 
2010
 
2009
 
2008
 
2007
 
2006
 
Summary of Operations
                               
Operating Revenues:
                               
  Regulated Gas Distribution
 
$
864,297
 
$
1,053,993
 
$
1,128,287
 
$
1,131,554
 
$
1,141,011
 
  Non-Regulated Gas Marketing
   
858,782
   
836,865
   
1,075,845
   
718,704
   
689,572
 
  Other
   
11,950
   
4,340
   
4,841
   
5,603
   
4,445
 
          Total Operating Revenues
   
1,735,029
   
1,895,198
   
2,208,973
   
1,855,861
   
1,835,028
 
                                 
Operating Expenses:
                               
  Regulated Gas Distribution
                               
    Natural and propane gas
   
519,905
   
699,984
   
770,097
   
797,924
   
821,721
 
    Other operation expenses
   
141,995
   
146,542
   
144,611
   
131,798
   
128,180
 
    Maintenance
   
27,244
   
27,818
   
25,827
   
24,306
   
21,198
 
    Depreciation and amortization
   
37,572
   
36,751
   
35,303
   
34,080
   
30,904
 
    Taxes, other than income taxes
   
61,407
   
68,639
   
69,023
   
68,361
   
71,038
 
          Total Regulated Gas Distribution
               Operating Expenses
   
788,123
   
979,734
   
1,044,861
   
1,056,469
   
1,073,041
 
  Non-Regulated Gas Marketing
   
836,687
   
787,056
   
1,048,162
   
698,962
   
662,391
 
  Other
   
5,353
   
3,344
   
4,603
   
5,376
   
5,024
 
          Total Operating Expenses
   
1,630,163
   
1,770,134
   
2,097,626
   
1,760,807
   
1,740,456
 
Operating Income
   
104,866
   
125,064
   
111,347
   
95,054
   
94,572
 
Allowance for Funds Used During Construction
   
(112
)
 
(152
)
 
(72
 
(17
)
 
(45
)
Other Income and (Income Deductions) - Net
   
3,232
   
1,605
   
1,953
   
6,830
   
5,553
 
Interest Charges:
                               
  Interest on long-term debt
   
24,583
   
24,583
   
19,851
   
22,502
   
22,329
 
  Interest on long-term debt to unconsolidated
    affiliate trust
   
   
   
486
   
277
   
277
 
  Other interest charges
   
2,269
   
5,163
   
9,140
   
11,155
   
10,278
 
          Total Interest Charges
   
26,852
   
29,746
   
29,477
   
33,934
   
32,884
 
Income from Continuing Operations Before Income
                               
  Taxes and Dividends on Laclede Gas Redeemable
                               
    Preferred Stock
   
81,134
   
96,771
   
83,751
   
67,933
   
67,196
 
Income Tax Expense
   
27,094
   
32,509
   
26,190
   
22,146
   
21,301
 
Dividends on Laclede Gas Redeemable
                               
  Preferred Stock
   
   
15
   
35
   
43
   
48
 
Income from Continuing Operations
   
54,040
   
64,247
   
57,526
   
45,744
   
45,847
 
Income from Discontinued Operations, Net
                               
  of Income Tax
   
   
   
20,396
   
4,027
   
3,142
 
Net Income
 
$
54,040
 
$
64,247
 
$
77,922
 
$
49,771
 
$
48,989
 
                                 
Average Number of Common Shares Outstanding:
                               
  Basic
   
21,986
   
21,893
   
21,657
   
21,455
   
21,247
 
  Diluted
   
22,039
   
21,960
   
21,730
   
21,496
   
21,279
 
                                 
Basic Earnings Per Share of Common Stock:
                               
  Income from Continuing Operations
 
$
2.43
 
$
2.90
 
$
2.64
 
$
2.12
 
$
2.15
 
  Income from Discontinued Operations
   
   
   
0.93
   
0.19
   
0.15
 
  Net Income
 
$
2.43
 
$
2.90
 
$
3.57
 
$
2.31
 
$
2.30
 
                                 
Diluted Earnings Per Share of Common Stock:
                               
  Income from Continuing Operations
 
$
2.43
 
$
2.89
 
$
2.63
 
$
2.11
 
$
2.15
 
  Income from Discontinued Operations
   
   
   
0.93
   
0.19
   
0.15
 
  Net Income
 
$
2.43
 
$
2.89
 
$
3.56
 
$
2.30
 
$
2.30
 



Item 6. Selected Financial Data (continued)

The Laclede Group, Inc.

   
Fiscal Years Ended September 30
 
(Thousands, Except Per Share Amounts)
 
2010
 
2009
 
2008
 
2007
 
2006
 
                                 
Dividends Declared –
                               
  Common Stock
 
$
35,127
 
$
34,100
 
$
32,776
 
$
31,505
 
$
30,045
 
Dividends Declared Per
                               
  Share of Common Stock
 
$
1.58
 
$
1.54
 
$
1.50
 
$
1.46
 
$
1.41
 
                                 
Utility Plant
                               
  Gross Plant – End of Period
 
$
1,326,284
 
$
1,280,238
 
$
1,229,174
 
$
1,187,828
 
$
1,149,104
 
  Net Plant – End of Period
   
884,084
   
855,929
   
823,197
   
793,794
   
763,827
 
  Capital Expenditures
   
56,234
   
51,384
   
55,304
   
56,434
   
57,925
 
  Property Retirements
   
10,946
   
9,732
   
15,629
   
16,331
   
22,588
 
Non-Utility Property
   
4,551
   
4,061
   
3,793
   
4,065
   
4,263
 
Other Investments
   
50,226
   
44,973
   
43,314
   
43,635
   
41,354
 
Total Assets of Discontinued Operations
   
   
   
   
73,357
   
76,353
 
Total Assets – End of Period
   
1,840,196
   
1,762,018
   
1,772,655
   
1,641,153
   
1,570,160
 
                                 
Capitalization – End of Period
                               
  Common Stock and Paid-In Capital
 
$
180,991
 
$
176,386
 
$
169,234
 
$
157,707
 
$
148,487
 
  Retained Earnings
   
361,723
   
342,810
   
312,808
   
268,761
   
250,495
 
  Accumulated Other Comprehensive Income (Loss)
   
(7,137
)
 
(2,166
)
 
4,437
   
1,857
   
3,655
 
        Common Stock Equity
   
535,577
   
517,030
   
486,479
   
428,325
   
402,637
 
  Laclede Gas Redeemable Preferred Stock
   
   
   
467
   
627
   
787
 
  Long-Term Debt to Unconsolidated Affiliate Trust
   
   
   
   
46,400
   
46,400
 
  Long-Term Debt – Laclede Gas
   
364,298
   
389,240
   
389,181
   
309,122
   
349,041
 
Total Capitalization
 
$
899,875
 
$
906,270
 
$
876,127
 
$
784,474
 
$
798,865
 
                                 
Shares of Common Stock
                               
  Outstanding – End of Period
   
22,293
   
22,168
   
21,993
   
21,646
   
21,362
 
  Book Value Per Share – End of Period
 
$
24.02
 
$
23.32
 
$
22.12
 
$
19.79
 
$
18.85
 
                                 
Consolidated Net Economic Earnings Data (a)
                               
                                 
Net Economic Earnings (Non-GAAP)
 
$
56,165
 
$
60,806
 
$
59,154
 
$
46,082
 
$
44,482
 
Add: Unrealized gain (loss) on energy-related
  derivative contracts, net of tax
   
(2,125
)
 
3,441
   
(1,628
)
 
(338
)
 
1,365
 
Income from Continuing Operations (GAAP)
 
$
54,040
 
$
64,247
 
$
57,526
 
$
45,744
 
$
45,847
 
                                 
Diluted Earnings per Share of Common Stock:
                               
  Net Economic Earnings (Non-GAAP)
 
$
2.52
 
$
2.74
 
$
2.70
 
$
2.13
 
$
2.08
 
  Add: Unrealized gain (loss) on energy-related
    derivative contracts, net of tax
   
(0.09
)
 
0.15
   
(0.07
)
 
(0.02
)
 
0.07
 
  Income from Continuing Operations (GAAP)
 
$
2.43
 
$
2.89
 
$
2.63
 
$
2.11
 
$
2.15
 
 
  (a)
This section contains the non-GAAP financial measures of net economic earnings and net economic earnings per share. Refer to the Earnings section of Management’s Discussion and Analysis of Financial Condition and Results of Operations on page 27 for a discussion regarding the use of non-GAAP measures.


Note:
Earnings per share (EPS) and diluted shares outstanding amounts for previous periods have been restated to reflect the retrospective application of a new accounting standard that the Company adopted on October 1, 2009. Reported net income was not affected by the adoption of this new accounting standard.
   
 
Discontinued operations reflects the operations and sale of the Company’s former subsidiary, SM&P Utility Resources, Inc., which was sold on March 31, 2008.

Laclede Gas Company’s Selected Financial Data is included in Exhibit 99.1.



ITEM 7 . MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS


THE LACLEDE GROUP, INC.

INTRODUCTION

This management’s discussion analyzes the financial condition and results of operations of The Laclede Group, Inc. (Laclede Group or the Company) and its subsidiaries. It includes management’s view of factors that affect its business, explanations of past financial results including changes in earnings and costs from the prior year periods, and their effects on the Company’s overall financial condition and liquidity.

The Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Company’s consolidated financial statements and the notes thereto.


RESULTS OF OPERATIONS

Overview

Laclede Group’s earnings are primarily derived from the regulated activities of its largest subsidiary, Laclede Gas Company (Laclede Gas or the Utility), Missouri’s largest natural gas distribution company. Laclede Gas is regulated by the Missouri Public Service Commission (MoPSC or Commission) and serves the City of St. Louis and parts of ten counties in eastern Missouri. Laclede Gas delivers natural gas to retail customers at rates and in accordance with tariffs authorized by the MoPSC. The Utility’s earnings are primarily generated by the sale of heating energy. The Utility’s weather mitigation rate design lessens the impact of weather volatility on Laclede Gas customers during cold winters and stabilizes the Utility’s earnings by recovering fixed costs more evenly during the heating season. Due to the seasonal nature of the business of Laclede Gas, Laclede Group’s earnings are seasonal in nature and are typically concentrated in the November through April period, which generally corresponds with the heating season.

Laclede Energy Resources, Inc. (LER) is engaged in the marketing of natural gas and related activities on a non-regulated basis. LER markets natural gas to both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service territory, including large retail and wholesale customers. LER’s operations and customer base are more subject to fluctuations in market conditions than the Utility.

Other subsidiaries provide less than 10% of consolidated revenues.

On March 31, 2008, the Company completed the sale of 100% of its interest in its wholly-owned subsidiary SM&P Utility Resources, Inc. (SM&P) to Stripe Acquisition, Inc. (an affiliate of Kohlberg Management VI, LLC) for $85 million in cash, subject to certain closing and post-closing adjustments. SM&P was an underground facilities locating and marking business that formerly comprised Laclede Group’s Non-Regulated Services operating segment. The sales agreement included representations, warranties, and indemnification provisions customary for such transactions and was filed as an exhibit to the March 31, 2008 Form 10-Q. In accordance with generally accepted accounting principles, the results of operations for SM&P are reported as discontinued operations in the Statements of Consolidated Income.



Based on the nature of the business of the Company and its subsidiaries, as well as current economic conditions, management focuses on the following key variables in evaluating the financial condition and results of operations and managing the business:

Regulated Gas Distribution Segment:

the Utility’s ability to recover the costs of purchasing and distributing natural gas from its customers;
the impact of weather and other factors, such as customer conservation, on revenues and expenses;
changes in the regulatory environment at the federal, state, and local levels, as well as decisions by regulators, that impact the Utility’s ability to earn its authorized rate of return;
the Utility’s ability to access credit markets and maintain working capital sufficient to meet operating requirements; and,
the effect of natural gas price volatility on the business.

Non-Regulated Gas Marketing Segment:

the risks of competition;
regional fluctuations in natural gas prices;
new national pipeline infrastructure projects;
credit and/or capital market access;
counterparty risks; and,
the effect of natural gas price volatility on the business.
 
Further information regarding how management seeks to manage these key variables is discussed below.
 
Laclede Group’s strategy is to improve the performance of its core Utility, while developing non-regulated businesses and taking a measured approach in the pursuit of additional growth opportunities that complement the Utility business.

The Utility’s strategy focuses on improving performance and mitigating the impact of weather fluctuations on Laclede Gas’ customers while improving the ability to recover its authorized distribution costs and return. The Utility’s distribution costs are the essential, primarily fixed expenditures it must incur to operate and maintain more than 16,000 miles of mains and services comprising its natural gas distribution system and related storage facilities. The Utility’s distribution costs include wages and employee benefit costs, depreciation and maintenance expenses, and other regulated utility operating expenses, excluding natural and propane gas expense. Distribution costs are considered in the ratemaking process, and recovery of these types of costs is included in revenues generated through the Utility’s tariff rates, as approved by the MoPSC. In addition, Laclede Gas is working to improve its ability to provide reliable natural gas service at a reasonable cost, while maintaining and building a secure and dependable infrastructure. The settlement of the Utility’s rate case in 2010 retained the Utility’s weather mitigation rate design that better ensures the recovery of its fixed costs and margins despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage.

The Utility’s income from off-system sales and capacity release remains subject to fluctuations in market conditions. The Utility is allowed to retain 15% to 25% of the first $6 million in annual income earned (depending on the level of income earned) and 30% of income exceeding $6 million annually. Some of the factors impacting the level of off-system sales include the availability and cost of the Utility’s natural gas supply, the weather in its service area, and the weather in other markets. When Laclede Gas’ service area experiences warmer-than-normal weather while other markets experience colder weather or supply constraints, some of the Utility’s natural gas supply is available for off-system sales and there may be a demand for such supply in other markets. See the Regulatory and Other Matters section on page 35 of this report for additional information on regulatory issues relative to the Utility.


Laclede Gas works actively to reduce the impact of wholesale natural gas prices on its costs by strategically structuring its natural gas supply portfolio to increase its gas supply availability and pricing alternatives and through the use of derivative instruments to protect its customers from significant changes in the commodity price of natural gas. Nevertheless, the overall cost of purchased gas remains subject to fluctuations in market conditions. The Utility’s Purchased Gas Adjustment (PGA) Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of derivative instruments to hedge the purchase price of natural gas, as well as gas inventory carrying costs. The Utility believes it will continue to be able to obtain sufficient gas supply. The price of natural gas supplies and other economic conditions may affect sales volumes, due to the conservation efforts of customers, and cash flows associated with the timing of collection of gas costs and related accounts receivable from customers. Long-term increases in the wholesale cost of natural gas supplies may adversely impact the Utility’s competitive position compared with alternative energy sources.

The Utility relies on both short-term credit and long-term capital markets, as well as cash flows from operations, to satisfy its seasonal cash requirements and fund its cost of capital expenditures. Laclede Gas’ ability to issue commercial paper supported by lines of credit, to issue long-term bonds, or to obtain new lines of credit is dependent on current conditions in the credit and capital markets. Management focuses on maintaining a strong balance sheet and believes it currently has adequate access to credit and capital markets and will have sufficient capital resources to meet its foreseeable obligations. See the Liquidity and Capital Resources section on page 38 for additional information.

LER focuses on growing its markets on a long-term and sustainable basis by providing both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service area with another choice in non-regulated natural gas suppliers. LER utilizes its natural gas supply agreements, transportation agreements, and other executory contracts to provide a variety of services to its customers at competitive prices. It closely monitors and manages the natural gas commodity price risk associated with providing such services to its customers through the use of exchange-traded/cleared derivative instruments and other contractual arrangements. LER is committed to managing commodity price risk, while it continues to seek new growth opportunities and expand the services that it now provides. Nevertheless, income from LER’s operations is more subject to fluctuations in market conditions than the Utility’s operations. LER’s business is directly impacted by the effects of competition in the marketplace and the impact of new pipeline infrastructure and surplus natural gas supplies on regional natural gas commodity prices.

In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. Many of LER’s physical purchase and sale transactions are recognized in earnings when the natural gas is delivered. However, generally accepted accounting principles (GAAP) require that some of LER’s energy-related transactions be accounted for as derivatives, with the changes in their fair value (representing unrealized gains or losses) recorded in earnings in periods prior to physical delivery. Because related transactions of a purchase and sale strategy may be accounted for differently, there may be timing differences in the recognition of earnings under GAAP and economic earnings realized upon settlement. The Company reports both GAAP and economic earnings, as discussed below.

In addition to its operating cash flows, LER relies on parental guarantees to secure its purchase and sales obligations of natural gas. LER also has access to Laclede Group’s liquidity resources. A large portion of LER’s receivables are from customers in the energy industry. LER also enters into netting arrangements with many of its energy counterparties to reduce overall credit and collateral exposure. Although LER’s uncollectible amounts are closely monitored and have not been significant, increases in uncollectible amounts from customers are possible and could adversely affect LER’s liquidity and results.

LER carefully monitors the creditworthiness of counterparties to its transactions. LER performs in-house credit reviews of potential customers and may require credit assurances such as prepayments, letters of credit, or parental guarantees when appropriate. Credit limits for customers are established and monitored.



EARNINGS

Laclede Group’s consolidated net income for fiscal years 2010, 2009, and 2008 was $54.0 million, $64.2 million, and $77.9 million, respectively. Basic and diluted earnings per share (EPS) were $2.43 for fiscal year 2010 compared with basic and diluted earnings per share of $2.90 and $2.89, respectively, for fiscal year 2009, and $3.57 and $3.56, respectively, for fiscal year 2008. There was no effect from discontinued operations in fiscal years 2010 and 2009. In fiscal year 2008, due to the sale of SM&P, income from discontinued operations totaled $20.4 million, or $0.93 per share.

Laclede Group reports income from continuing operations and earnings per share determined in accordance with GAAP. As Laclede Group’s non-regulated subsidiary, LER, continues to expand its business, the number of transactions accounted for through fair value measurements has increased. As a result, management also uses the non-GAAP measures of net economic earnings and net economic earnings per share when internally evaluating results of operations. Net economic earnings exclude from income from continuing operations the after-tax impacts of net unrealized gains and losses on energy-related derivatives that are required by GAAP fair value accounting. This adjustment eliminates the impact of timing differences related to current changes in the fair value of financial and physical transactions prior to their completion and settlement. Management believes that excluding the earnings volatility caused by recognizing changes in fair value prior to settlement provides a useful representation of the economic impact of only the actual settled transactions and their effects on results of operations. These internal non-GAAP operating metrics should not be considered as an alternative to, or more meaningful than, GAAP measures such as income from continuing operations. While management uses these non-GAAP measures to evaluate both Laclede Gas and LER, the net effect of unrealized gains and losses on the Utility’s earnings is minimal because gains or losses on its natural gas derivative instruments are deferred pursuant to its PGA Clause, as authorized by the MoPSC. These unrealized gains and losses result primarily from two sources:

1)
changes in fair values of physical and/or financial derivatives prior to the period of settlement; and,
2)
ineffective portions of accounting hedges, required to be recorded in earnings prior to settlement, due to differences in commodity price changes between the locations of the forecasted physical purchase or sale transactions and the locations of the underlying hedge instruments.

Unrealized gains or losses are recorded in each period until being replaced with the actual gains or losses realized when the associated physical transaction(s) occur.



Reconciliations of net economic earnings and net economic earnings per share to the Company’s most directly comparable GAAP measures are provided below.

Overview – Income (Loss) from Continuing Operations by Operating Segment

(Millions, except per share amounts)
Net Economic Earnings
(Non-GAAP)
Add: Unrealized gain (loss) on energy-related derivative contracts*
Income from Continuing Operations
(GAAP)
Year Ended September 30, 2010
                       
 
Regulated Gas Distribution
 
$
36.1
   
$
(0.1
)
 
$
36.0
 
 
Non-Regulated Gas Marketing
   
15.7
     
(2.0
)
   
13.7
 
 
Other
   
4.3
     
     
4.3
 
 
     Total
 
$
56.1
   
$
(2.1
)
 
$
54.0
 
 
Per Share Amounts **
 
$
2.52
   
$
(0.09
)
 
$
2.43
 
                           
Year Ended September 30, 2009
                       
 
Regulated Gas Distribution
 
$
33.1
   
$
0.1
   
$
33.2
 
 
Non-Regulated Gas Marketing
   
28.1
     
3.3
     
31.4
 
 
Other
   
(0.4
)
   
     
(0.4
)
 
     Total
 
$
60.8
   
$
3.4
   
$
64.2
 
 
Per Share Amounts **
 
$
2.74
   
$
0.15
   
$
2.89
 
                           
Year Ended September 30, 2008
                       
 
Regulated Gas Distribution
 
$
39.1
   
$
   
$
39.1
 
 
Non-Regulated Gas Marketing
   
20.9
     
(1.6
)
   
19.3
 
 
Other
   
(0.9
)
   
     
(0.9
)
 
     Total
 
$
59.1
   
$
(1.6
)
 
$
57.5
 
 
Per Share Amounts **
 
$
2.70
   
$
(0.07
)
 
$
2.63
 
   
*
Amounts presented net of income taxes. Income taxes are calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of unrealized gain (loss) on energy-related derivative contracts. For the fiscal years ended 2010, 2009 and 2008 the amount of income tax expense (benefit) included in the total reconciling item above is $(1.3) million, $2.2 million, and $(1.0) million, respectively.
   
**
Net economic earnings per share is calculated by replacing consolidated income from continuing operations with consolidated net economic earnings in the GAAP diluted earnings per share calculation.

Laclede Group’s consolidated income from continuing operations was $54.0 million in fiscal year 2010, compared with $64.2 million in fiscal year 2009, and $57.5 million in fiscal year 2008. Net economic earnings were $56.1 million in fiscal year 2010, compared with $60.8 million in fiscal year 2009, and $59.1 million in fiscal year 2008. Earnings decreased in fiscal year 2010 (compared with fiscal year 2009) primarily due to lower income reported by Laclede Group’s Non-Regulated Gas Marketing segment. This decrease was partially offset by increased Other Income, and improved results reported by Laclede Group’s Regulated Gas Distribution segment. Earnings increased in fiscal year 2009 (compared with fiscal year 2008) primarily due to improved results reported by Laclede Group’s Non-Regulated Gas Marketing segment, partially offset by lower earnings reported by Laclede Group’s Regulated Gas Distribution segment.

Basic and diluted earnings per share from continuing operations were $2.43 for fiscal year 2010 compared with basic and diluted earnings per share of $2.90 and $2.89, respectively, for fiscal year 2009, and $2.64 and $2.63, respectively, for fiscal year 2008. Net economic earnings per share were $2.52 in fiscal year 2010, compared with $2.74 in fiscal year 2009, and $2.70 in fiscal year 2008. The year-to-year variations in earnings per share and net economic earnings per share were primarily due to the changes in net income and net economic earnings, respectively, in each period.



2010 vs. 2009

Regulated Gas Distribution income from continuing operations and Regulated Gas Distribution net economic earnings increased by $2.8 million and $3.0 million, respectively, in 2010, compared with 2009. The increase was primarily due to the following factors (quantified on a pre-tax basis):

 
decreases in operation and maintenance expense totaling $5.1 million, including a lower provision for uncollectible accounts totaling $3.4 million;
 
higher Infrastructure System Replacement Surcharge (ISRS) revenues totaling $3.2 million; and,
 
the benefit of the general rate increase, effective September 1, 2010, totaling $2.5 million.

These factors were partially offset by:

 
lower income from off-system sales and capacity release totaling $4.3 million; and,
 
the effect of lower system gas sales volumes and other variations totaling $2.8 million.

The Non-Regulated Gas Marketing segment reported income from continuing operations totaling $13.7 million for fiscal year 2010, a decrease in earnings of $17.7 million compared with fiscal year 2009. Net economic earnings decreased $12.4 million compared with fiscal year 2009. These decreases were primarily due to LER’s significantly reduced margins on sales of natural gas. The reduced sales margins were driven primarily by narrower regional price differentials that have recently prevailed in the marketplace, as compared to the favorable market conditions that existed during fiscal year 2009. On a GAAP basis, the reduced sales margins this year also included the effect of after-tax net unrealized losses from certain of LER’s energy-related derivative contracts, totaling $2.0 million, recognized in earnings during fiscal year 2010, compared with after-tax net unrealized gains, totaling $3.3 million, recognized during fiscal year 2009.

Other income from continuing operations and Other net economic earnings increased by $4.7 million in 2010, compared with 2009. The increase was primarily due to a propane transaction in the wholesale market by Laclede Gas during the quarter ended December 31, 2009. This non-regulated transaction resulted from an inventory exchange that the counterparty settled in cash instead of through a return of inventory.

2009 vs. 2008

Regulated Gas Distribution income from continuing operations and Regulated Gas Distribution net economic earnings decreased by $5.9 million and $6.0 million, respectively, in 2009, compared with 2008. The decrease was primarily due to the following factors (quantified on a pre-tax basis, except for the income tax item):

 
increases in operation and maintenance expenses, excluding the provision for uncollectible accounts, totaling $4.9 million;
 
the effect of lower system gas sales volumes and other variations totaling $2.0 million;
 
the effect of the recognition of previously unrecognized tax benefits and the reversal of related expenses recorded during fiscal year 2008, totaling $1.6 million; and,
 
an increase in depreciation and amortization expense totaling $1.4 million.

These factors were partially offset by higher ISRS revenues totaling $3.8 million.

The Non-Regulated Gas Marketing segment reported income from continuing operations totaling $31.4 million for fiscal year 2009, an increase in earnings of $12.1 million compared with fiscal year 2008. Net economic earnings increased $7.2 million compared with fiscal year 2008. These increased earnings were primarily due to LER’s increased sales volumes primarily attributable to its acquisition of additional firm pipeline transportation capacity prior to the 2008 – 2009 winter. This capacity, along with favorable natural gas costs, supported 49% higher sales volumes and greater margins in fiscal year 2009 as compared with fiscal year 2008. These factors were partially offset by the effect of a benefit from the reversal of certain tax-related expenses totaling $1.3 million during fiscal year 2008. On a GAAP basis, the increased sales margins also included the effect of after-tax net unrealized gains from certain of LER’s energy-derivative contracts, totaling $3.3 million, recognized in earnings during fiscal year 2009, compared with after-tax net unrealized losses, totaling $1.6 million, recognized during fiscal year 2008.



Regulated Gas Distribution Operating Revenues

Laclede Gas passes on to Utility customers (subject to prudence review) increases and decreases in the wholesale cost of natural gas in accordance with its PGA Clause. The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income.

2010 vs. 2009

Regulated Gas Distribution Operating Revenues for fiscal year 2010 decreased $189.7 million compared to fiscal year 2009, primarily due to lower wholesale gas costs. Temperatures experienced in the Utility’s service area during 2010 were 1.6% warmer than the same period last year and 2.5% warmer than normal. Total system therms sold and transported were 894.5 million for fiscal year 2010 compared with 908.0 million for fiscal year 2009. Total off-system therms sold and transported were 71.0 million for fiscal year 2010 compared with 163.0 million for fiscal year 2009. The decrease in Regulated Gas Distribution Operating Revenues was primarily attributable to the following factors:

(Millions)
     
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
 
$
(141.1
)
Lower off-system sales volumes (reflecting less favorable market conditions as described in greater detail in the
  Results of Operations)
   
(42.8
)
Lower system sales volumes and other variations
   
(10.2
)
Higher ISRS revenues
   
3.2
 
General rate increase, effective September 1, 2010
   
2.5
 
Lower prices charged for off-system sales
   
(1.3
)
      Total Variation
 
$
(189.7
)

2009 vs. 2008

Regulated Gas Distribution Operating Revenues for fiscal year 2009 decreased $74.3 million compared to fiscal year 2008, primarily due to lower gas prices charged for off-system sales. Temperatures experienced in the Utility’s service area during 2009 were 1.8% warmer than fiscal year 2008 and 1.5% warmer than normal. Total system therms sold and transported were 908.0 million for fiscal year 2009 compared with 934.6 million for fiscal year 2008. Total off-system therms sold and transported were 163.0 million for fiscal year 2009 compared with 143.7 million for fiscal year 2008. The decrease in Regulated Gas Distribution Operating Revenues was primarily attributable to the following factors:

(Millions)
     
Lower prices charged for off-system sales
 
$
(64.2
)
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
   
(19.0
)
Higher off-system sales volumes (reflecting more favorable market conditions as described in greater
  detail in the Results of Operations)
   
16.6
 
Lower system sales volumes and other variations
   
(11.5
)
Higher ISRS revenues
   
3.8
 
      Total Variation
 
$
(74.3
)



Regulated Gas Distribution Operating Expenses

2010 vs. 2009

Regulated Gas Distribution Operating Expenses in fiscal year 2010 decreased $191.6 million, or 19.6%, from fiscal year 2009. Natural and propane gas expense decreased $180.1 million from last year’s level, primarily attributable to lower rates charged by our suppliers and lower off-system gas expense. Other operation and maintenance expenses decreased $5.1 million, or 2.9%, primarily due to a lower provision for uncollectible accounts, reduced distribution and maintenance expenses, a lower provision for injuries and damages, and decreased charges for outside services. These factors were partially offset by the effect of a gain on the disposal of assets recorded in fiscal year 2009 and an increase in pension expense. Depreciation and amortization expense increased $0.8 million, or 2.2%, primarily due to additional depreciable property. Taxes, other than income taxes, decreased $7.2 million, or 10.5%, primarily due to decreased gross receipts taxes (attributable to the decreased revenues).

2009 vs. 2008

Regulated Gas Distribution Operating Expenses in fiscal year 2009 decreased $65.1 million, or 6.2%, from fiscal year 2008. Natural and propane gas expense decreased $70.1 million from fiscal year 2008, primarily attributable to lower off-system gas expense, decreased rates charged by our suppliers, and lower volumes purchased for sendout. Other operation and maintenance expenses increased $3.9 million, or 2.3%, primarily due to increases in compensation expenses, higher maintenance charges, and increased injuries and damages expense, partially offset by a decrease in distribution charges, a lower provision for uncollectible accounts, and a gain on the disposal of assets in fiscal year 2009. Depreciation and amortization expense increased $1.4 million, or 4.1%, primarily due to additional depreciable property.

Non-Regulated Gas Marketing Operating Revenues and Operating Expenses

Non-Regulated Gas Marketing Operating Revenues increased $21.9 million in fiscal year 2010 from those revenues for fiscal year 2009 primarily due to 2% higher sales volumes and higher per unit gas prices charged by LER. The increase in Non-Regulated Gas Marketing Operating Expenses of $49.6 million was primarily associated with higher prices charged by suppliers and increased volumes purchased.

Non-Regulated Gas Marketing Operating Revenues decreased $239.0 million in fiscal year 2009 from those revenues for fiscal year 2008 primarily due to lower per unit gas sales prices charged by LER, partially offset by 49% higher sales volumes. The decrease in Non-Regulated Gas Marketing Operating Expenses of $261.1 million was primarily associated with lower prices charged by suppliers, partially offset by increased volumes purchased.

Other Operating Revenues and Operating Expenses

Other Operating Revenues increased $7.6 million in fiscal year 2010 (compared to fiscal year 2009) primarily due to a propane transaction in the wholesale market by Laclede Gas during the quarter ended December 31, 2009. This non-regulated transaction resulted from an inventory exchange that the counterparty settled in cash instead of through a return of inventory. The increase in Other Operating Expenses, totaling $2.0 million in fiscal year 2010 (compared to fiscal year 2009), was primarily due to expenses associated with this propane transaction.

Other Income and (Income Deductions)-Net

Other Income and (Income Deductions)-Net increased $1.7 million in fiscal year 2010 (compared to fiscal year 2009), due to higher net investment gains and other minor variations, partially offset by lower income associated with carrying costs applied to under-recoveries of gas costs and lower interest income. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s PGA Clause.

Other Income and (Income Deductions)-Net decreased $0.4 million in fiscal year 2009 (compared to fiscal year 2008), due to lower interest income and the effect of a benefit recognized during fiscal year 2008 from the reversal of certain tax-related expenses. These factors were largely offset by the effect of a loss on the redemption of long-term debt (primarily unamortized issuance costs) recognized during fiscal year 2008 and increased income associated with carrying costs applied to under-recoveries of gas costs.



Interest Charges

The $2.9 million decrease in interest charges in fiscal year 2010 (over fiscal year 2009) was primarily due to lower interest on short-term debt. The $0.3 million increase in interest charges in fiscal year 2009 (over fiscal year 2008) was primarily due to higher interest on long-term debt, primarily attributable to the issuance of $80.0 million principal amount of 6.35% first mortgage bonds on September 23, 2008. This increase was largely offset by lower interest on short-term debt. Average short-term interest rates were 0.3% this year compared with 1.5% in fiscal year 2009 and 4.1% in fiscal year 2008. Average short-term borrowings were $107.9 million, $207.6 million, and $180.7 million for fiscal years 2010, 2009, and 2008, respectively.

Income Taxes

Income tax expense decreased $5.4 million in fiscal year 2010 (from fiscal year 2009) and increased $6.3 million in fiscal year 2009 (over fiscal year 2008). These variations are primarily due to changes in pre-tax income. The variation in 2009 (compared to 2008) also reflects the effect of lower income tax expense in fiscal year 2008 due to the recognition of previously unrecognized tax benefits.

Income from Discontinued Operations

The sale of SM&P on March 31, 2008 resulted in after-tax earnings of $25.4 million, net of associated costs of disposal. Income from Discontinued Operations for fiscal year 2008 was $20.4 million, consisting of the net effect of the sale and SM&P’s seasonal operating loss through the March 31 sale date. Basic and diluted earnings per share from discontinued operations were $0.93 for fiscal year 2008.



Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our consolidated financial statements, which have been prepared in accordance with GAAP. GAAP requires that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. We believe the following represent the more significant items requiring the use of judgment and estimates in preparing our consolidated financial statements:

 
Accounts Receivable and Allowance for Doubtful Accounts – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.

 
Employee Benefits and Postretirement Obligations – Pension and postretirement obligations are calculated by actuarial consultants that utilize several statistical factors and other assumptions provided by management related to future events, such as discount rates, returns on plan assets, compensation increases, and mortality rates. For the Utility, the amount of expense recognized and the amounts reflected in other comprehensive income are dependent upon the regulatory treatment provided for such costs, as discussed further below. Certain liabilities related to group medical benefits and workers’ compensation claims, portions of which are self-insured and/or contain “stop-loss” coverage with third-party insurers to limit exposure, are established based on historical trends.


The table below reflects the sensitivity of Laclede’s plans to potential changes in key assumptions:

Pension Plan Benefits:
                     
                       
           
Estimated
     
Estimated
 
           
Increase/
     
Increase/
 
           
(Decrease) to
     
(Decrease) to
 
           
Projected
     
Annual
 
           
Benefit
     
Net Pension
 
   
Increase/
     
Obligation
     
Cost*
 
Actuarial Assumptions
 
(Decrease)
     
(Thousands)
     
(Thousands)
 
                         
Discount Rate
 
0.25
%
   
$
(9,820
)
 
$
199
 
   
(0.25
)
     
10,120
     
(220
)
                         
Rate of Future Compensation Increase
 
0.25
%
     
6,400
     
380
 
   
(0.25
)
     
(6,300
)
   
(370
)
                         
Expected Return on Plan Assets
 
0.25
%
     
     
(610
)
   
(0.25
)
     
     
610
 
                         
Postretirement Benefits:
                       
                         
             
Estimated
     
Estimated
 
             
Increase/
     
Increase/
 
             
(Decrease) to
     
(Decrease) to
 
             
Projected
     
Annual Net
 
             
Postretirement
     
Postretirement
 
             
Benefit
     
Benefit
 
   
Increase/ 
       
Obligation
     
Cost*
 
Actuarial Assumptions
 
(Decrease)
       
(Thousands)
     
(Thousands)
 
                         
Discount Rate
 
0.25
%
   
$
(2,320
)
 
$
(116
)
   
(0.25
)
     
2,380
     
114
 
                         
Expected Return on Plan Assets
 
0.25
%
     
     
(100
)
   
(0.25
)
     
     
100
 
                         
Annual Medical Cost Trend
 
1.00
%
     
5,850
     
1,270
 
   
(1.00
)
     
(5,300
)
   
(1,130
)
                         
* Excludes the impact of regulatory deferral mechanism. See Note 3 , Pension Plans and Other Postretirement Benefits, of the Notes to Consolidated Financial Statements for information regarding the regulatory treatment of these costs.



Regulated Operations Laclede Gas accounts for its regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. Management believes the following represent the more significant items recorded through the application of this accounting guidance:

 
The Utility’s PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including the costs, cost reductions, and related carrying costs associated with the Utility’s use of natural gas derivative instruments to hedge the purchase price of natural gas. The difference between actual costs incurred and costs recovered through the application of the PGA are recorded as regulatory assets and regulatory liabilities that are recovered or refunded in a subsequent period. The PGA Clause also authorizes the Utility to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The PGA Clause also permits the application of carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments. The PGA Clause also provides for a portion of income from off-system sales and capacity release revenues to be flowed through to customers.
   
 
The Company records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes, and the amounts used for income tax purposes. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or regulatory liability accounts for regulated companies, and will be reflected as income or loss for non-regulated companies. Pursuant to the direction of the MoPSC, Laclede Gas’ provision for income tax expense for financial reporting purposes reflects an open-ended method of tax depreciation. Laclede Gas’ provision for income tax expense also records the income tax effect associated with the difference between overheads capitalized to construction for financial reporting purposes and those recognized for tax purposes without recording an offsetting deferred income tax expense. These two methods are consistent with the regulatory treatment prescribed by the MoPSC.
   
 
Asset retirement obligations are recorded in accordance with GAAP using various assumptions related to the timing, method of settlement, inflation, and profit margins that third parties would demand to settle the future obligations. These assumptions require the use of judgment and estimates and may change in future periods as circumstances dictate. As authorized by the MoPSC, Laclede Gas accrues future removal costs associated with its property, plant and equipment through its depreciation rates, even if a legal obligation does not exist as defined by GAAP. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognizable pursuant to GAAP is a timing difference between the recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities.




 
The amount of net periodic pension and other postretirement benefit cost recognized in the financial statements related to the Utility’s qualified pension plans and other postretirement benefit plans is based upon allowances, as approved by the MoPSC, which have been established in the rate-making process for the recovery of these costs from customers. The differences between these amounts and actual pension and other postretirement benefit costs incurred for financial reporting purposes are deferred as regulatory assets or regulatory liabilities. GAAP also requires that changes that affect the funded status of pension and other postretirement benefit plans, but that are not yet required to be recognized as components of pension and other postretirement benefit cost, be reflected in other comprehensive income. For the Utility’s qualified pension plans and other postretirement benefit plans, amounts that would otherwise be reflected in other comprehensive income are deferred with entries to regulatory assets or regulatory liabilities.

Non-Regulated Gas Marketing Energy Contracts – LER routinely enters into contracts for the physical purchase or sale of natural gas in a future period. In determining the appropriate accounting treatment for these contracts, management is required to assess the contract terms and various other factors to determine if the contracts are subject to the derivative accounting guidance in ASC Topic 815, “Derivatives and Hedging.” If a contract is deemed to meet the definition of derivative, management’s judgment is further required in determining if the contract is eligible for the normal purchases or normal sales election, which, if elected, permits the Company to account for the contract in the period the natural gas is delivered. To the extent LER’s contracts qualify for the normal purchases or normal sales election under GAAP, the election is generally taken. Many of LER’s contracts are accounted for in this manner. However, pursuant to GAAP, certain contracts do not qualify for this election and are required to be accounted for as derivatives with changes in fair value (representing unrealized gains or losses) recognized in earnings in the periods prior to physical delivery. Unrealized gains or losses on these contracts are recognized as either Non-Regulated Gas Marketing operating revenues or Non-Regulated Gas Marketing operating expenses in the Statements of Consolidated Income. In the absence of quoted prices in active markets for identical assets or liabilities, determining the fair value of a derivative contract requires judgment as to the appropriateness of various market inputs and involves making assumptions regarding how market participants would price the asset or liability. In addition to these physical contracts, LER also utilizes natural gas futures and swap contracts traded on or cleared through the New York Mercantile Exchange (NYMEX) to manage the price risk associated with certain of its fixed-price commitments. These contracts are generally designated for hedge accounting treatment, as discussed in Note 11 of the Notes to Consolidated Financial Statements.

For further discussion of significant accounting policies, see Note 1 of the Notes to Consolidated Financial Statements included on page 55.



There have been several significant regulatory developments affecting Laclede Gas.

During fiscal year 2006, the MoPSC approved permanent modifications to the Cold Weather Rule affecting the disconnection and reconnection practices of utilities during the winter heating season. Those modifications included provisions to allow the Utility to obtain accounting authorizations and defer for future recovery certain costs incurred with the modifications. During fiscal year 2007, the Utility deferred for future recovery $2.7 million of costs associated with the fiscal year 2007 heating season. In 2008, the Utility and the MoPSC Staff filed a Non-Unanimous Stipulation & Agreement in which these parties agreed to a recovery of $2.5 million of costs, which Public Counsel opposed. The Commission approved the $2.5 million cost recovery recommended by the Utility and the MoPSC Staff, which Public Counsel appealed to the Cole County, Missouri Circuit Court. In 2009, the Court affirmed the Commission’s Order and Public Counsel appealed to the Court of Appeals for the Western District of Missouri. On December 22, 2009, the Court of Appeals also issued a judgment affirming the Commission’s Order. On January 5, 2010, Public Counsel sought rehearing of the decision or transfer to the Missouri Supreme Court. The Court subsequently denied this request.



On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, LER. The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. On December 31, 2009, the MoPSC Staff proposed a number of non-monetary recommendations only, based on its review of gas costs for fiscal year 2008. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.

In its December 31, 2007 recommendation relating to fiscal year 2006 gas costs, the MoPSC Staff also raised questions regarding whether certain sales and capacity release transactions subject to the Federal Energy Regulatory Commission (FERC)’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Company commenced an internal review of the questions raised by the MoPSC Staff and notified the FERC Staff that it took this action. In June 2008, as a result of the internal review, the Company provided the FERC Staff with a self report regarding compliance of sales and capacity release activities with the FERC’s regulations and policies. On February 9, 2010, the FERC Staff informed the Company that it has closed its investigation of the Company’s self report without taking further action.

In connection with the affiliate transaction matters mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order approving a 2001 Stipulation and Agreement that permitted the Company’s corporate reorganization into a holding company structure. Also, on October 6, 2010, the MoPSC Staff filed a related complaint against Laclede Gas alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. Laclede Gas believes that neither of the complaints have merit and intends to vigorously oppose both of them. In addition, the Company had filed a counterclaim against the MoPSC Staff in the July 7 complaint case alleging that the Staff has failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and the provisions under which the Company allocates costs among affiliated companies. However, on November 3, 2010, the MoPSC issued an order dismissing the Utility’s counterclaim for failure to state a claim upon which relief may be granted.

On July 9, 2008, Laclede Gas made a tariff filing with the MoPSC that would make the payment provisions for the restoration of gas service under the Utility’s Cold Weather Rule available to customers in the summer of 2008 and enable the Utility to increase or decrease its PGA rates to correct for any shortfall or surplus created by the difference between the gas cost portion of the Utility’s actual net bad debt write-offs and the amount of such cost that is embedded in its existing rates. As a result of the ensuing procedural schedule, the Cold Weather Rule portion of the filing became moot. On April 15, 2009, the Commission rejected the Utility’s tariffs on the grounds that it did not have the legal authority to approve them, of which Laclede Gas sought judicial review. On January 11, 2010, the Court found that the Commission did have the legal authority to approve such tariffs, which decision the Commission appealed to the Missouri Court of Appeals, Western District. On October 19, 2010, the Western District overruled the Cole County Circuit Court’s decision and affirmed the Commission’s April 15, 2009 Order. Laclede Gas has filed with the Western District a motion for rehearing and an application to transfer the case to the Missouri Supreme Court.

On December 4, 2009, Laclede Gas filed tariff sheets in a new general rate case proceeding designed to increase revenues by approximately $52.6 million annually, or 6.9%. On July 23, 2010 and August 3, 2010, the Utility and the other parties to the proceeding filed Stipulation and Agreements that comprised a settlement of all matters and provided for a net $20.5 million increase in annual revenues, reflecting an annual increase of $31.4 million in base rates minus $10.9 million that was being billed to customers through the ISRS. The settlement also retained the Utility’s weather mitigation rate design and provided for the funding of various low-income, weatherization, and conservation and energy efficiency programs. On August 18, 2010, the MoPSC approved the settlement, which became effective September 1, 2010.

On January 15, 2010, the Utility made an ISRS filing with the Commission designed to increase revenues by $3.2 million annually, $2.8 million of which the MoPSC approved effective March 31, 2010. These surcharges were reset to zero effective September 1, 2010, as the ISRS-related costs are being recovered through new base rates effective on that same date. On October 29, 2010, the Utility made an ISRS filing with the Commission designed to increase revenues $2.6 million annually, pending approval by the Commission.



On June 29, 2010, the Office of Federal Contract Compliance Programs issued a Notice of Violations to Laclede Gas alleging lapses in certain employment selection procedures during a two-year period ending in February 2006. The Company believes that the allegations lack merit and is vigorously defending its position. While the results of the claims cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the consolidated financial position and results of operations of the Company.


ACCOUNTING PRONOUNCEMENTS

The Company has evaluated or is in the process of evaluating the impact that recently issued accounting standards will have on the Company’s financial position or results of operations upon adoption. For disclosures related to the adoption of new accounting standards, see the New Accounting Standards section of Note 1 of the Notes to Consolidated Financial Statements.


INFLATION

The accompanying consolidated financial statements reflect the historical costs of events and transactions, regardless of the purchasing power of the dollar at the time. Due to the capital-intensive nature of the business of Laclede Gas, the most significant impact of inflation is on the depreciation of utility plant. Rate regulation, to which Laclede Gas is subject, allows recovery through its rates of only the historical cost of utility plant as depreciation. While no plans exist to undertake replacements of plant in service other than normal replacements and those under existing replacement programs, Laclede Gas believes that any higher costs experienced upon replacement of existing facilities would be recovered through the normal regulatory process.


FINANCIAL CONDITION


CASH FLOWS

The Company’s short-term borrowing requirements typically peak during colder months when Laclede Gas borrows money to cover the lag between when it purchases its natural gas and when its customers pay for that gas. Changes in the wholesale cost of natural gas (including cash payments for margin deposits associated with the Utility’s use of natural gas derivative instruments), variations in the timing of collections of gas cost under the Utility’s PGA Clause, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year and from year to year, and can cause significant variations in the Utility’s cash provided by or used in operating activities.

Net cash provided by operating activities for fiscal years 2010 and 2009 was $106.9 million and $228.8 million, respectively. Net cash used in operating activities for fiscal year 2008 was $36.5 million. The decrease in net cash provided by operating activities in fiscal year 2010 (compared to fiscal year 2009) is primarily attributable to increased payments for natural gas storage inventories this year. The improvement in cash flows provided by operating activities in fiscal year 2009 (over fiscal year 2008) was primarily attributable to reduced payments for natural gas storage inventories, other variations in the timing of the collection of gas costs under the PGA Clause, and reduced cash paid for income taxes.

Net cash used in investing activities for fiscal years 2010 and 2009 was $60.8 million and $52.3 million, respectively. Net cash provided by investing activities for fiscal year 2008 was $26.9 million. Net cash used in investing activities in fiscal years 2010 and 2009 primarily reflected capital expenditures. Net cash provided by investing activities in fiscal year 2008 is primarily attributable to the proceeds from the sale of SM&P, partially offset by capital expenditures.

Net cash used in financing activities for fiscal years 2010, 2009, and 2008 was $33.8 million, $116.8 million, and $28.3 million, respectively. The variation in net cash used in financing activities in fiscal year 2010 (over fiscal year 2009) primarily reflects a reduction in repayments of short-term debt this year. The variation in net cash used in financing activities in fiscal year 2009 (over fiscal year 2008) primarily reflects an increase in the repayments of short-term debt, partially offset by the net effect of changes in long-term debt during fiscal year 2008, including the redemption of the Company’s long-term debt to an unconsolidated affiliate trust. The Company used a portion of the proceeds from the aforementioned sale of SM&P to fund the redemption of the long-term debt to the unconsolidated affiliate trust.




LIQUIDITY AND CAPITAL RESOURCES

Short-term Investments

Laclede Group had short-term investments totaling $76.0 million at September 30, 2010, earning an average interest rate of 0.3%. These investments, which are presented as cash and cash equivalents on the Consolidated Balance Sheets, were diversified among several money market funds and interest-bearing deposits at highly-rated commercial banks. The money market funds are accessible by the Company on demand. The bank deposits are also generally available on demand, though the banks reserve the right to require seven days’ notice for a withdrawal. These funds are used to support the working capital needs of the Company’s subsidiaries. The balance of short-term investments ranged between $60.1 million and $106.4 million during the fiscal year.

Short-term Debt

As indicated in the discussion of cash flows above, the Company’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. Laclede Gas has a syndicated line of credit in place of $320 million from 10 banks, with the largest portion provided by a single bank being 17.5%. This line expires in December 2011. During fiscal year 2010, Laclede Gas utilized only commercial paper for external short-term funding. Commercial paper borrowings ranged between $48.2 million and $178.0 million during the fiscal year, and stood at $129.7 million on September 30, 2010. The weighted average interest rate on the short-term borrowings was 0.3% per annum at September 30, 2010. For the entire fiscal year, short-term borrowings averaged $107.9 million at an average interest rate of 0.3%. Based on average short-term borrowings for the year, an increase in the average interest rate of 100 basis points would decrease pre-tax earnings and cash flows of Laclede Group by approximately $1.1 million on an annual basis. Portions of such increases or decreases may be offset through the application of PGA carrying costs. Laclede Gas borrowed a maximum of $1.2 million from Laclede Group during the fiscal year, and there were no such borrowings outstanding at the end of the fiscal year.

Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation and amortization (EBITDA) to be at least 2.25 times interest expense. On September 30, 2010, total debt was 56% of total capitalization . For the fiscal year ended September 30, 2010, EBITDA was 4.55 times interest expense.

Short-term cash requirements outside of Laclede Gas have generally been met with internally-generated funds. However, Laclede Group has $50 million in working capital lines of credit which expire in September 2011, to meet short-term liquidity needs of its subsidiaries. These lines of credit have covenants limiting the total debt of the consolidated Laclede Group to no more than 70% of the Company’s total capitalization. This ratio stood at 49% on September 30, 2010. These lines have been used to provide for seasonal funding needs of various subsidiaries from time to time. There were no borrowings under Laclede Group’s lines during the fiscal year.

Long-term Debt, Equity, and Shelf Registrations

Laclede Gas has on file with the Securities and Exchange Commission (SEC) an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, which expires May 28, 2013. The entire amount of this shelf registration remains available to Laclede Gas at this time.

The Utility has MoPSC authority to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock receive paid-in capital, and enter into capital lease agreements, all for a total of up to $518 million, effective from June 30, 2010 through June 30, 2013. During fiscal year 2010, pursuant to this and previous authorities, the Utility sold 40 shares of its common stock to Laclede Group for $1.4 million. For more information on these sales of stock, see Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities. As of November 19, 2010, $517.6 million remains available under this authorization. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions, as well as future MoPSC authorizations.



At September 30, 2010, Laclede Gas had fixed-rate long-term debt totaling $390 million (including current maturities). On November 15, 2010, Laclede Gas paid at maturity $25 million principal amount of 6 1/2% first mortgage bonds. This maturity was funded through short-term borrowings. While the remaining long-term debt issues are fixed-rate, they are subject to changes in their fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period. Of the Utility’s $390 million in long-term debt, $75 million have no call option, $235 million have make-whole call options, and $80 million are callable at par in 2013. None of the debt has any put options.

Laclede Group has on file a shelf registration on form S-3 with the SEC that allows for the issuance of equity securities and debt securities. No securities have been issued under this registration statement, which expires November 26, 2011. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions. In addition, Laclede Group has a registration statement on file on From S-3 for the issuance and sale of up to 400,000 shares of its common stock under its Dividend Reinvestment and Stock Purchase Program. There were 327,781 shares and 317,186 shares at September 30, 2010 and November 19, 2010, respectively, remaining available for issuance under this Form S-3.

Guarantees

Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends into 2015. At September 30, 2010, the maximum guarantees under these leases were $1.3 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At September 30, 2010, the carrying value of the liability recognized for these guarantees was $0.3 million.

Laclede Group had guarantees totaling $105.3 million for performance and payment of certain wholesale gas supply purchases by LER, as of September 30, 2010. Since that date, total guarantees issued by Laclede Group on behalf of LER increased by $2.3 million bringing the total to $107.6 million in guarantees outstanding at November 19, 2010. No amounts have been recorded for these guarantees in the financial statements.

Other

The Company’s and the Utility’s access to capital markets, including the commercial paper market, and their respective financing costs, may depend on the credit rating of the entity that is accessing the capital markets. These ratings, which are indicated below, were unchanged over the past fiscal year, but remain subject to review and change by the rating agencies.

Type of Facility
S&P
Moody’s
Fitch
Laclede Group Issuer Rating
A
 
A-
Laclede Gas First Mortgage Bonds
A
A2
A+
Laclede Gas Commercial Paper
A-1
P-2
F1

Utility capital expenditures were $56.2 million in fiscal year 2010, compared with $51.4 million and $55.3 million for fiscal years 2009 and 2008, respectively. Utility capital expenditures are expected to be approximately $64 million in fiscal year 2011. The increase in capital expenditures expected for fiscal year 2011, compared with prior periods, is primarily attributable to anticipated additional expenditures for distribution plant, as well as other planned improvements to the Utility’s natural gas storage facilities and general plant purchases. Non-utility capital expenditures for fiscal year 2010 were $0.8 million compared with $1.0 million in fiscal year 2009 and $1.3 million in fiscal year 2008, and are estimated to be approximately $0.6 million in fiscal year 2011.

Consolidated capitalization at September 30, 2010 consisted of 59.5% Laclede Group common stock equity and 40.5% Laclede Gas long-term debt.



Laclede Group’s ratio of earnings (from continuing operations) to fixed charges was 3.8 for fiscal year 2010, 4.1 for fiscal year 2009, and 3.7 for fiscal year 2008.

It is management’s view that the Company has adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements, which primarily include capital expenditures, scheduled maturities of long-term debt, short-term seasonal needs, and dividends.


CONTRACTUAL OBLIGATIONS

As of September 30, 2010, Laclede Group had contractual obligations with payments due as summarized
below (in millions):

   
Payments due by period
 
       
Less than
 
1-3
 
3-5
 
More than
 
Contractual Obligations
 
Total
 
1 Year
 
Years
 
Years
 
5 Years
 
Principal Payments on Long-Term Debt
 
$
390.0
 
$
25.0
 
$
25.0
 
$
 
$
340.0
 
Interest Payments on Long-Term Debt
   
484.9
   
23.8
   
45.1
   
42.7
   
373.3
 
Operating Leases (a)
   
15.3
   
5.1
   
7.0
   
3.2
   
 
Purchase Obligations – Natural Gas (b)
   
908.0
   
494.7
   
372.2
   
26.7
   
14.4
 
Purchase Obligations – Other (c)
   
89.8
   
17.8
   
18.4
   
16.7
   
36.9
 
Total (d)
 
$
1,888.0
 
$
566.4
 
$
467.7
 
$
89.3
 
$
764.6
 

(a)
Operating lease obligations are primarily for office space, vehicles, and power operated equipment in the Regulated Gas Distribution segment. Additional payments will be incurred if renewal options are exercised under the provisions of certain agreements.
(b)
These purchase obligations represent the minimum payments required under existing natural gas transportation and storage contracts and natural gas supply agreements in the Regulated Gas Distribution and Non-Regulated Gas Marketing segments. These amounts reflect fixed obligations as well as obligations to purchase natural gas at future market prices, calculated using September 30, 2010 forward market prices. Laclede Gas recovers the costs related to its purchases, transportation, and storage of natural gas through the operation of its PGA Clause, subject to prudence review by the MoPSC; however, variations in the timing of collections of gas costs from customers affect short-term cash requirements. Additional contractual commitments are generally entered into prior to or during the heating season.
(c)
These purchase obligations reflect miscellaneous agreements for the purchase of materials and the procurement of services necessary for normal operations.
(d)
The categories of Capital Leases and Other Long-Term Liabilities have been excluded from the table above because there are no material amounts of contractual obligations under these categories. Long-term liabilities associated with unrecognized tax benefits, totaling $6.4 million, have been excluded from the table above because the timing of future cash outflows, if any, cannot be reasonably estimated. Also, commitments related to pension and postretirement benefit plans have been excluded from the table above. The Company expects to make contributions to its qualified, trusteed pension plans totaling $10.6 million in fiscal year 2011. Laclede Gas anticipates a $2.4 million contribution relative to its non-qualified pension plans during fiscal year 2011. With regard to the postretirement benefits, the Company anticipates Laclede Gas will contribute $13.3 million to the qualified trusts and $0.3 million directly to participants from Laclede Gas’ funds during fiscal year 2011. For further discussion of the Company’s pension and postretirement benefit plans, refer to Note 3 , Pension Plans and Other Postretirement Benefits, of the Notes to Consolidated Financial Statements.


MARKET RISK

Commodity Price Risk

Laclede Gas’ commodity price risk, which arises from market fluctuations in the price of natural gas, is primarily managed through the operation of its PGA Clause. The PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies. The Utility is allowed the flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months. The Utility is able to mitigate, to some extent, changes in commodity prices through the use of physical storage supplies and regional supply diversity. Laclede Gas also has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing its price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. However, the timing of recovery for cash payments related to margin requirements may cause short-term cash requirements to vary. Nevertheless, carrying costs associated with such requirements, as well as other variations in the timing of collections of gas costs, are recovered through the PGA Clause. For more information about the Utility’s natural gas derivative instruments, see Note 11 , Derivative Instruments and Hedging Activities, of the Notes to Consolidated Financial Statements.

In the course of its business, Laclede Group’s non-regulated gas marketing subsidiary, LER, enters into contracts to purchase and sell natural gas at fixed prices and natural gas index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed price commitments. Pursuant to this risk management policy, LER manages the price risk associated with its fixed-price commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed-prices or through the use of natural gas futures and swap contracts traded on or cleared through the NYMEX to lock in margins. At September 30, 2010 and 2009, LER’s unmatched fixed-price positions were not material to Laclede Group’s financial position or results of operations.

As mentioned above, LER uses natural gas futures and swap contracts traded on or cleared through the NYMEX to manage the commodity price risk associated with its fixed-price natural gas purchase and sale commitments. These derivative instruments are generally designated as cash flow hedges of forecasted purchases or sales. Such accounting treatment generally permits a substantial portion of the gain or loss to be deferred from recognition in earnings until the period that the associated forecasted purchase or sale is recognized in earnings. To the extent a hedge is effective, gains or losses on the derivatives will be offset by changes in the value of the hedged forecasted transactions. Accordingly, the Company does not expect any material adverse earnings impact associated with the use of these instruments. Information about the fair values of LER’s exchange-traded/cleared natural gas derivative instruments is presented below:

(Thousands)
 
Derivative
Fair
Values
 
Cash
Margin
 
Derivatives
and Cash
Margin
 
                     
Net balance of derivative assets at September 30, 2009
 
$
1,807
 
$
960
 
$
2,767
 
Changes in fair value
   
3,568
   
   
3,568
 
Settlements
   
(15,337
)
 
   
(15,337
)
Changes in cash margin
   
   
10,608
   
10,608
 
Net balance of derivative assets (liabilities) at September 30, 2010
 
$
(9,962
)
$
11,568
 
$
1,606
 

(Thousands)
 
At September 30, 2010
 
   
Maturity by Fiscal Year
 
     
Total
   
2011
   
2012
   
2013
 
Fair values of exchange-traded/cleared natural gas derivatives - net
 
$
(9,962
)
$
(6,531
)
$
(3,418
)
$
(13
)
                           
MMBtu – net long futures/swap positions
   
4,550
   
2,310
   
2,180
   
60
 




Many of LER’s physical natural gas derivative contracts are designated as normal purchases or normal sales, as permitted by GAAP. This election permits the Company to account for the contract in the period the natural gas is delivered. However, certain contracts do not qualify for this election under GAAP and are required to be accounted for as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. Below is a reconciliation of the beginning and ending balances for physical natural gas contracts accounted for as derivatives, none of which will settle beyond fiscal year 2011:

(Thousands)
     
         
Net balance of derivative assets at September 30, 2009
 
$
1,066
 
Changes in fair value
   
834
 
Settlements
   
(1,732
)
Net balance of derivative assets at September 30, 2010
 
$
168
 

For further details related to LER’s derivatives and hedging activities, see Note 11 , Derivative Instruments and Hedging Activities, of the Notes to Consolidated Financial Statements.

Counterparty Credit Risk

LER has concentrations of counterparty credit risk in that a significant portion of its transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. LER also has concentrations of credit risk with certain individually significant counterparties. To the extent possible, LER enters into netting arrangements with its counterparties to mitigate exposure to credit risk. Although not recorded on the consolidated balance sheets, LER is also exposed to credit risk associated with its derivative contracts designated as normal purchases and normal sales. LER closely monitors its credit exposure and, although uncollectible amounts have not been significant, increased counterparty defaults are possible and may result in financial losses and/or capital limitations. For more information on these concentrations of credit risk, including how LER manages these risks, see Note 12 , Concentrations of Credit Risk, of the Notes to Consolidated Financial Statements.

Interest Rate Risk

The Company is subject to interest rate risk associated with its long-term and short-term debt issuances. In fiscal year 2010, an increase of 100 basis points in the underlying average interest rate for short-term debt would have caused an increase in interest expense of approximately $1.1 million. Portions of such increases may be offset through the application of PGA carrying costs. At September 30, 2010, Laclede Gas had fixed-rate long-term debt, including current obligations, totaling $390 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period.


ENVIRONMENTAL MATTERS

Laclede Gas owns and operates natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. For information relative to environmental matters, see Note 16 , Commitments and Contingencies, of the Notes to Consolidated Financial Statements.




OFF-BALANCE SHEET ARRANGEMENTS

Laclede Group has no off-balance sheet arrangements.


Laclede Gas Company’s Management’s Discussion and Analysis of Financial Condition and Results of Operations is included in Exhibit 99.1 of this report.


Item 7A . Quantitative and Qualitative Disclosures About Market Risk

For this discussion, see Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk , on page 41 of this report.



Item 8 . Financial Statements and Supplementary Data
 
     
2010 10-K Page
       
   
   
       
   
Financial Statements:
 
       
   
The Laclede Group, Inc.:
 
   
For Years Ended September 30, 2010, 2009, and 2008:
 
   
   
   
   
   
As of September 30, 2010 and 2009:
 
   
   
   
Notes to Consolidated Financial Statements:
 
   
   
   
   
   
   
   
   
   
   
   
   
   
   
   
   
   







Management Report on Internal Control Over Financial Reporting

Management is responsible for establishing and maintaining adequate internal controls over financial reporting. The Company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements and can provide only reasonable assurance with respect to financial statement preparation and presentation. Also, projections of any evaluation of effectiveness to future periods are subject to the risks that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

The Company’s management, including our Chief Executive Officer and Chief Financial Officer, conducted an assessment of the effectiveness of the Company’s internal control over financial reporting as of September 30, 2010. In making this assessment, management used the criteria in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on that assessment, management concluded that the Company’s internal control over financial reporting was effective as of September 30, 2010. Deloitte & Touche LLP, an independent registered public accounting firm, has issued an attestation report on the Company’s internal control over financial reporting, which is included herein.
















REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of
The Laclede Group, Inc.
St. Louis, Missouri

We have audited the internal control over financial reporting of The Laclede Group, Inc. and subsidiaries (the “Company”) as of September 30, 2010, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of September 30, 2010, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements and financial statement schedule as of and for the year ended September 30, 2010 of the Company and our report dated November 19, 2010 expressed an unqualified opinion on those financial statements and financial statement schedule.


/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010



REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Board of Directors and Shareholders of
The Laclede Group, Inc.
St. Louis, Missouri
 
We have audited the accompanying consolidated balance sheets and statements of consolidated capitalization of The Laclede Group, Inc. and subsidiaries (the “Company”) as of September 30, 2010 and 2009, and the related consolidated statements of income, common shareholders’ equity, comprehensive income, and cash flows for each of the three years in the period ended September 30, 2010. Our audits also included the financial statement schedule listed in the Index at Item 15. These consolidated financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on the consolidated financial statements and financial statement schedule based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). 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 Laclede Group, Inc. and subsidiaries as of September 30, 2010 and 2009, and the results of their operations and cash flows for each of the three years in the period ended September 30, 2010, 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, presents fairly, in all material respects, the information set forth therein.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of September 30, 2010, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated November 19, 2010 expressed an unqualified opinion on the Company’s internal control over financial reporting.
 
 
/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010



THE LACLEDE GROUP, INC.
                         
                         
                           
(Thousand, Except Per Share Amounts)
                         
Years Ended September 30
     
2010
     
2009
     
2008
 
                                 
Operating Revenues:
                               
  Regulated Gas Distribution
     
$
864,297
     
$
1,053,993
     
$
1,128,287
 
  Non-Regulated Gas Marketing
       
858,782
       
836,865
       
1,075,845
 
  Other
       
11,950
       
4,340
       
4,841
 
          Total Operating Revenues
       
1,735,029
       
1,895,198
       
2,208,973
 
Operating Expenses:
                               
  Regulated Gas Distribution
                               
    Natural and propane gas
       
519,905
       
699,984
       
770,097
 
    Other operation expenses
       
141,995
       
146,542
       
144,611
 
    Maintenance
       
27,244
       
27,818
       
25,827
 
    Depreciation and amortization
       
37,572
       
36,751
       
35,303
 
    Taxes, other than income taxes
       
61,407
       
68,639
       
69,023
 
          Total Regulated Gas Distribution Operating Expenses
       
788,123
       
979,734
       
1,044,861
 
  Non-Regulated Gas Marketing
       
836,687
       
787,056
       
1,048,162
 
  Other
       
5,353
       
3,344
       
4,603
 
          Total Operating Expenses
       
1,630,163
       
1,770,134
       
2,097,626
 
Operating Income
       
104,866
       
125,064
       
111,347
 
Other Income and (Income Deductions) – Net
       
3,120
       
1,453
       
1,881
 
Interest Charges:
                               
    Interest on long-term debt
       
24,583
       
24,583
       
19,851
 
    Interest on long-term debt to unconsolidated affiliate trust
       
       
       
486
 
    Other interest charges
       
2,269
       
5,163
       
9,140
 
          Total Interest Charges
       
26,852
       
29,746
       
29,477
 
Income from Continuing Operations Before Income Taxes
                               
  and Dividends on Laclede Gas Redeemable Preferred Stock
       
81,134
       
96,771
       
83,751
 
Income Tax Expense
       
27,094
       
32,509
       
26,190
 
Dividends on Laclede Gas Redeemable Preferred Stock
       
       
15
       
35
 
Income from Continuing Operations
       
54,040
       
64,247
       
57,526
 
Income from Discontinued Operations, Net of Income Tax ( Note 2 )
       
       
       
20,396
 
Net Income
     
$
54,040
     
$
64,247
     
$
77,922
 
                                 
Average Number of Common Shares Outstanding:
                               
  Basic
       
21,986
       
21,893
       
21,657
 
  Diluted
       
22,039
       
21,960
       
21,730
 
                                 
Basic Earnings Per Share of Common Stock:
                               
  Income from Continuing Operations
     
$
2.43
     
$
2.90
     
$
2.64
 
  Income from Discontinued Operations
       
       
       
0.93
 
  Net Income
     
$
2.43
     
$
2.90
     
$
3.57
 
                                 
Diluted Earnings Per Share of Common Stock:
                               
  Income from Continuing Operations
     
$
2.43
     
$
2.89
     
$
2.63
 
  Income from Discontinued Operations
       
       
       
0.93
 
  Net Income
     
$
2.43
     
$
2.89
     
$
3.56
 
                                 
                                 
                                 
                     




THE LACLEDE GROUP, INC.
                         
                 
                           
(Thousands)
                         
Years Ended September 30
     
2010
     
2009
     
2008
 
                                 
Net Income
     
$
54,040
     
$
64,247
     
$
77,922
 
Other Comprehensive Income (Loss), Before Tax:
                               
  Net gains (losses) on cash flow hedging derivative instruments:
                               
    Net hedging gain arising during the period
       
5,259
       
6,019
       
8,091
 
    Reclassification adjustment for gains included in net income
       
(13,045
)
     
(15,270
)
     
(3,814
)
        Net unrealized (losses) gains on cash flow hedging
                               
          derivative instruments
       
(7,786
)
     
(9,251
)
     
4,277
 
  Defined benefit pension and other postretirement benefit plans:
                               
    Net actuarial loss arising during the period
       
(1,783
)
     
(1,728
)
     
(271
)
    Amortization of actuarial loss included in net periodic pension and
                               
      postretirement benefit cost
       
1,471
       
199
       
171
 
        Net defined benefit pension and other postretirement benefit plans
       
(312
)
     
(1,529
)
     
(100
)
Other Comprehensive (Loss) Income, Before Tax
       
(8,098
)
     
(10,780
)
     
4,177
 
Income Tax (Benefit) Expense Related to Items
                               
  of Other Comprehensive Income (Loss)
       
(3,127
)
     
(4,146
)
     
1,597
 
Other Comprehensive (Loss) Income, Net of Tax
       
(4,971
)
     
(6,634
)
     
2,580
 
Comprehensive Income
     
$
49,069
     
$
57,613
     
$
80,502
 
                                 
                                 
                           
                         








THE LACLEDE GROUP, INC.
                 
                 
                   
(Thousands)
                 
September 30
     
2010
     
2009
 
                       
ASSETS
                     
Utility Plant
     
$
1,326,284
     
$
1,280,238
 
  Less – Accumulated depreciation and amortization
       
442,200
       
424,309
 
          Net Utility Plant
       
884,084
       
855,929
 
                       
Non-utility property (net of accumulated depreciation and
                     
  amortization, 2010, $3,864; 2009, $3,508)
       
4,551
       
4,061
 
Other investments
       
50,226
       
44,973
 
          Other Property and Investments
       
54,777
       
49,034
 
                       
Current Assets:
                     
  Cash and cash equivalents
       
86,919
       
74,591
 
  Accounts receivable:
                     
    Utility
       
70,053
       
81,262
 
    Non-utility
       
56,160
       
42,382
 
    Other
       
11,671
       
7,511
 
    Allowance for doubtful accounts
       
(10,295
)
     
(11,160
)
  Inventories:
                     
    Natural gas stored underground at LIFO cost
       
113,576
       
93,313
 
    Propane gas at FIFO cost
       
15,625
       
19,847
 
    Materials, supplies, and merchandise at average cost
       
3,867
       
4,158
 
  Natural gas receivable
       
22,963
       
28,344
 
  Derivative instrument assets
       
10,285
       
17,178
 
  Unamortized purchased gas adjustments
       
23,718
       
 
  Deferred income taxes
       
       
1,707
 
  Prepayments and other
       
9,653
       
9,650
 
          Total Current Assets
       
414,195
       
368,783
 
                       
Deferred Charges:
                     
  Regulatory assets
       
479,462
       
482,999
 
  Other
       
7,678
       
5,273
 
          Total Deferred Charges
       
487,140
       
488,272
 
Total Assets
     
$
1,840,196
     
$
1,762,018
 








THE LACLEDE GROUP, INC.
                 
CONSOLIDATED BALANCE SHEETS (Continued)
                 
                   
(Thousands)
                 
September 30
     
2010
     
2009
 
                       
CAPITALIZATION AND LIABILITIES
                     
Capitalization:
                     
  Common stock equity
     
$
535,577
     
$
517,030
 
  Long-term debt – Laclede Gas
       
364,298
       
389,240
 
          Total Capitalization
       
899,875
       
906,270
 
                       
Current Liabilities:
                     
  Notes payable
       
129,650
       
129,800
 
  Accounts payable
       
95,595
       
72,765
 
  Advance customer billings
       
16,809
       
21,140
 
  Current portion of long-term debt
       
25,000
       
 
  Wages and compensation accrued
       
13,410
       
12,682
 
  Dividends payable
       
8,942
       
8,687
 
  Customer deposits
       
11,244
       
12,400
 
  Interest accrued
       
9,639
       
9,943
 
  Taxes accrued
       
10,501
       
15,951
 
  Unamortized purchased gas adjustments
       
       
3,130
 
  Deferred income taxes
       
155
       
 
  Other
       
12,979
       
12,642
 
          Total Current Liabilities
       
333,924
       
299,140
 
                       
Deferred Credits and Other Liabilities:
                     
  Deferred income taxes
       
292,391
       
256,196
 
  Unamortized investment tax credits
       
3,538
       
3,754
 
  Pension and postretirement benefit costs
       
207,607
       
202,681
 
  Asset retirement obligations
       
25,837
       
25,503
 
  Regulatory liabilities
       
47,365
       
44,225
 
  Other
       
29,659
       
24,249
 
          Total Deferred Credits and Other Liabilities
       
606,397
       
556,608
 
Commitments and Contingencies ( Note 16 )
                     
          Total Capitalization and Liabilities
     
$
1,840,196
     
$
1,762,018
 
                       
                       
                       
                     









THE LACLEDE GROUP, INC.
                 
                 
                   
(Thousands, Except for Shares and Per Share Amounts)
             
 
 
September 30
     
2010
     
2009
 
                       
Common Stock Equity:
                     
  Common stock, par value $1 per share:
                     
    Authorized – 2010 and 2009, 70,000,000 shares
                     
      Issued – 2010, 22,292,804 shares; and 2009, 22,168,120 shares
     
$
22,293
     
$
22,168
 
  Paid-in capital
       
158,698
       
154,218
 
  Retained earnings
       
361,723
       
342,810
 
  Accumulated other comprehensive loss
       
(7,137
)
     
(2,166
)
          Total Common Stock Equity
       
535,577
       
517,030
 
                       
Long-Term Debt – Laclede Gas:
                     
  First Mortgage Bonds:
                     
    6-1/2% Series, due November 15, 2010
       
       
25,000
 
    6-1/2% Series, due October 15, 2012
       
25,000
       
25,000
 
    5-1/2% Series, due May 1, 2019
       
50,000
       
50,000
 
    7% Series, due June 1, 2029
       
25,000
       
25,000
 
    7.90% Series, due September 15, 2030
       
30,000
       
30,000
 
    6% Series, due May 1, 2034
       
100,000
       
100,000
 
    6.15% Series, due June 1, 2036
       
55,000
       
55,000
 
    6.35% Series, due October 15, 2038
       
80,000
       
80,000
 
          Total
       
365,000
       
390,000
 
  Unamortized discount, net of premium, on long-term debt
       
(702
)
     
(760
)
          Total Long-Term Debt – Laclede Gas
       
364,298
       
389,240
 
          Total Capitalization
     
$
899,875
     
$
906,270
 
                       
                       
                       
Long-term debt dollar amounts are exclusive of current portion.
                     
                       
                     









THE LACLEDE GROUP, INC.
                     
             
               
   
Common Stock Issued
 
Paid-in
 
Retained
 
Accum.
Other
Comp.
     
(Thousands, Except for Shares and Per Share Amounts)
 
Shares
 
Amount
 
Capital
 
Earnings
 
Income
 
Total
 
                                     
BALANCE OCTOBER 1, 2007
 
21,645,637
 
$
21,646
 
$
136,061
 
$
268,761
 
$
1,857
 
$
428,325
 
  Adoption of FIN 48, as codified in
    ASC Topic 740, as of October 1, 2007
 
   
   
   
(1,099
)
 
   
(1,099
)
  Net income
 
   
   
   
77,922
   
   
77,922
 
  Dividend reinvestment plan
 
106,436
   
106
   
3,681
   
   
   
3,787
 
  Stock-based compensation costs
 
   
   
2,615
   
   
   
2,615
 
  Employee stock options exercised
 
178,750
   
179
   
4,833
   
   
   
5,012
 
  Employee restricted stock awards
 
62,650
   
62
   
(62
)
 
   
   
 
  Non-employee directors’ restricted stock awards
 
   
   
(421
)
 
   
   
(421
)
  Tax benefit – stock compensation
 
   
   
534
   
   
   
534
 
  Dividends declared:
                                   
    Common stock ($1.50 per share)
 
   
   
   
(32,776
)
 
   
(32,776
)
  Other comprehensive income, net of tax
 
   
   
   
   
2,580
   
2,580
 
BALANCE SEPTEMBER 30, 2008
 
21,993,473
   
21,993
   
147,241
   
312,808
   
4,437
   
486,479
 
  Net income
 
   
   
   
64,247
   
   
64,247
 
  Dividend reinvestment plan
 
47,037
   
47
   
1,969
   
   
   
2,016
 
  Stock-based compensation costs
 
   
   
3,981
   
   
   
3,981
 
  Employee stock options exercised
 
54,125
   
54
   
1,604
   
   
   
1,658
 
  Employee restricted stock awards
 
73,485
   
74
   
(74
)
 
   
   
 
  Employees’ taxes paid associated with restricted
    shares withheld upon vesting
 
   
   
(675
)
 
   
   
(675
)
  Non-employee directors’ restricted stock awards
 
   
   
(570
)
 
   
   
(570
)
  Tax benefit – stock compensation
 
   
   
742
   
   
   
742
 
  Dividends declared:
                                   
    Common stock ($1.54 per share)
 
   
   
   
(34,100
)
 
   
(34,100
)
  Other comprehensive loss, net of tax
 
   
   
   
   
(6,634
 
(6,634
)
  Adoption of SFAS No. 158, as codified in
    ASC Topic 715, net of tax
 
   
   
   
(145
)
 
31
   
(114
)
BALANCE SEPTEMBER 30, 2009
 
22,168,120
   
22,168
   
154,218
   
342,810
   
(2,166
 
517,030
 
  Net income
 
   
   
   
54,040
   
   
54,040
 
  Dividend reinvestment plan
 
42,733
   
43
   
1,379
   
   
   
1,422
 
  Stock-based compensation costs
 
   
   
3,783
   
   
   
3,783
 
  Employee stock options exercised
 
12,500
   
13
   
371
   
   
   
384
 
  Employee restricted stock awards
 
69,451
   
69
   
(69
)
 
   
   
 
  Employees’ taxes paid associated with restricted
    shares withheld upon vesting
 
   
   
(576
)
 
   
   
(576
)
  Non-employee directors’ restricted stock awards
 
   
   
(406
)
 
   
   
(406
)
  Tax benefit – stock compensation
 
   
   
(2
)
 
   
   
(2
)
  Dividends declared:
                                   
    Common stock ($1.58 per share)
 
   
   
   
(35,127
)
 
   
(35,127
)
  Other comprehensive loss, net of tax
 
   
   
   
   
(4,971
)
 
(4,971
)
BALANCE SEPTEMBER 30, 2010
 
22,292,804
 
$
22,293
 
$
158,698
 
$
361,723
 
$
(7,137
)
$
535,577
 
                                     
                                     
                                     
                         








THE LACLEDE GROUP, INC.
             
             
               
(Thousands)
             
Years Ended September 30
 
2010
 
2009
 
2008
 
                     
Operating Activities:
                   
  Net Income
 
$
54,040
 
$
64,247
 
$
77,922
 
  Adjustments to reconcile net income to
                   
      net cash provided by (used in) operating activities:
                   
    Gain on sale of discontinued operations
   
   
   
(44,401
)
    Depreciation, amortization and accretion
   
37,908
   
37,041
   
36,913
 
    Deferred income taxes and investment tax credits
   
32,757
   
17,937
   
5,786
 
    Other - net
   
2,891
   
3,682
   
5,494
 
    Changes in assets and liabilities:
                   
      Accounts receivable – net
   
(7,594
)
 
78,964
   
(50,106
)
      Unamortized purchased gas adjustments
   
(26,848
)
 
36,541
   
(20,598
)
      Deferred purchased gas costs
   
20,265
   
(45,234
)
 
(19,614
)
      Accounts payable
   
22,457
   
(86,184
)
 
59,161
 
      Advance customer billings – net
   
(4,331
)
 
(4,408
)
 
108
 
      Taxes accrued
   
(5,583
)
 
4,546
   
(6,886
)
      Natural gas stored underground
   
(20,263
)
 
102,868
   
(68,011
)
      Other assets and liabilities
   
1,216
   
18,753
   
(12,300
)
          Net cash provided by (used in) operating activities
   
106,915
   
228,753
   
(36,532
)
                     
Investing Activities:
                   
  Proceeds from sale of discontinued operations
   
   
   
83,554
 
  Capital expenditures
   
(56,997
)
 
(52,384
)
 
(56,621
)
  Other investments
   
(3,776
)
 
130
   
(1,393
)
  Proceeds from unconsolidated affiliate trust’s redemption of its common securities
   
   
   
1,400
 
          Net cash (used in) provided by investing activities
   
(60,773
)
 
(52,254
)
 
26,940
 
                     
Financing Activities:
                   
  Issuance of first mortgage bonds
   
   
   
80,000
 
  Maturity of first mortgage bonds
   
   
   
(40,000
)
  Redemption of long-term debt to unconsolidated affiliate trust
   
   
   
(46,400
)
  (Repayment) issuance of short-term debt - net
   
(150
)
 
(86,100
)
 
4,500
 
  Change in book overdrafts
   
358
   
652
   
 
  Issuance of common stock
   
1,806
   
3,674
   
8,799
 
  Non-employee directors’ restricted stock awards
   
(406
)
 
(570
)
 
(421
)
  Dividends paid
   
(34,851
)
 
(33,806
)
 
(32,430
)
  Preferred stock redeemed/reacquired
   
   
(627
)
 
(160
)
  Employees’ taxes paid associated with restricted shares withheld upon vesting
   
(576
)
 
(675
)
 
 
  Excess tax benefits from stock-based compensation
   
131
   
761
   
387
 
  Other
   
(126
)
 
(116
)
 
(2,530
)
          Net cash used in financing activities
   
(33,814
)
 
(116,807
)
 
(28,255
)
                     
Net Increase (Decrease) in Cash and Cash Equivalents
   
12,328
   
59,692
   
(37,847
)
Cash and Cash Equivalents at Beginning of Year
   
74,591
   
14,899
   
52,746
 
Cash and Cash Equivalents at End of Year
 
$
86,919
 
$
74,591
 
$
14,899
 
                     
Supplemental Disclosure of Cash Paid (Refunded) During the Year for:
                   
    Interest
 
$
26,393
 
$
29,266
 
$
32,687
 
    Income taxes
   
(3,842
)
 
5,936
   
47,572
 
                     
                     
                   






THE LACLEDE GROUP, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 
1.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF CONSOLIDATION - The consolidated financial statements include the accounts of The Laclede Group, Inc. (Laclede Group or the Company) and its subsidiary companies. All subsidiaries are wholly owned. Laclede Gas Company (Laclede Gas or the Utility) and other subsidiaries of Laclede Group may engage in related party transactions during the ordinary course of business. All intercompany balances have been eliminated from the consolidated financial statements of Laclede Group except that certain intercompany transactions with Laclede Gas are not eliminated in accordance with the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” Those types of transactions include sales of natural gas from Laclede Gas to Laclede Energy Resources, Inc. (LER), sales of natural gas from LER to Laclede Gas, and transportation services provided by Laclede Pipeline Company to Laclede Gas. These revenues are shown on the Intersegment revenues lines in the table included in Note 15 under Regulated Gas Distribution, Non-Regulated Gas Marketing, and Other columns, respectively.
DISCONTINUED OPERATIONS - On March 31, 2008, Laclede Group sold 100% of its interest in SM&P Utility Resources, Inc. (SM&P), its wholly-owned subsidiary, which comprised the Non-Regulated Services segment. In accordance with generally accepted accounting principles, the operating results of SM&P and gain on sale have been aggregated and reported on the Statements of Consolidated Income as Income from Discontinued Operations, Net of Income Tax. The Company has reported in discontinued operations interest expense based on amounts previously recorded by SM&P. Discontinued operations does not include general corporate overheads previously recorded by SM&P. For additional information relative to the Company’s sale of SM&P, refer to Note 2 , Discontinued Operations.
INVESTMENT IN UNCONSOLIDATED AFFILIATE TRUST - In fiscal year 2003, Laclede Group formed Laclede Capital Trust I (Trust), its affiliated, nonconsolidated trust, for the sole purpose of issuing trust securities and investing the gross proceeds of the sale of the trust securities in debt securities of Laclede Group. All of the Trust securities had a liquidation value of $25 per share and a dividend rate of 7.70%, with all of its common securities being owned by Laclede Group and all of its preferred securities being sold to the public. The Trust’s sole asset was the Company’s $46.4 million aggregate principal amount of 7.70% debentures due December 1, 2032, which had the same economic terms as the Trust securities and were reflected as Long-term debt to unconsolidated affiliate trust on the Consolidated Balance Sheets. The Company’s investment in the Trust common securities was included on the Other investments line on the Consolidated Balance Sheets.
On May 5, 2008, Laclede Group redeemed in full its $46.4 million subordinated debentures, which also triggered the redemption of all of the Trust common and preferred securities on the same date. Interest on the debentures and distributions on the Trust securities ceased on and after the redemption date. Upon redemption, Laclede Group recognized a pre-tax loss of $1.4 million, primarily attributable to unamortized issuance costs. A portion of the proceeds received from the sale of SM&P was used to fund the redemption. The Trust was dissolved on June 16, 2008.
NATURE OF OPERATIONS - Laclede Group is a public utility holding company under the Public Utility Holding Company Act of 2005. All subsidiaries are wholly owned by Laclede Group. The Regulated Gas Distribution segment includes the regulated activities of Laclede Gas, Laclede Group’s largest subsidiary and core business unit. Laclede Gas is a public utility engaged in the retail distribution and sale of natural gas. Laclede Gas serves an area in eastern Missouri, with a population of approximately 2.1 million, including the City of St. Louis and parts of ten counties in eastern Missouri. As an adjunct to its gas distribution business, Laclede Gas operates an underground natural gas storage field. The Non-Regulated Gas Marketing segment includes LER, a subsidiary engaged in the marketing of natural gas and related activities on a non-regulated basis. The activities of other subsidiaries are described in Note 15 , Information by Operating Segment, and are included in the Other column.
USE OF ESTIMATES - The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.
SYSTEM OF ACCOUNTS - The accounts of Laclede Gas are maintained in accordance with the Uniform System of Accounts prescribed by the Missouri Public Service Commission (MoPSC or Commission), which system substantially conforms to that prescribed by the Federal Energy Regulatory Commission (FERC). The accounts of Laclede Pipeline Company are maintained in accordance with the Uniform System of Accounts prescribed by the FERC.


UTILITY PLANT, DEPRECIATION AND AMORTIZATION - Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses.
Utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal years 2010, 2009, and 2008, annual depreciation and amortization expense averaged 3.1% of the original cost of depreciable and amortizable property.
The Utility’s capital expenditures were $56.2 million, $51.4 million, and $55.3 million for fiscal years 2010, 2009, and 2008, respectively. Additionally, the Utility had recorded accruals for capital expenditures totaling $2.2 million at September 30, 2010, $1.7 million at September 30, 2009, and $2.3 million at September 30, 2008. Accrued capital expenditures are excluded from the Statements of Consolidated Cash Flows.
ASSET RETIREMENT OBLIGATIONS - Laclede Group records legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Company has recorded asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of Laclede Gas’ distribution system and general plant. Asset retirement obligations recorded by Laclede Group’s other subsidiaries are not material. As authorized by the MoPSC, Laclede Gas accrues future asset removal costs associated with its property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities. When Laclede Gas retires depreciable utility plant and equipment, it charges the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities. In the rate setting process, the regulatory liability is deducted from the rate base upon which the Utility has the opportunity to earn its allowed rate of return.
The following table presents a reconciliation of the beginning and ending balances of Asset retirement obligations at September 30 as reported in the Consolidated Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Asset retirement obligations, beginning of year
 
$
25,503
 
$
26,833
 
 
Liabilities incurred during the period
   
208
   
415
 
 
Liabilities settled during the period
   
(904
)
 
(2,776
)
 
Accretion
   
1,526
   
1,567
 
 
Revisions in estimated cash flows
   
(496
)
 
(536
)
 
Asset retirement obligations, end of year
 
$
25,837
 
$
25,503
 

REGULATED OPERATIONS - Laclede Gas accounts for its regulated operations in accordance with ASC Topic 980. This Topic sets forth the application of generally accepted accounting principles in the United States of America (GAAP) for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities).


The following regulatory assets and regulatory liabilities were reflected in the Consolidated Balance Sheets as of September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Regulatory Assets:
             
 
  Future income taxes due from customers
 
$
100,624
 
$
91,782
 
 
  Pension and postretirement benefit costs
   
288,077
   
280,939
 
 
  Unamortized purchased gas adjustments
   
23,718
   
 
 
  Purchased gas costs
   
74,040
   
94,305
 
 
  Compensated absences
   
7,885
   
7,425
 
 
  Cold weather rule
   
4,275
   
5,264
 
 
  Other
   
4,561
   
3,284
 
 
     Total Regulatory Assets
 
$
503,180
 
$
482,999
 
 
Regulatory Liabilities:
             
 
  Unamortized purchased gas adjustments
 
$
 
$
3,130
 
 
  Unamortized investment tax credits
   
3,538
   
3,754
 
 
  Accrued cost of removal
   
45,441
   
41,590
 
 
  Other
   
1,924
   
2,635
 
 
     Total Regulatory Liabilities
 
$
50,903
 
$
51,109
 

As authorized by the MoPSC, Laclede Gas discontinued deferring certain costs for future recovery, as expenses associated with those specific areas were included in approved rates effective December 27, 1999. Previously deferred costs of $10.5 million are being recovered and amortized on a straight-line basis over a fifteen-year period, without return on investment. Amortization of these costs totaled $7.6 million from December 27, 1999 through September 30, 2010.
Certain previously deferred costs, totaling $2.6 million, are being recovered and amortized on a straight-line basis over a period of approximately two years, without return on investment. Amortization of these costs totaled $0.1 million from September 1, 2010 through September 30, 2010.
NATURAL GAS STORED UNDERGROUND - Inventory of Utility natural gas in storage is priced on a last-in, first-out (LIFO) basis. The replacement cost of natural gas stored underground for current use at September 30, 2010 and September 30, 2009 was less than the LIFO cost by $26.5 million and $33.1 million, respectively. The inventory carrying value is not adjusted to the lower of cost or market prices because, pursuant to the Laclede Gas Purchased Gas Adjustment (PGA) Clause, actual gas costs are recovered in customer rates.
REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its regulated gas distribution revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at September 30, 2010 and 2009, for the Utility, were $11.3 million and $12.7 million, respectively.
LER and Laclede Group’s other subsidiaries record revenues when earned, either when the product is delivered or when services are performed.
In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. Many of LER’s derivative natural gas contracts are designated as normal purchases or normal sales, and, as such, are excluded from the scope of ASC Topic 815, “Derivatives and Hedging.” As such, those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value (representing unrealized gains or losses) recognized in earnings in the periods prior to physical delivery. For additional information on derivative instruments, refer to Note 11 , Derivative Instruments and Hedging Activities.


PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT – As authorized by the MoPSC, the PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, the Utility is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism. Certain other provisions of the PGA Clause are included below:
 
The tariffs allow the Utility flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months.
 
The Utility is authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The Utility is also authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits.
 
The MoPSC approved a plan applicable to the Utility’s gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level of gas cost. This gas supply cost management program  allows the Utility to retain 10% of cost savings, up to a maximum of $3.0 million annually. The Utility recorded $0.6 million in pre-tax income under the plan in fiscal year 2008. Laclede Gas did not record any income under the plan during fiscal years 2009 and 2010. Income recorded under the plan is included in Regulated Gas Distribution Operating Revenues on the Statements of Consolidated Income.
Pursuant to the provisions of the PGA Clause, the difference between actual costs incurred and costs recovered through the application of the PGA (including costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs), amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Company’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries are reflected as a deferred charge or credit until fiscal year end. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA Clause also provides for the treatment of income from off-system sales and capacity release revenues, as described below.
OFF-SYSTEM SALES - Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The customer share of such income is determined in accordance with the table below. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November.

 
Pre-tax Income
Customer Share
 
Company Share
 
First $2 million
85%
 
15%
 
Next $2 million
80%
 
20%
 
Next $2 million
75%
 
25%
 
Amounts exceeding $6 million
70%
 
30%



INCOME TAXES - Laclede Group and its subsidiaries have elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. GAAP permits the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. Laclede Group companies record deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities in the financial statements, and the related tax basis. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or regulatory liability accounts for regulated companies, and will be reflected as income or loss for non-regulated companies.
Laclede Gas’ investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
CASH AND CASH EQUIVALENTS - All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Company’s controlled disbursement bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the Consolidated Balance Sheets. Changes in book overdrafts between periods are reflected as Financing Activities in the Statements of Consolidated Cash Flows.
NATURAL GAS RECEIVABLE – From time to time, LER enters into natural gas transactions with natural gas pipeline companies known as park and loan arrangements. Under the terms of the arrangements, LER purchases natural gas from a third party and delivers that natural gas to the pipeline company for the right to receive the same quantity of natural gas from the pipeline company at the same location in a specified future period. These arrangements are accounted for as non-monetary transactions under GAAP and are recorded at the carrying amount. As such, natural gas receivables are reflected on the Consolidated Balance Sheets at cost, which includes related pipeline fees associated with the transactions. In the period that the natural gas is returned to LER, concurrent with the sale of the natural gas to a third party, the related natural gas receivable is expensed in the Statements of Consolidated Income. In conjunction with these transactions, LER usually enters into New York Mercantile Exchange (NYMEX) natural gas futures contracts or fixed price sales agreements to protect against market changes in future sales prices.
EARNINGS PER COMMON SHARE - As discussed in the New Accounting Pronouncements section below, the Company adopted certain changes to the computation of earnings per share effective October 1, 2009. GAAP requires dual presentation of basic and diluted earnings per share (EPS). EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareholders. Certain of the Company’s stock-based compensation awards pay nonforfeitable dividends to the participants during the vesting period and, as such, are deemed participating securities. Basic EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding that are increased for additional shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares, pursuant to the treasury stock method. Shares attributable to non-participating stock options and time-vested restricted stock/units are excluded from the calculation of diluted earnings per share if the effect would be antidilutive. Shares attributable to non-participating performance-contingent restricted stock awards are only included in the calculation of diluted earnings per share to the extent the underlying performance and/or market conditions are satisfied (a) prior to the end of the reporting period or (b) would be satisfied if the end of the reporting period were the end of the related contingency period and the result would be dilutive. The Company’s EPS computations are set forth in Note 5 , Earnings Per Common Share.
GROSS RECEIPTS AND SALES TAXES - Gross receipts taxes associated with Laclede Gas’ natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Consolidated Income. Amounts recorded in Regulated Gas Distribution Operating Revenues were $44.1 million, $51.6 million, and $52.5 million for fiscal years 2010, 2009, and 2008, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
Sales taxes imposed on applicable Company sales are billed to customers. These amounts are not recorded in the Statements of Consolidated Income, but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the Consolidated Balance Sheets.


ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.
GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES - The Company self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting.
FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below:
Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities.
Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data.
Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability.
Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Additional information about fair value measurements is provided in Note 3 , Pension Plans and Other Postretirement Benefits, Note 9 , Fair Value of Financial Instruments, and Note 10 , Fair Value Measurements.
STOCK-BASED COMPENSATION – The Company measures all share-based compensation awards at fair value at the date of grant and recognizes the compensation cost of the awards over the requisite service period. Forfeitures are estimated at the time of grant and revised, if necessary, in subsequent periods if the actual forfeitures differ from those estimates. Refer to Note 4 , Stock-Based Compensation, for further discussion of the accounting for the Company’s stock-based compensation plans.
NEW ACCOUNTING STANDARDS – In September 2006, the FASB issued Statement of Financial Accounting Standards (SFAS) No. 157, “Fair Value Measurements,” as codified in ASC Topic 820, “Fair Value Measurements and Disclosures.” This Statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. The Statement applies to fair value measurements required under other accounting guidance that require or permit fair value measurements. Accordingly, this Statement does not require any new fair value measurements. The guidance in this Statement does not apply to the Company’s stock-based compensation plans accounted for in accordance with ASC Topic 718, “Compensation-Stock Compensation.” The Company partially adopted SFAS No. 157 on October 1, 2008 and elected the one-year deferral allowed by FASB Staff Position (FSP) No. FAS 157-2, which permits delayed application of this Statement for nonfinancial assets and nonfinancial liabilities, except for those recognized or disclosed at fair value on a recurring basis. The partial adoption of this Statement had no impact on the Company’s financial position or results of operations. For disclosures required pursuant to ASC Topic 820, see Note 10 , Fair Value Measurements. The Company adopted SFAS No. 157 for certain nonfinancial assets and nonfinancial liabilities as of October 1, 2009. Such adoption had no impact on the Company’s financial position or results of operations.
In June 2008, the FASB issued FSP No. Emerging Issues Task Force (EITF) 03-6-1, “Determining Whether Instruments Granted in Share-Based Payment Transactions Are Participating Securities,” as codified is ASC Topic 260, “Earnings per Share.” This FSP addresses whether instruments granted in share-based payment transactions are participating securities prior to vesting and, therefore, need to be included in the earnings allocation in computing EPS under the two-class method described in ASC Topic 260. The guidance in this FSP states that unvested share-based payment awards that contain nonforfeitable rights to dividends or dividend equivalents (whether paid or unpaid) are participating securities and shall be included in the computation of EPS pursuant to the two-class method. The FSP requires that the guidance be applied retrospectively to all prior-period EPS data presented. Certain of the Company’s stock-based compensation awards pay nonforfeitable dividends to the participants during the vesting period and, as such, are deemed participating securities under this FSP. The Company adopted this FSP effective October 1, 2009. EPS and diluted shares outstanding amounts for previous fiscal years have been restated to reflect the retrospective application of the FSP. For fiscal year 2009, the effect of adoption reduced total basic and diluted EPS by $0.03 each, compared to originally reported amounts. For fiscal year 2008, the effect of adoption reduced total basic EPS $0.03 and reduced total diluted EPS by $0.02, compared to originally reported amounts. Reported net income and cash flows were not affected by the adoption of the FSP. The Company’s EPS computations are set forth in Note 5 , Earnings Per Common Share.


In December 2008, the FASB issued FSP No. FAS 132(R)-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets,” as codified in ASC Topic 715, “Compensation–Retirement Benefits.” This FSP provides guidance on an employer’s disclosures about plan assets of a defined benefit pension or other postretirement plan. The FSP requires disclosure of additional information regarding investment policies and strategies, the classes of plan assets, fair value measurements of plan assets, and significant concentrations of risk. The enhanced disclosures, which the Company adopted this fiscal year, are presented in Note 3 , Pension Plans and Other Postretirement Benefits. The FSP does not require disclosures for comparative periods prior to adoption.
In August 2009, the FASB issued Accounting Standards Update (ASU) No. 2009-05, “Measuring Liabilities at Fair Value,” to update ASC Topic 820. The guidance provides clarification on measuring liabilities at fair value when a quoted price in an active market is not available. In such circumstances, the ASU specifies that a valuation technique should be applied that uses either the quote of the identical liability when traded as an asset, the quoted prices for similar liabilities or similar liabilities when traded as assets, or another valuation technique consistent with existing fair value measurement guidance. Laclede Group’s adoption of this ASU in the first quarter of fiscal year 2010 had no impact on the Company’s financial position or results of operations.
In January 2010, the FASB issued ASU No. 2010-06, “Improving Disclosures about Fair Value Measurements,” which amends ASC Topic 820. The ASU requires separate disclosure of significant transfers in and out of level 1 and level 2 fair value measurements. It also requires disclosure of the policy for when transfers are recognized. Additionally, the ASU clarifies certain areas of the guidance, including the level of disaggregation required in fair value measurement disclosures. While the adoption of these updates during the quarter ended March 31, 2010 had no effect on the consolidated financial statements, the Company modified its disclosures in Note 10 , Fair Value Measurements, accordingly. The ASU also requires that certain activity in the level 3 fair value measurements reconciliation be presented on a gross basis (instead of net). This change is effective for the Company’s disclosures in the first quarter of fiscal year 2012.
In February 2010, the FASB issued ASU No. 2010-09, “Amendments to Certain Recognition and Disclosure Requirements.” The ASU amends ASC Topic 855, “Subsequent Events.” Subsequent events or transactions occur after the balance sheet date, but prior to the financial statements being issued, and are required to be assessed by management for possible financial statement recognition and/or disclosure. For entities that are Securities and Exchange Commission (SEC) filers, this ASU removes the requirement to disclose the date through which subsequent events have been evaluated to alleviate potential conflicts with SEC guidance. Laclede Group adopted this ASU during the quarter ended March 31, 2010. While the adoption of the ASU did not impact the consolidated financial statements or management’s process for assessing subsequent events, the Company did modify its disclosures accordingly.


2.
DISCONTINUED OPERATIONS

On March 31, 2008, the Company completed the sale of 100% of its interest in its wholly-owned subsidiary, SM&P, to Stripe Acquisition, Inc. (an affiliate of Kohlberg Management VI, LLC) for $85 million in cash, subject to certain closing and post-closing adjustments. SM&P was an underground facilities locating and marking business that previously comprised Laclede Group’s Non-Regulated Services operating segment. The sales agreement included representations, warranties, and indemnification provisions customary for such transactions and was filed as an exhibit to the March 31, 2008 Form 10-Q. For information concerning Laclede Group’s obligations under these provisions, see Note 16 , Commitments and Contingencies.
In accordance with generally accepted accounting principles, the operating results of SM&P have been aggregated and reported on the Statements of Consolidated Income as Income from Discontinued Operations, Net of Income Tax. The Company has reported in discontinued operations interest expense based on amounts previously recorded by SM&P. Discontinued operations includes pre-tax interest expense of $1.6 million for fiscal year 2008. Discontinued operations does not include general corporate overhead expense. Income from Discontinued Operations reported in the Statements of Consolidated Income consists of the following:

 
(Thousands)
 
2008
 
           
 
Operating revenues
 
$
65,423
 
           
 
Loss from operations
   
(9,434
)
 
Gain on disposal
   
44,401
 
 
Pre-tax income
   
34,967
 
 
Income tax expense
   
14,571
 
 
Income from Discontinued Operations
 
$
20,396
 

Cash flows from SM&P’s operations were not material.

 
61
 
 

3.
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

In September 2009, the Company adopted the measurement date provisions in ASC Topic 715. ASC Topic 715 requires that plan assets and benefit obligations be measured as of the date of the employer’s fiscal year-end statement of financial position. The Company previously used a June 30 valuation date for its benefit plans. To change to a September 30 measurement date, the Company elected to use the 15-month alternative transition approach, wherein benefit costs for the period between June 30, 2008 and September 30, 2009 are allocated proportionately between a retained earnings adjustment and periodic benefit cost for the period. As a result of changing the measurement date, excluding the effect of income taxes, the Company recorded a one-time cumulative effect adjustment to reduce retained earnings by $0.2 million, increase accumulated other comprehensive income by $50,000, and, pursuant to ASC Topic 980, increase net regulatory assets by $5.1 million. In conjunction with the adoption, the Company recorded increases to benefit liabilities totaling $5.3 million.

Pension Plans

Laclede Gas has non-contributory, defined benefit, trusteed forms of pension plans covering substantially all employees. Effective January 1, 2009, the Utility modified the calculation of future benefits under Laclede Gas’ primary plan from a years of service and final average compensation formula to a cash balance formula, which accrues benefits based on a percentage of compensation and provides interest credits on the balance. Benefits attributable to plan participation prior to January 1, 2009 will be based on final average compensation at the date of termination of employment and years of service earned at January 1, 2009. Effective January 1, 2010, the Utility modified the calculation of future benefits under its Missouri Natural Gas division plan from a career average formula to a cash balance formula, which accrues benefits based on a percentage of compensation, provides interest credits on the balance, and provides certain transition credits. Benefits attributable to plan participation prior to January 1, 2010 will be based on career average compensation earned as a participant prior to January 1, 2010. Plan assets consist primarily of corporate and U.S. government obligations and equity market exposure achieved through derivative instruments.
Pension costs in 2010, 2009, and 2008 amounted to $7.4, $6.2, and $6.1 million, respectively, including amounts charged to construction.
The net periodic pension costs include the following components:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Service cost – benefits earned during the period
 
$
8,841
 
$
8,936
 
$
12,970
 
 
Interest cost on projected benefit obligation
   
19,729
   
20,957
   
18,680
 
 
Expected return on plan assets
   
(20,256
)
 
(20,938
)
 
(20,650
)
 
Amortization of prior service cost
   
756
   
1,035
   
1,088
 
 
Amortization of actuarial loss
   
8,107
   
3,096
   
3,165
 
 
Sub-total
   
17,177
   
13,086
   
15,253
 
 
Loss on lump-sum settlement
   
1,078
   
   
 
 
Regulatory adjustment
   
(10,862
)
 
(6,890
)
 
(9,120
)
 
Net pension cost
 
$
7,393
 
$
6,196
 
$
6,133
 

Other changes in plan assets and pension benefit obligations recognized in other comprehensive income include the following:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Current year actuarial loss
 
$
3,822
 
$
84,187
 
$
18,050
 
 
Amortization of actuarial loss
   
(9,185
)
 
(3,096
)
 
(3,165
)
 
Current year prior service credit
   
(2,949
)
 
   
 
 
Amortization of prior service cost
   
(756
)
 
(1,035
)
 
(1,088
)
 
Sub-total
   
(9,068
)
 
80,056
   
13,797
 
 
Regulatory adjustment
   
9,380
   
(78,527
)
 
(13,697
)
 
Total recognized in other comprehensive income
 
$
312
 
$
1,529
 
$
100
 



Pursuant to the provisions of the Laclede Gas pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a MoPSC Order, lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs. Lump-sum payments recognized as settlements during fiscal 2010 were $2.3 million. No lump-sum payments were recognized as settlements during fiscal years 2009 and 2008.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s qualified pension plans is based on an allowance of $4.8 million annually. The difference between this amount and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
The following table sets forth the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Benefit obligation at beginning of year
 
$
378,032
 
$
308,736
 
 
Service cost
   
8,841
   
12,371
 
 
Interest cost
   
19,729
   
26,150
 
 
Plan amendments
   
(2,949
)
 
 
 
Actuarial loss
   
28,437
   
54,769
 
 
Settlement loss
   
778
   
 
 
Gross benefits paid **
   
(34,508
)
 
(23,994
)
                 
 
Benefit obligation at end of year
 
$
398,360
 
$
378,032
 
                 
 
Accumulated benefit obligation at end of year
 
$
338,042
 
$
305,255
 
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.
     
 
**
Includes $(2,293) lump-sum payments recognized as settlements in fiscal year 2010. No lump-sum payments were recognized as settlements in fiscal year 2009.

The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Fair value of plan assets at beginning of year
 
$
223,688
 
$
248,346
 
 
Actual return on plan assets
   
45,648
   
(3,245
)
 
Employer contributions
   
6,094
   
2,581
 
 
Gross benefits paid **
   
(34,508
)
 
(23,994
)
 
Fair value of plan assets at end of year
 
$
240,922
 
$
223,688
 
                 
 
Funded status of plans, end of year
 
$
(157,438
)
$
(154,344
)
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.
     
 
**
Includes $(2,293) lump-sum payments recognized as settlements in fiscal year 2010. No lump-sum payments were recognized as settlements in fiscal year 2009.



The following table sets forth the amounts recognized in the Consolidated Balance Sheets at September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Current liabilities
 
$
(2,420
)
$
(1,920
)
 
Noncurrent liabilities
   
(155,018
)
 
(152,424
)
 
  Total
 
$
(157,438
)
$
(154,344
)
                 
 
Pre-tax amounts recognized in accumulated other comprehensive income
             
 
  not yet recognized as components of net periodic pension cost consist of:
             
 
Net actuarial loss
 
$
157,327
 
$
162,689
 
 
Prior service costs
   
6,245
   
9,950
 
 
  Sub-total
   
163,572
   
172,639
 
 
Adjustments for amounts included in Regulatory Assets
   
(158,867
)
 
(168,246
)
 
  Total
 
$
4,705
 
$
4,393
 

At September 30, 2010, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic pension cost during fiscal year 2011:

 
(Thousands)
     
           
 
Amortization of net actuarial loss
 
$
10,228
 
 
Amortization of prior service cost
   
642
 
 
  Sub-total
   
10,870
 
 
Regulatory adjustment
   
(10,444
)
 
  Total
 
$
426
 

The assumptions used to calculate net periodic pension costs are as follows:

   
2010
 
2009
 
2008
             
 
Weighted average discount rate
5.25%
 
6.60%
 
6.25%
 
Weighted average rate of future compensation increase
3.25%
 
3.75%
 
3.50%
 
Expected long-term rate of return on plan assets
8.25%
 
8.25%
 
8.25%

The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually.
The assumptions used to calculate the benefit obligations are as follows:

   
2010
 
2009
         
 
Weighted average discount rate
4.75%
 
5.25%
 
Weighted average rate of future compensation increase
3.00%
 
3.25%



Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Projected benefit obligation
 
$
398,360
 
$
378,032
 
 
Fair value of plan assets
   
240,922
   
223,688
 
                 
 
Accumulated benefit obligation
   
338,042
   
305,255
 
 
Fair value of plan assets
   
240,922
   
223,688
 

Following are the targeted and actual plan assets by category:

   
2011
 
2010
 
2009
   
Target
 
Actual
 
Actual
             
 
Equity Strategy
50%
 
49%
 
50%
 
Debt Securities
50%
 
51%
 
50%
 
  Total
100%
 
100%
 
100%

Laclede Gas’ investment policy is designed to maximize, to the extent possible, the funded status of the plan over time, and minimize volatility of funding and costs. The policy seeks to maximize investment returns consistent with these objectives and Laclede Gas’ tolerance for risk. The duration of plan liabilities and the impact of potential changes in asset values on the funded status are fundamental considerations in the selection of plan assets. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with the policy. The policy seeks to avoid significant concentrations of risk by investing in a diversified portfolio of assets. Investments in corporate, U. S. government and agencies, and, to a lesser extent, international debt securities seek to provide duration matching with plan liabilities, and typically have investment grade ratings and reflect allocations across various entities and industries. The investment policy permits the use of derivative instruments, which may be used to achieve the desired market exposure of an index, adjust portfolio duration, or rebalance the total portfolio to the target asset allocation. The Equity Strategy utilizes a combination of derivative instruments and debt securities to achieve both diversified equity market exposure while generating returns from the fixed-income investments and providing further duration matching with the liabilities. Performance and compliance with the guidelines is regularly monitored. The policy calls for increased allocations to debt securities as the funded status improves.
Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:

 
 
(Millions)
 
 
Pensions from
Qualified Trust
 
Pensions from
Laclede Gas
Funds
 
                         
 
2011
   
$
22.0
     
$
2.4
   
 
2012
     
20.8
       
1.5
   
 
2013
     
23.8
       
1.0
   
 
2014
     
25.9
       
0.8
   
 
2015
     
30.1
       
0.7
   
 
2016 – 2020
     
188.2
       
3.7
   

The funding policy of Laclede Gas is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Contributions to the pension plans in fiscal year 2011 are anticipated to be $10.6 million into the qualified trusts, and $2.4 million into the non-qualified plans.



Postretirement Benefits

Laclede Gas provides certain life insurance benefits at retirement. Medical insurance is available after early retirement until age 65. The transition obligation not yet includible in postretirement benefit cost is being amortized over 20 years. Postretirement benefit costs in 2010, 2009, and 2008 amounted to $7.6 million per year, including amounts charged to construction.
Net periodic postretirement benefit costs consisted of the following components:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Service cost – benefits earned during the period
 
$
6,442
 
$
5,132
 
$
4,560
 
 
Interest cost on accumulated postretirement
                   
 
  benefit obligation
   
4,515
   
4,679
   
3,909
 
 
Expected return on plan assets
   
(3,032
)
 
(2,376
)
 
(2,039
)
 
Amortization of transition obligation
   
136
   
136
   
136
 
 
Amortization of prior service credit
   
(2,328
)
 
(2,328
)
 
(2,328
)
 
Amortization of actuarial loss
   
3,980
   
3,509
   
2,985
 
 
Sub-total
   
9,713
   
8,752
   
7,223
 
 
Regulatory adjustment
   
(2,071
)
 
(1,110
)
 
419
 
 
Net postretirement benefit cost
 
$
7,642
 
$
7,642
 
$
7,642
 

Other changes in plan assets and postretirement benefit obligations recognized in other comprehensive income include the following:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Current year actuarial loss
 
$
6,713
 
$
11,137
 
$
9,772
 
 
Amortization of actuarial loss
   
(3,980
)
 
(3,509
)
 
(2,985
)
 
Amortization of prior service credit
   
2,328
   
2,328
   
2,328
 
 
Amortization of transition obligation
   
(136
)
 
(136
)
 
(136
)
 
Sub-total
   
4,925
   
9,820
   
8,979
 
 
Regulatory adjustment
   
(4,925
)
 
(9,820
)
 
(8,979
)
 
Total recognized in other comprehensive income
 
$
 
$
 
$
 

Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s postretirement benefit plans is based on an allowance of $7.6 million annually. The difference between this amount and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Benefit obligation at beginning of year
 
$
83,631
 
$
69,714
 
 
Service cost
   
6,442
   
6,415
 
 
Interest cost
   
4,515
   
5,848
 
 
Actuarial loss
   
7,564
   
7,298
 
 
Gross benefits paid
   
(4,173
)
 
(5,644
)
 
Benefit obligation at end of year
 
$
97,979
 
$
83,631
 
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.




The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Fair value of plan assets at beginning of year
 
$
33,561
 
$
26,082
 
 
Actual return on plan assets
   
3,883
   
(869
)
 
Employer contributions
   
11,819
   
13,992
 
 
Gross benefits paid
   
(4,173
)
 
(5,644
)
 
Fair value of plan assets at end of year
 
$
45,090
 
$
33,561
 
                 
 
Funded status of plans, end of year
 
$
(52,889
)
$
(50,070
)
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.

The following table sets forth the amounts recognized in the Consolidated Balance Sheets at September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Current liabilities
 
$
(300
)
$
(280
)
 
Noncurrent liabilities
   
(52,589
)
 
(49,790
)
 
  Total
 
$
(52,889
)
$
(50,070
)
                 
 
Pre-tax amounts recognized in accumulated other comprehensive income
             
 
  not yet recognized as components of net periodic postretirement cost
             
 
    consist of:
             
 
Net actuarial loss
 
$
49,442
 
$
46,709
 
 
Prior service credit
   
(4,423
)
 
(6,751
)
 
Transition obligation
   
365
   
501
 
 
  Sub-total
   
45,384
   
40,459
 
 
Adjustments for amounts included in Regulatory Assets
   
(45,384
)
 
(40,459
)
 
  Total
 
$
 
$
 

At September 30, 2010, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic postretirement benefit cost during fiscal year 2011:

 
  (Thousands)
       
 
  Amortization of net actuarial loss
 
$
4,443
 
 
  Amortization of prior service credit
   
(2,328
)
 
  Amortization of transition obligation
   
136
 
 
    Sub-total
   
2,251
 
 
  Regulatory adjustment
   
(2,251
)
 
    Total
 
$
 

The assumptions used to calculate net periodic postretirement benefit costs are as follows:

   
2010
 
2009
 
2008
             
 
Weighted average discount rate
5.15%
 
6.35%
 
6.25%
 
Weighted average rate of future compensation increase
3.25%
 
3.75%
 
3.50%
 
Expected long-term rate of return on plan assets
8.25%
 
8.25%
 
8.25%




The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually.
The assumptions used to calculate the accumulated postretirement benefit obligations are as follows:

   
2010
 
2009
         
 
Weighted average discount rate
4.70%
 
5.15%
 
Weighted average rate of future compensation increase
3.00%
 
3.25%

The assumed medical cost trend rates at September 30 are as follows:

   
2010
 
2009
 
Medical cost trend assumed for next year
8.00%
 
8.00%
 
Rate to which the medical cost trend rate is assumed to decline
     
 
    (the ultimate medical cost trend rate)
5.00%
 
5.00%
 
Year that the rate reaches the ultimate trend
2017
 
2016

The following table presents the effect of an assumed 1% change in the assumed medical cost trend rate:

 
(Thousands)
 
1% Increase
 
1% Decrease
 
                     
 
Effect on net periodic postretirement benefit cost
   
$
1,270
   
$
(1,130
)
 
Effect on accumulated postretirement benefit obligation
     
5,850
     
(5,300
)

Following are the targeted and actual plan assets by category:

   
2011
 
2010
 
2009
   
Target
 
Actual
 
Actual
             
 
Equity Securities
60%
 
59%
 
58%
 
Debt Securities
40%
 
41%
 
42%
 
  Total
100%
 
100%
 
100%

Missouri state law provides for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. Laclede Gas established Voluntary Employees’ Beneficiary Association and Rabbi trusts as its external funding mechanisms. Laclede Gas’ investment policy seeks to maximize investment returns consistent with Laclede Gas’ tolerance for risk. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with policy. Performance and compliance with the guidelines is regularly monitored. Laclede Gas’ current investment policy targets an asset allocation of 60% to equity securities and 40% to debt securities, excluding cash held in short-term debt securities for the purpose of making benefit payments. Laclede Gas currently invests in a mutual fund which is rebalanced on an ongoing basis to the target allocation. The mutual fund is diversified across U.S. stock and bond markets.


Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:

 
 
(Millions)
 
Benefits Paid
from
Qualified Trust
  
Benefits Paid
from Laclede Gas
Funds
 
                         
 
2011
   
$
5.0
     
$
0.3
   
 
2012
     
5.3
       
0.3
   
 
2013
     
5.5
       
0.3
   
 
2014
     
5.9
       
0.3
   
 
2015
     
6.4
       
0.3
   
 
2016 – 2020
     
45.7
       
1.9
   

Laclede Gas’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Contributions to the postretirement plans in fiscal year 2011 are anticipated to be $13.3 million to the qualified trusts, and $0.3 million paid directly to participants from Laclede Gas funds.

Other Plans

Laclede Gas sponsors 401(k) plans that cover substantially all employees. The plans allow employees to contribute a portion of their base pay in accordance with specific guidelines. Laclede Gas provides a match of such contributions within specific limits. The cost of the defined contribution plans of Laclede Gas amounted to $3.6 million, $3.5 million, and $3.1 million for fiscal years 2010, 2009, and 2008, respectively.

Fair Value Measurements of Pension and Other Postretirement Plan Assets

The table below categorizes the fair value measurements of Laclede Gas’ pension plan assets:

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Total
 
 
As of September 30, 2010
                         
 
Cash and cash equivalents
 
$
1,406
 
$
 
$
 
$
1,406
 
 
Debt Securities
                         
 
  U.S. bond mutual funds
   
33,082
   
   
   
33,082
 
 
  U.S. government
   
   
90,993
   
   
90,993
 
 
  U.S. corporate
   
   
90,476
   
   
90,476
 
 
  U.S. municipal
   
   
6,241
   
   
6,241
 
 
  International
   
   
18,676
   
   
18,676
 
 
Derivative instruments (a)
   
   
9
   
   
9
 
 
Other
   
   
39
   
   
39
 
 
          Total
 
$
34,488
 
$
206,434
 
$
 
$
240,922
 
 
 
(a)
Derivative assets of $10,399 net of cash margin payable of $10,390.



The table below categorizes the fair value measurements of Laclede Gas’ postretirement plan assets:

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Total
 
 
As of September 30, 2010
                         
 
Cash and cash equivalents
 
$
1,021
 
$
 
$
 
$
1,021
 
 
U.S. stock/bond mutual fund
   
44,069
   
   
   
44,069
 
 
          Total
 
$
45,090
 
$
 
$
 
$
45,090
 

Cash and cash equivalents include money market mutual funds valued based on quoted market prices. Fair values of derivative instruments are calculated by investment managers who use valuation models that incorporate observable market inputs. Debt securities are valued based on broker/dealer quotations or by using observable market inputs. The stock and bond mutual funds are valued at the quoted market price of the identical securities.

4.
STOCK-BASED COMPENSATION

The Laclede Group 2006 Equity Incentive Plan (the 2006 Plan) was approved at the annual meeting of shareholders of Laclede Group on January 26, 2006. The purpose of the 2006 Plan is to encourage officers and employees of the Company and its subsidiaries to contribute to the Company’s success and align their interests with that of shareholders. To accomplish this purpose, the Compensation Committee (Committee) of the Board of Directors may grant awards under the 2006 Plan that may be earned by achieving performance objectives and/or other criteria as determined by the Committee. Under the terms of the 2006 Plan, officers and employees of the Company and its subsidiaries, as determined by the Committee, are eligible to be selected for awards. The 2006 Plan provides for restricted stock, restricted stock units, qualified and non-qualified stock options, stock appreciation rights, and performance shares payable in stock, cash, or a combination of both. The 2006 Plan generally provides a minimum vesting period of at least three years for each type of award. The maximum number of shares reserved for issuance under the 2006 Plan is 1,250,000. The 2006 Plan replaced the Laclede Group Equity Incentive Plan (the 2003 Plan). Shares reserved under the 2003 Plan, other than those needed for currently outstanding awards, were canceled upon shareholder approval of the 2006 Plan.
The Company’s Restricted Stock Plan for Non-Employee Directors (Plan) was amended and approved by shareholders in January 2009. The principal purpose of the Plan is to attract and retain qualified persons who are not employees or former employees of the Company or any of its subsidiaries for service as members of the Board of Directors and to encourage ownership in the Company by such non-employee directors by granting shares of common stock subject to restrictions. Shares vest depending on the participant’s age upon entering the Plan and years of service as a director. The total number of shares of common stock that may be issued under the Restricted Stock Plan for Non-Employee Directors is 150,000.
The Company issues new shares to satisfy employee restricted stock awards and stock option exercises. Shares for non-employee directors are purchased on the open market.

Restricted Stock Awards

During fiscal year 2010, the Company granted 95,400 performance-contingent restricted shares and share units to executive officers and key employees at a weighted average grant date fair value of $25.41 per share. This number represents the maximum shares that can be earned pursuant to the terms of the awards. The shares and share units have a performance period ending September 30, 2012, during which participants are entitled to voting rights on the target level, or 63,600 shares. Dividends on these target level of shares accrue during the performance period and will be paid to the participants up to the target level upon vesting, but are subject to forfeiture if the underlying shares do not vest. The number of shares and share units that will ultimately vest is dependent upon the attainment of certain levels of earnings growth and portfolio development performance goals; further, under the terms of the award, the Compensation Committee of the Board of Directors has the discretion to reduce by up to 25% the number that vest if the Company’s total shareholder return (TSR) during the performance period ranks below the median relative to a comparator group of companies. This TSR provision is considered a market condition under generally accepted accounting principles and is discussed further below.
The weighted average grant date fair value of performance-contingent restricted stock granted during fiscal years 2009 and 2008 was $47.17 and $29.99, respectively.


During fiscal year 2010, 58,250 shares of performance-contingent restricted stock, awarded on November 2, 2006 and December 5, 2007, vested. The Company withheld 18,899 of the vested shares at a weighted average price of $30.49 per share pursuant to elections by employees to satisfy tax withholding obligations. During fiscal year 2009, 43,000 shares of performance-contingent restricted stock, awarded on November 2, 2005, vested. The Company withheld 12,615 of these vested shares at a weighted average price of $53.48 per share pursuant to elections by employees to satisfy tax withholding obligations.
Performance-contingent restricted stock and performance-contingent restricted stock unit activity for fiscal year 2010 is presented below:

           
Weighted
           
Average
     
Shares/
   
Grant Date
     
Units
   
Fair Value
                   
 
Nonvested at September 30, 2009
 
225,950
     
$
37.85
 
                   
 
Granted (maximum shares that can be earned)
 
95,400
     
$
25.41
 
 
Vested
 
(58,250
)
   
$
34.75
 
 
Forfeited
 
(7,800
)
   
$
32.67
 
                   
 
Nonvested at September 30, 2010
 
255,300
     
$
34.07
 

During fiscal year 2010, the Company granted 29,500 shares of time-vested restricted stock to executive officers and key employees at a weighted average grant date fair value of $30.55 per share. These shares were awarded on November 4, 2009, December 1, 2009, January 4, 2010, May 3, 2010, and July 1, 2010 and vest November 4, 2012, December 1, 2012, January 4, 2013, May 3, 2013, and July 1, 2013, respectively. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture. The weighted average grant date fair value of time-vested restricted stock and restricted stock units awarded to employees during fiscal year 2009 and 2008 was $50.55 and $31.99 per share, respectively.
During fiscal year 2010, the Company granted 12,500 shares of time-vested restricted stock to non-employee directors at a weighted average grant date fair value of $32.32 per share. The weighted average grant date fair value of restricted stock awarded to non-employee directors during fiscal years 2009 and 2008 was $46.52 and $33.77 per share, respectively. These shares vest depending on the participant’s age upon entering the plan and years of service as a director. The plan’s trustee acquires the shares for the awards in the open market and holds the shares as trustee for the benefit of the non-employee directors until the restrictions expire. In the interim, the participants receive full dividends and voting rights.
Time-vested restricted stock and time-vested restricted stock unit activity for fiscal year 2010 is presented below:

           
Weighted
           
Average
     
Shares/
   
Grant Date
     
Units
   
Fair Value
                   
 
Nonvested at September 30, 2009
 
90,150
     
$
39.08
 
                   
 
Granted
 
42,000
     
$
31.08
 
 
Vested
 
(7,000
)
   
$
34.18
 
 
Forfeited
 
(3,300
)
   
$
38.49
 
                   
 
Nonvested at September 30, 2010
 
121,850
     
$
36.62
 

The total fair value of restricted stock (performance-contingent and time-vested) vested during fiscal years 2010, 2009, and 2008 was $2.0 million, $2.6 million, and $0.1 million, respectively, and the related actual tax benefit realized was $0.8 million, $1.0 million, and $38,000, respectively.



Stock Option Awards

No stock options were granted during fiscal years 2010, 2009, and 2008. Stock option activity for fiscal year 2010 is presented below:

                 
Weighted
       
                 
Average
       
           
Weighted
   
Remaining
   
Aggregate
 
           
Average
   
Contractual
   
Intrinsic
 
     
Stock
   
Exercise
   
Term
   
Value
 
     
Options
   
Price
   
(Years)
   
($000)
 
                               
 
Outstanding at September 30, 2009
 
356,225
   
$
30.84
               
                               
 
Granted
 
   
$
               
 
Exercised
 
(12,500
)
 
$
30.70
               
 
Forfeited
 
(2,125
)
 
$
34.95
               
 
Expired
 
(5,625
)
 
$
34.95
               
                               
 
Outstanding at September 30, 2010
 
335,975
   
$
30.75
   
4.3
   
$
1,271
 
                               
 
Fully Vested and Expected to Vest
  at September 30, 2010
 
334,347
   
$
30.73
   
4.3
   
$
1,271
 
                               
 
Exercisable at September 30, 2010
 
312,725
   
$
30.44
   
4.2
   
$
1,271
 

Exercise prices of options outstanding at September 30, 2010 range from $23.27 to $34.95. During fiscal year 2010, cash received from the exercise of stock options was $0.4 million, the intrinsic value of the options exercised was $34,000 and the related actual tax benefit realized was $13,000. During fiscal year 2009, cash received from the exercise of stock options was $1.7 million, the intrinsic value of the options exercised was $0.9 million and the related actual tax benefit realized was $0.4 million. During fiscal year 2008, cash received from the exercise of stock options was $5.0 million, the intrinsic value of the options exercised was $2.0 million and the related actual tax benefit realized was $0.8 million.
The closing price of the Company’s common stock was $34.42 at September 30, 2010.



Equity Compensation Costs

Compensation cost for performance-contingent restricted stock awards is based upon the probable outcome of the performance conditions. For shares that do not vest or are not expected to vest due to the outcome of the performance conditions, no compensation cost is recognized and any previously recognized compensation cost is reversed.
The fair value of awards of performance-contingent and time-vested restricted stock and restricted stock units, not subject to the TSR provision, is estimated using the closing price of the Company’s stock on the date of the grant. For those awards that do not pay dividends during the vesting period, the estimate of fair value is reduced by the present value of the dividends expected to be paid on the Company’s common stock during the performance period, discounted using an appropriate U.S. Treasury yield. For shares subject to the TSR provision, the estimated impact of this market condition is reflected in the grant date fair value per share of the awards. Accordingly, compensation cost is not reversed to reflect any actual reductions in the awards that may result from the TSR provision. However, if the Company’s TSR during the performance period ranks below the level specified in the award agreements, relative to a comparator group of companies, and the Committee elects not to reduce the award (or reduce by a lesser amount), this election would be accounted for as a modification of the original award and additional compensation cost would be recognized at that time. The grant date fair value per share of the awards subject to the TSR provision awarded during fiscal years 2010, 2009, and 2008 was valued by a Monte Carlo simulation model that assessed the probabilities of various TSR outcomes. The significant assumptions used in the Monte Carlo simulations are as follows:

   
2010
 
2009
 
2008
 
               
 
Risk free interest rate
1.40%
 
1.61%
 
2.89%
 
 
Expected dividend yield of stock
 
 
 
 
Expected volatility of stock
35.3%
 
31.8%
 
24.96%
 
 
Vesting period
2.9 years
 
2.9 years
 
2.8 years
 

The risk free interest rate was based on the yield on U.S. Treasury securities matching the vesting period. The expected volatility is based on the historical volatility of the Company’s stock. Volatility assumptions were also made for each of the companies included in the comparator group. The vesting period is equal to the performance period set forth in the terms of the award.

The amounts of compensation cost recognized for share-based compensation arrangements are presented below:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Total equity compensation cost
 
$
3,795
 
$
3,990
 
$
2,651
 
 
Compensation cost capitalized
   
(798
)
 
(815
)
 
(578
)
 
Compensation cost recognized in net income
   
2,997
   
3,175
   
2,073
 
 
Income tax benefit recognized in net income
   
(1,156
)
 
(1,225
)
 
(799
)
 
Compensation cost recognized in net income, net of income tax
 
$
1,841
 
$
1,950
 
$
1,274
 

As of September 30, 2010, there was $3.4 million of total unrecognized compensation cost related to nonvested share-based compensation arrangements. That cost is expected to be recognized over a weighted average period of 2.3 years.





5.
EARNINGS PER COMMON SHARE

As mentioned in the New Accounting Pronouncements section of Note 1 , the Company adopted the provisions of FSP No. EITF 03-6-1 effective October 1, 2009. EPS and diluted shares outstanding amounts for fiscal year 2009 and 2008 have been restated to reflect the retrospective application of the FSP. For the fiscal year ended 2009, the effect of adoption reduced total basic and diluted EPS by $0.03 each, compared to originally reported amounts. For fiscal year 2008, the effect of adoption reduced total basic EPS by $0.03 and reduced total diluted EPS by $0.02, compared to originally reported amounts. Reported net income and cash flows were not affected by the adoption of the FSP. For details on the methodology used to compute EPS, see the Earnings Per Common Share section of Note 1 .

 
(Thousands, Except Per Share Amounts)
 
2010
 
2009
 
2008
 
 
Basic EPS:
                   
 
Income from Continuing Operations
 
$
54,040
 
$
64,247
 
$
57,526
 
 
  Less: Income allocated to participating securities
   
529
   
699
   
477
 
 
Income from Continuing Operations Available
  to Common Shareholders
 
$
53,511
 
$
63,548
 
$
57,049
 
                       
 
Weighted Average Shares Outstanding
   
21,986
   
21,893
   
21,657
 
 
Earnings Per Share of Common Stock from
                   
 
  Continuing Operations
 
$
2.43
 
$
2.90
 
$
2.64
 
                       
 
Diluted EPS:
                   
 
Income from Continuing Operations
 
$
54,040
 
$
64,247
 
$
57,526
 
 
  Less: Income allocated to participating securities
   
528
   
698
   
476
 
 
Income from Continuing Operations Available
  to Common Shareholders
 
$
53,512
 
$
63,549
 
$
57,050
 
                       
 
Weighted Average Shares Outstanding
   
21,986
   
21,893
   
21,657
 
 
Dilutive Effect of Stock Options
                   
 
and Restricted Stock
   
53
   
67
   
73
 
 
Weighted Average Diluted Shares
   
22,039
   
21,960
   
21,730
 
                       
 
Earnings Per Share of Common Stock from
                   
 
  Continuing Operations
 
$
2.43
 
$
2.89
 
$
2.63
 
                       
 
Outstanding Shares Excluded from the
                   
 
Calculation of Diluted EPS Attributable to:
                   
 
Antidilutive stock options
   
75
   
   
 
 
Performance-contingent restricted stock
   
123
   
57
   
30
 
 
Total
   
198
   
57
   
30
 





Total shares of common stock outstanding were 22.29 million and 22.17 million at September 30, 2010 and 2009, respectively.
Common stock and paid-in capital increased $4.6 million in fiscal year 2010. The issuance of 42,733 common shares under the Dividend Reinvestment and Stock Purchase Plan increased common stock and paid-in capital by $1.4 million. The remaining $3.2 million increase was primarily due to stock-based compensation costs and the issuance of 81,951 shares of common stock under the Equity Incentive Plan. Common stock and paid-in capital increased $7.2 million in fiscal year 2009. The issuance of 47,037 common shares under the Dividend Reinvestment and Stock Purchase Plan increased common stock and paid-in capital by $2.0 million. The remaining $5.2 million increase was primarily due to stock-based compensation costs and the issuance of 127,610 shares of common stock under the Equity Incentive Plan.
On August 23, 2001, Laclede Group declared a dividend of one preferred share purchase right for each outstanding share of common stock. Each preferred share purchase right entitles the registered holder to purchase from Laclede Group one one-hundredth of Series A junior participating preferred stock for a purchase price of $90, subject to adjustment. The value of one one-hundredth of a preferred share purchasable upon the exercise of each right should, because of the nature of the preferred shares’ dividend, liquidation, and voting rights, approximate the value of one common share. The rights expire on October 1, 2011 and may be redeemed by Laclede Group for one cent each at any time before they become exercisable. The rights will not be exercisable or transferable apart from the common stock until ten business days after (i) public announcement that a person or group has acquired beneficial ownership of 20% or more of the common stock, or (ii) commencement of, or announcement of an intention to make, a tender or exchange offer for beneficial ownership of 20% or more of the common stock. Following such an event, a right will entitle its holder to purchase, for the purchase price, the number of shares equal to the purchase price divided by one-half of the market price. Alternatively, Laclede Group may exchange each right for one one-hundredth of a preferred share. The number of rights outstanding is the same as the number of shares of common stock outstanding on any date prior to rights becoming exercisable or transferable apart from the common stock.
Substantially all of the utility plant of Laclede Gas is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock. These provisions are applicable regardless of whether the stock is publicly held or, as has been the case since the formation of Laclede Group, held solely by the Utility’s parent company. Under the most restrictive of these provisions, no cash dividend may be declared or paid if, after the dividend, the aggregate net amount spent for all dividends after September 30, 1953, would exceed a maximum amount determined by a formula set out in the mortgage. Under that formula, the maximum amount is the sum of $8 million plus earnings applicable to common stock (adjusted for stock repurchases and issuances) for the period from September 30, 1953, to the last day of the quarter before the declaration or payment date for the dividends. As of September 30, 2010 and 2009, the amount under the mortgage’s formula that was available to pay dividends was $280 million and $274 million, respectively. Thus, all of the Utility’s retained earnings were free from such restrictions as of those dates.
Laclede Group has on file a shelf registration on Form S-3 with the SEC that allows for the issuance of equity securities and debt securities. No securities have been issued under this registration statement, which expires November 26, 2011. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions. In addition, Laclede Group has a registration statement on file on Form S-3 for the issuance and sale of up to 400,000 shares of its common stock under its Dividend Reinvestment and Stock Purchase Program. There were 327,781 shares and 317,186 shares at September 30, 2010 and November 19, 2010, respectively, remaining available for issuance under this Form S-3.
Laclede Gas has on file with the SEC an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, all of which remains available to Laclede Gas at this time. The Utility has authority from the MoPSC until June 30, 2013 to issue up to $518 million in debt securities and preferred stock, including on a private placement basis, as well as to enter into capital leases, issue common stock and receive paid-in capital, of which $517.6 million remained under this authorization as of September 30, 2010. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions.



The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the
Consolidated Balance Sheets at September 30 were as follows:

 
(Thousands)
 
 
Net Unrealized Gains (Losses) on Cash Flow Hedges
Defined Benefit Pension and Other
Postretirement
Benefit Plans
Total
 
 
Balance, September 30, 2008
   
$
6,227
   
$
(1,790
)
 
$
4,437
 
 
Current-period change
     
(5,695
)
   
(939
)
   
(6,634
)
 
Adoption of SFAS No. 158, as codified in
  ASC Topic 715
     
     
31
     
31
 
 
Balance, September 30, 2009
     
532
     
(2,698
)
   
(2,166
)
 
Current-period change
     
(4,779
)
   
(192
)
   
(4,971
)
 
Balance, September 30, 2010
   
$
(4,247
)
 
$
(2,890
)
 
$
(7,137
)

Income tax expense (benefit) recorded for items of other comprehensive income reported in the Statements of Consolidated Comprehensive Income is calculated by applying statutory federal, state, and local income tax rates applicable to ordinary income. The tax rates applied to individual items of other comprehensive income are similar within each reporting period.


7.

Maturities on long-term debt for the five fiscal years subsequent to September 30, 2010 are as follows:

 
2011
$25 million
  (Paid at maturity on November 15, 2010)
 
2012
 
 
2013
$25 million
 
 
2014
 
 
2015
 

At September 30, 2010, Laclede Gas had fixed-rate long-term debt totaling $390 million (including current maturities). While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. Of the Utility’s $390 million in long-term debt, $75 million have no call options, $235 million have make-whole call options, and $80 million are callable at par in 2013. None of the debt has any put options.
Laclede Gas has on file with the SEC an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, all of which remains available to Laclede Gas at this time. The Utility has authority from the MoPSC until June 30, 2013 to issue up to $518 million in debt securities and preferred stock, including on a private placement basis, as well as to enter into capital leases, issue common stock and receive paid-in capital, of which $517.6 million remained under this authorization as of September 30, 2010. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions.
Substantially all of the utility plant of Laclede Gas is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock, which are described more fully in Note 6 , Stockholders’ Equity.
At September 30, 2010 and 2009, Laclede Gas had preferred stock shares authorized totaling 1,480,000, but none were issued and outstanding.




8.
NOTES PAYABLE AND CREDIT AGREEMENTS

The Company’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. Laclede Gas has a syndicated line of credit in place of $320 million from 10 banks, with the largest portion provided by a single bank being 17.5%. This line expires in December 2011. During fiscal year 2010, Laclede Gas utilized only commercial paper for external short-term funding. Commercial paper borrowings ranged between $48.2 million and $178.0 million during the fiscal year, and stood at $129.7 million on September 30, 2010. The weighted average interest rate on the short-term borrowings was 0.3% per annum at September 30, 2010. For the entire fiscal year, short-term borrowings averaged $107.9 million at an average interest rate of 0.3%. Laclede Gas borrowed a maximum of $1.2 million from Laclede Group during the fiscal year, and there were no such borrowings outstanding at the end of the fiscal year.
During fiscal year 2009, the Utility’s short-term borrowing requirements, which ranged between $116.9 million and $386.4 million, were generally met by the sale of commercial paper. However, due to unfavorable terms in the commercial paper markets generally in the first half of fiscal year 2009, Laclede Gas utilized its line of credit and borrowing from Laclede Group as more economical sources of short-term financing. External borrowings (which exclude borrowings from Laclede Group) ranged between $116.9 million and $309.9 million. The Utility had $129.8 million in commercial paper outstanding as of September 30, 2009, at a weighted average interest rate of 0.2% per annum, and no borrowings under its bank line or from Laclede Group.
Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation, and amortization (EBITDA) to be at least 2.25 times interest expense. On September 30, 2010, total debt was 56% of total capitalization . For the fiscal year ended September 30, 2010, EBITDA was 4.55 times interest expense.
Short-term cash requirements outside of Laclede Gas have generally been met with internally-generated funds. However, Laclede Group has $50 million in working-capital lines of credit, which expire in September 2011, to meet short-term liquidity needs of its subsidiaries. These lines of credit have covenants limiting the total debt of the consolidated Laclede Group to no more than 70% of the Company’s total capitalization. This ratio stood at 49% on September 30, 2010. These lines have been used to provide for seasonal funding needs of various subsidiaries from time to time. There were no borrowings under Laclede Group’s lines during the fiscal year.


9.
FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts and estimated fair values of financial instruments at September 30, 2010 and 2009 are as follows:

 
 
(Thousands)
 
Carrying
Amount
 
Fair
Value
 
                 
 
2010:
             
 
Cash and cash equivalents
 
$
86,919
 
$
86,919
 
 
Marketable securities
   
12,856
   
12,856
 
 
Derivative instrument assets
   
12,761
   
12,761
 
 
Derivative instrument liabilities
   
14
   
14
 
 
Short-term debt
   
129,650
   
129,650
 
 
Long-term debt, including current portion
   
389,298
   
443,959
 
                 
 
2009:
             
 
Cash and cash equivalents
 
$
74,591
 
$
74,591
 
 
Marketable securities
   
11,110
   
11,110
 
 
Derivative instrument assets
   
17,178
   
17,178
 
 
Derivative instrument liabilities
   
976
   
976
 
 
Short-term debt
   
129,800
   
129,800
 
 
Long-term debt
   
389,240
   
423,375
 

The carrying amounts for cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. The fair values of marketable securities, derivative instruments assets, and derivative instrument liabilities are valued as described in Note 10 , Fair Value Measurements.



10.
FAIR VALUE MEASUREMENTS

The following table categorizes the assets and liabilities in the Consolidated Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Effects of Netting and Cash Margin Receivables
/Payables
   
Total
 
 
As of September 30, 2010
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
12,856
 
$
 
$
 
$
 
$
12,856
 
 
  NYMEX natural gas contracts
   
5,087
   
   
   
7,214
   
12,301
 
 
  NYMEX gasoline and heating
    oil contracts
   
59
   
   
   
220
   
279
 
 
  Natural gas commodity contracts
   
   
161
   
76
   
(56
)
 
181
 
 
        Total
 
$
18,002
 
$
161
 
$
76
 
$
7,378
 
$
25,617
 
                                   
 
Liabilities
                               
 
  NYMEX natural gas contracts
 
$
53,677
 
$
 
$
 
$
(53,677
)
$
 
 
  NYMEX gasoline & heating
    oil contracts
   
37
   
   
   
(37
)
 
 
 
  Natural gas commodity contracts
   
   
17
   
53
   
(56
)
 
14
 
 
        Total
 
$
53,714
 
$
17
 
$
53
 
$
(53,770
)
$
14
 
                                   
 
As of September 30, 2009
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
11,110
 
$
 
$
 
$
 
$
11,110
 
 
  NYMEX natural gas contracts
   
10,803
   
   
   
4,057
   
14,860
 
 
  NYMEX gasoline and heating
    oil contracts
   
278
   
   
   
(1
)
 
277
 
 
  Natural gas commodity contracts
   
   
1,688
   
558
   
(205
)
 
2,041
 
 
        Total
 
$
22,191
 
$
1,688
 
$
558
 
$
3,851
 
$
28,288
 
                                   
 
Liabilities
                               
 
  NYMEX natural gas contracts
 
$
55,170
 
$
 
$
 
$
(55,170
)
$
 
 
  Natural gas commodity contracts
   
   
522
   
659
   
(205
)
 
976
 
 
        Total
 
$
55,170
 
$
522
 
$
659
 
$
(55,375
)
$
976
 

The mutual funds included in Level 1 are valued based on quoted market prices of identical securities that are provided by the trustees of these securities. Derivative instruments included in Level 1 are valued using quoted market prices on the NYMEX. Derivative instruments included in Level 2 are valued using broker or dealer quotation services or by using observable market inputs. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. During fiscal years 2010 and 2009, there were no transfers between the levels of the fair value hierarchy. The Company’s policy is to recognize such transfers, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer. The following is a reconciliation of the Level 3 beginning and ending net derivative balances:

 
(Thousands)
 
2010
 
2009
 
                 
 
Beginning of period
 
$
(101
)
$
 
 
Issuances and settlements - net
   
53
   
(109
)
 
Net gains related to derivatives not held at end of period
   
48
   
 
 
Net gains related to derivatives still held at end of period
   
23
   
8
 
 
End of period
 
$
23
 
$
(101
)




The mutual funds are included in the Other investments line of the Consolidated Balance Sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the Consolidated Balance Sheets when a legally enforceable netting agreement exists between the Company and the counterparty to a derivative contract. For additional information on derivative instruments, see Note 11 , Derivative Instruments and Hedging Activities.


11.
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation and permits the Utility to hedge up to 70% of its normal volumes purchased for up to a 36-month period. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause, through which the MoPSC allows the Utility to recover gas supply costs, subject to prudence review. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. The Utility does not designate these instruments as hedging instruments for financial reporting purposes because gains or losses associated with the use of these derivative instruments are deferred and recorded as regulatory assets or regulatory liabilities pursuant to ASC Topic 980, and, as a result, have no direct impact on the Statements of Consolidated Income. The timing of the operation of the PGA Clause may cause interim variations in short-term cash flows, because the Utility is subject to cash margin requirements associated with changes in the values of these instruments. Nevertheless, carrying costs associated with such requirements are recovered through the PGA Clause.
From time to time, Laclede Gas purchases NYMEX futures contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At September 30, 2010, Laclede Gas held 0.6 million gallons of gasoline futures contracts at an average price of $2.10 per gallon and 0.1 million gallons of heating oil futures contracts (to hedge diesel fuel purchases) at an average price of $2.33 per gallon. Most of these futures contracts, the longest of which extends to September 2011, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815. The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.
In the course of its business, Laclede Group’s non-regulated gas marketing subsidiary, LER, enters into commitments associated with the purchase or sale of natural gas. Many of LER’s derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815 and are accounted for as executory contracts on an accrual basis. Any of LER’s derivative natural gas contracts that are not designated as normal purchases or normal sales are accounted for at fair value. At September 30, 2010, the fair values of 6.8 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet. All of these contracts will settle during fiscal year 2011. These contracts have not been designated as hedges; therefore, changes in the fair value of these contracts are reported in earnings each period. Furthermore, LER manages the price risk associated with its fixed-priced commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of NYMEX futures contracts to lock in margins. At September 30, 2010, LER’s unmatched fixed-price positions were not material to Laclede Group’s financial position or results of operations. LER’s NYMEX natural gas futures contracts used to lock in margins are generally designated as cash flow hedges of forecasted transactions for financial reporting purposes.
Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the Consolidated Balance Sheets at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income (OCI). Accumulated other comprehensive income (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at September 30, 2010, it is expected that approximately $3.8 million of pretax losses will be reclassified into the Statements of Consolidated Income during fiscal year 2011. The net amount of pre-tax (losses) gains recognized in earnings for the ineffective portion of cash flow hedges was $(1.0) million, $2.9 million, and $(2.8) million for fiscal years 2010, 2009, and 2008, respectively. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the Statements of Consolidated Cash Flows.


The Company’s exchange-traded/cleared derivative instruments consist primarily of NYMEX positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. NYMEX-traded contracts are supported by the financial and credit quality of the clearing members of the NYMEX and have nominal credit risk. Open NYMEX natural gas futures positions at September 30, 2010 were as follows:

     
Laclede Gas Company
 
Laclede Energy
Resources, Inc.
 
     
MMBtu
(millions)
 
Avg. Price
Per
MMBtu
 
MMBtu
(millions)
 
Avg. Price
Per
MMBtu
 
 
Open short futures positions
                         
 
    Fiscal 2011
 
 
$
   
4.35
 
$
4.84
   
                             
 
Open long futures positions
                         
 
    Fiscal 2011
 
13.16
 
$
6.19
   
6.66
 
$
5.74
   
 
    Fiscal 2012
 
4.94
   
5.47
   
2.18
   
6.43
   
 
    Fiscal 2013
 
   
   
0.06
   
5.41
   

At September 30, 2010, Laclede Gas also had 23.9 million MMBtu of other price risk mitigation measures in place through the use of NYMEX natural gas option-based strategies.



The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income
 
                           
   
Location of Gain (Loss)
                     
(Thousands)
 
Recorded in Income
     
2010
       
2009 (a)
   
Derivatives in Cash Flow Hedging Relationships
                         
                           
  Effective portion of gain (loss) recognized in
    OCI on derivatives:
                         
       NYMEX natural gas contracts
       
$
5,099
     
$
3,733
   
       NYMEX gasoline and heating oil contracts
         
160
       
248
   
          Total
       
$
5,259
     
$
3,981
   
                           
  Effective portion of gain (loss) reclassified from
    AOCI to income:
                         
       NYMEX natural gas contracts
 
Non-Regulated Gas Marketing Operating Revenues
   
$
15,632
     
$
12,997
   
   
Non-Regulated Gas Marketing Operating Expenses
     
(2,851
)
     
(6,117
)
 
               Sub-total
         
12,781
       
6,880
   
                           
       NYMEX gasoline and heating oil contracts
 
Other Regulated Gas Distribution Operating Expenses
     
264
       
119
   
          Total
       
$
13,045
     
$
6,999
   
                           
  Ineffective portion of gain (loss) on derivatives
    recognized in income:
                         
       NYMEX natural gas contracts
 
Non-Regulated Gas Marketing Operating Revenues
   
$
1,338
     
$
745
   
   
Non-Regulated Gas Marketing Operating Expenses
     
(2,305
)
     
(258
)
 
               Sub-total
         
(967
)
     
487
   
                           
       NYMEX gasoline and heating oil contracts
 
Other Regulated Gas Distribution Operating Expenses
     
(57
)
     
198
   
          Total
       
$
(1,024
)
   
$
685
   
                           
Derivatives Not Designated as Hedging Instruments (b)
                     
                           
  Gain (loss) recognized in income on derivatives:
                         
                           
       Natural gas commodity contracts
 
Non-Regulated Gas Marketing Operating Revenues
   
$
4,269
     
$
1,785
   
   
Non-Regulated Gas Marketing Operating Expenses
     
(3,435
)
     
(46
)
 
       NYMEX natural gas contracts
 
Non-Regulated Gas Marketing Operating Revenues
     
(11
)
     
   
   
Non-Regulated Gas Marketing Operating Expenses
     
(552
)
     
824
   
       NYMEX gasoline and heating oil contracts
 
Other Income and (Income Deductions) - Net
     
(1
)
     
17
   
          Total
       
$
270
     
$
2,580
   

(a)
The Company prospectively adopted SFAS No. 161, as codified in ASC Topic 815, in the second quarter of fiscal year 2009. Accordingly, amounts disclosed in this column exclude activity prior to January 1, 2009.
(b)
Gains and losses on Laclede Gas’ NYMEX natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Utility’s PGA Clause and recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Consolidated Income.



Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2010
 
           
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair Value
*
Balance Sheet Location
 
Fair Value
*
Derivatives designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
$
3,174
 
Derivative Instrument Assets
$
9,705
 
   
Other Deferred Charges
 
4
 
Other Deferred Charges
 
3,435
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
56
 
Derivative Instrument Assets
 
34
 
        Sub-total
     
3,234
     
13,174
 
                   
Derivatives not designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
 
1,401
 
Derivative Instrument Assets
 
37,457
 
   
Other Deferred Charges
 
508
 
Other Deferred Charges
 
3,080
 
  Natural gas commodity contracts
 
Derivative Instrument Assets
 
237
 
Other Current Liabilities
 
14
 
   
Other Current Liabilities
 
 
Derivative Instrument Assets
 
56
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
3
 
Derivative Instrument Assets
 
3
 
        Sub-total
     
2,149
     
40,610
 
  Total derivatives
   
$
5,383
   
$
53,784
 
                   
Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2009
 
                   
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair Value
*
Balance Sheet Location
 
Fair Value
*
Derivatives designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
$
3,001
 
Derivative Instrument Assets
$
2,019
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
278
 
Derivative Instrument Assets
 
 
        Sub-total
     
3,279
     
2,019
 
                   
Derivatives not designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
 
7,802
 
Derivative Instrument Assets
 
53,151
 
  Natural gas commodity contracts
 
Derivative Instrument Assets
 
2,062
 
Other Current Liabilities
 
1,160
 
   
Other Current Liabilities
 
184
 
Derivative Instrument Assets
 
21
 
        Sub-total
     
10,048
     
54,332
 
  Total derivatives
   
$
13,327
   
$
56,351
 

*
The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Consolidated Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 10 , Fair Value Measurements, for information on the valuation of derivative instruments.



Following is a reconciliation of the amounts in the tables above to the amounts presented in the Consolidated Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Fair value of asset derivatives presented above
 
$
5,383
 
$
13,327
 
 
Fair value of cash margin receivables
   
61,148
   
59,226
 
 
Netting of assets and liabilities with the same counterparty
   
(53,770
)
 
(55,375
)
 
    Total
 
$
12,761
 
$
17,178
 
                 
 
Derivative Instrument Assets, per Consolidated Balance Sheets:
             
 
  Derivative instrument assets
 
$
10,285
 
$
17,178
 
 
  Other deferred charges
   
2,476
   
 
 
    Total
 
$
12,761
 
$
17,178
 
                 
 
Fair value of liability derivatives presented above
 
$
53,784
 
$
56,351
 
 
Netting of assets and liabilities with the same counterparty
   
(53,770
)
 
(55,375
)
 
  Derivative instrument liabilities, per Consolidated Balance Sheets*
 
$
14
 
$
976
 
                 
*
Included in the Other line of the Current Liabilities section
             


12.
CONCENTRATIONS OF CREDIT RISK

A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of transactions with these counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, LER has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, LER may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, LER may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry from which LER both sells and purchases natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. To date, losses have not been significant. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in accounts receivable attributable to energy producers and their marketing affiliates amounted to $19.4 million, or 35.1% of LER’s total accounts receivable at September 30, 2010. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $7.4 million. Accounts receivable attributable to utility companies and their marketing affiliates comprised $19.4 million of LER’s total accounts receivable, or 35.1% at September 30, 2010, while net receivable amounts from these customers, reflecting netting arrangements, were $15.2 million. LER also has concentrations of credit risk with certain individually significant counterparties. At September 30, 2010, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure), all of which are investment-grade rated companies, were $18.7 million, or 34.0% of LER’s total accounts receivable. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $12.7 million. Additionally, LER has concentrations of credit risk with pipeline companies associated with its natural gas receivable amounts.



13.
INCOME TAXES

The net provisions for income taxes from continuing operations charged during the fiscal years ended September 30, 2010, 2009, and 2008 are as follows:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Included in Statements of Consolidated Income:
                   
 
  Federal
                   
 
    Current
 
$
(4,796
)
$
12,614
 
$
17,584
 
 
    Deferred
   
28,304
   
15,454
   
5,097
 
 
    Investment tax credits
   
(216
)
 
(219
)
 
(227
)
 
  State and local
                   
 
    Current
   
(867
)
 
1,958
   
2,743
 
 
    Deferred
   
4,669
   
2,702
   
993
 
 
Total Income Tax Expense from Continuing Operations
 
$
27,094
 
$
32,509
 
$
26,190
 

For the year ended September 30, 2008, the Company recorded current income tax expense totaling $14.6 million and deferred income tax benefits totaling $77,000 related to discontinued operations.
The effective income tax rate varied from the federal statutory income tax rate for continuing operations for each year due to the following:

     
2010
 
2009
 
2008
 
                       
 
Federal income tax statutory rate
   
35.0
 %
 
35.0
 %
 
35.0
 %
 
State and local income taxes, net of federal
                   
 
  income tax benefits
   
3.0
   
3.1
   
2.9
 
 
Certain expenses capitalized on books and
                   
 
  deducted on tax return
   
(4.0
)
 
(2.9
)
 
(3.5
)
 
Taxes related to prior years
   
0.1
   
(0.6
)
 
(1.0
)
 
Other items – net
   
(0.7
)
 
(1.0
)
 
(2.1
)
 
Effective income tax rate
   
33.4
 %
 
33.6
 %
 
31.3
 %

The significant items comprising the net deferred tax liability recognized in the Consolidated Balance Sheets as of September 30 are as follows:

 
(Thousands)
 
2010
 
2009
 
                 
 
Deferred tax assets:
             
 
  Reserves not currently deductible
 
$
18,808
 
$
19,418
 
 
  Pension and other postretirement benefits
   
78,790
   
80,508
 
 
  Unamortized investment tax credits
   
2,222
   
2,358
 
 
  Other
   
11,723
   
13,067
 
 
      Total deferred tax assets
   
111,543
   
115,351
 
                 
 
Deferred tax liabilities:
             
 
  Relating to property
   
256,038
 
$
221,532
 
 
  Regulatory pension and other postretirement benefits
   
110,396
   
109,041
 
 
  Deferred gas costs
   
22,126
   
16,609
 
 
  Other
   
15,529
   
22,658
 
 
      Total deferred tax liabilities
   
404,089
   
369,840
 
                 
 
Net deferred tax liability
   
292,546
   
254,489
 
 
Net deferred tax asset (liability) – current
   
(155
)
 
1,707
 
 
Net deferred tax liability – non-current
 
$
292,391
 
$
256,196
 




Pursuant to GAAP, the Company may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Company records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are included in the Other line of the Deferred Credits and Other Liabilities section of the Consolidated Balance Sheets.
The following table presents a reconciliation of the beginning and ending balances of unrecognized tax benefits at September 30 as reported in the Consolidated Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Unrecognized tax benefits, beginning of year
 
$
1,366
 
$
1,033
 
 
Increases related to tax positions taken in current year
   
5,017
   
333
 
 
Unrecognized tax benefits, end of year
 
$
6,383
 
$
1,366
 

The amount of unrecognized tax benefits which, if recognized, would affect the Company’s effective tax rate were $1.7 million and $1.4 million as of September 30, 2010 and 2009, respectively. It is reasonably possible that events will occur in the next 12 months that could increase or decrease the amount of the Company’s unrecognized tax benefits. The Company does not expect any such change will be significant.
Interest accrued associated with the Company’s uncertain tax positions as of September 30, 2010 and 2009 were $0.3 million and $0.1 million, respectively, and no penalties were accrued as of those dates. Interest expense accrued during fiscal year 2010 was $0.2 million and immaterial for fiscal years 2009 and 2008. During fiscal year 2008, the Company reversed $0.8 million of accrued interest expense and $0.9 million of accrued penalties in the Statements of Consolidated Income.
The Company is subject to U.S. federal income tax as well as income tax of state and local jurisdictions. The Company is no longer subject to examination for fiscal years prior to 2007.


14.
OTHER INCOME AND (INCOME DEDUCTIONS) – NET

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Interest income
 
$
1,743
 
$
2,972
 
$
4,221
 
 
Net investment gain (loss)
   
1,077
   
(1,019
)
 
(1,299
)
 
Other income
   
276
   
423
   
68
 
 
Other income deductions
   
24
   
(923
)
 
(1,109
)
 
Other Income and (Income Deductions) – Net
 
$
3,120
 
$
1,453
 
$
1,881
 

The increase in Other Income and (Income Deductions) – Net in fiscal year 2010 (compared to fiscal year 2009), was primarily due to higher net investment gains and other minor variations, partially offset by lower income associated with carrying costs applied to under-recoveries of gas costs and lower interest income. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s PGA Clause.
The decrease in Other Income and (Income Deductions) – Net in fiscal year 2009 (compared to fiscal year 2008), was primarily due to lower interest income and the effect of a benefit recognized during fiscal year 2008 from the reversal of certain tax-related expenses. These factors were largely offset by the effect of a loss on the redemption of long-term debt (primarily unamortized issuance costs) recognized during fiscal year 2008 and increased income associated with carrying costs applied to under-recoveries of gas costs.




15.
I NFORMATION BY OPERATING SEGMENT

All of Laclede Group’s subsidiaries are wholly owned. The Regulated Gas Distribution segment consists of the regulated operations of Laclede Gas and is the core business segment of Laclede Group. Laclede Gas is a public utility engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri, with a population of approximately 2.1 million, including the City of St. Louis and parts of ten counties in eastern Missouri. The Non-Regulated Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas and related activities. Other includes Laclede Pipeline Company’s transportation of liquid propane regulated by the FERC as well as non-regulated activities, including real estate development, the compression of natural gas, and financial investments in other enterprises. These operations are conducted through five subsidiaries. Other also includes Laclede Gas’ non-regulated merchandise sales business, which was not material, and its non-regulated propane transaction. The merchandise sales business ceased operations on September 30, 2009. Accounting policies are described in Note 1 . Certain intersegment revenues with Laclede Gas are not eliminated in accordance with the provisions of ASC Topic 980. Those types of transactions include sales of natural gas from Laclede Gas to LER, sales of natural gas from LER to Laclede Gas, and transportation services provided by Laclede Pipeline Company to Laclede Gas. These revenues are shown on the Intersegment revenues lines in the table under Regulated Gas Distribution, Non-Regulated Gas Marketing, and Other columns, respectively.
As Laclede Group’s non-regulated subsidiary, LER, continues to expand its business, the number of transactions accounted for through fair value measurements has increased. Beginning in fiscal year 2010, management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impact of net unrealized gains and losses on energy-related derivative contracts. For comparative purposes, the measurement of segment performance has been presented to conform to the current-period presentation.




         
Non-
             
     
Regulated
 
Regulated
     
Unallocated
     
     
Gas
 
Gas
     
and
     
 
(Thousands)
 
Distribution
 
Marketing
 
Other
 
Eliminations
 
Consolidated
 
                                   
 
FISCAL 2010
                               
 
  Revenues from external customers
 
$
861,435
 
$
835,089
 
$
10,912
 
$
 
$
1,707,436
 
 
Intersegment revenues
   
2,862
   
23,693
   
1,038
   
   
27,593
 
 
Total Operating Revenues
   
864,297
   
858,782
   
11,950
   
   
1,735,029
 
 
Depreciation & amortization
   
37,572
   
*
 
**
 
   
37,572
 
 
Interest income
   
1,493
   
189
   
216
   
(155
)
 
1,743
 
 
Interest charges
   
26,852
   
   
155
   
(155
)
 
26,852
 
 
Income tax expense
   
15,842
   
8,609
   
2,643
   
   
27,094
 
 
Net economic earnings
   
36,141
   
15,709
   
4,315
   
   
56,165
 
 
Total assets
   
1,657,530
   
165,181
   
117,808
   
(100,323
)
 
1,840,196
 
 
Capital expenditures
   
56,234
   
733
   
92
   
(62
)
 
56,997
 
                                   
 
FISCAL 2009
                               
 
  Revenues from external customers
 
$
1,049,288
 
$
804,499
 
$
3,302
 
$
 
$
1,857,089
 
 
Intersegment revenues
   
4,705
   
32,366
   
1,038
   
   
38,109
 
 
Total Operating Revenues
   
1,053,993
   
836,865
   
4,340
   
   
1,895,198
 
 
Depreciation & amortization
   
36,751
   
   
**
 
   
36,751
 
 
Interest income
   
2,505
   
794
   
1,078
   
(1,405
)
 
2,972
 
 
Interest charges
   
30,353
   
   
798
   
(1,405
)
 
29,746
 
 
Income tax expense (benefit)
   
13,856
   
19,186
   
(533
)
 
   
32,509
 
 
Net economic earnings (losses)
   
33,057
   
28,081
   
(332
)
 
   
60,806
 
 
Total assets
   
1,598,600
   
148,248
   
105,237
   
(90,067
)
 
1,762,018
 
 
Capital expenditures
   
51,384
   
820
   
180
   
   
52,384
 
                                   
 
FISCAL 2008
                               
 
  Revenues from external customers
 
$
1,126,826
 
$
1,067,257
 
$
3,803
 
$
 
$
2,197,886
 
 
Intersegment revenues
   
1,461
   
8,588
   
1,038
   
   
11,087
 
 
Total Operating Revenues
   
1,128,287
   
1,075,845
   
4,841
   
   
2,208,973
 
 
Depreciation & amortization
   
35,303
   
   
**
 
   
35,303
 
 
Interest income
   
2,133
   
1,531
   
2,762
   
(2,205
)
 
4,221
 
 
Interest charges
   
30,214
   
(614
)
 
2,222
   
(2,345
)
 
29,477
 
 
Income tax expense (benefit)
   
15,244
   
11,404
   
(291
)
 
(167
)
 
26,190
 
 
Net economic earnings (losses)
   
39,139
   
20,886
   
(607
)
 
(264
)
 
59,154
 
 
Total assets of continuing operations
   
1,624,041
   
182,750
   
138,982
   
(173,118
)
 
1,772,655
 
 
Capital expenditures
   
55,304
   
41
   
25
   
1,251
   
56,621
 
 
 
*
Depreciation & amortization for Non-Regulated Gas Marketing is included in Non-Regulated Gas Marketing Expenses on the Statements of Consolidated Income ($0.1 million for fiscal year 2010).
 
 
**
Depreciation & amortization for Other is included in the Other Operating Expenses on the Statements of Consolidated Income ($0.2 million for fiscal year 2010 and $0.3 million per year for fiscal years 2009 and 2008).
 

 
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income
 
                 
 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Total Net Economic Earnings above
 
$
56,165
 
$
60,806
 
$
59,154
 
 
  Add: Unrealized gain (loss) on energy-related
    derivative contracts, net of tax
   
(2,125
)
 
3,441
   
(1,628
)
 
Income from Continuing Operations
 
$
54,040
 
$
64,247
 
$
57,526
 



16.
COMMITMENTS AND CONTINGENCIES

Commitments

Laclede Gas estimates fiscal year 2011 utility capital expenditures at approximately $64 million. Fiscal year 2011 capital expenditures for non-regulated subsidiaries are estimated at approximately $0.6 million. There are no material contractual commitments at September 30, 2010 related to these estimated capital expenditures.
Laclede Gas and LER have entered into various contracts, expiring on dates through 2017, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at September 30, 2010 are estimated at approximately $908 million. Additional contracts are generally entered into prior to or during the heating season. Laclede Gas estimates that it will pay approximately $86 million annually, at present rate levels, for fixed charges related to these or other contracts that are expected to be in place for the upcoming year for the reservation of gas supplies and pipeline transmission and storage capacity. The Utility recovers its costs from customers in accordance with the PGA Clause.
Laclede Pipeline Company (Pipeline), a wholly-owned subsidiary of Laclede Group, is providing liquid propane transportation service to Laclede Gas pursuant to an approved FERC tariff and a contractual arrangement between Pipeline and Laclede Gas. In accordance with the terms of that agreement, Laclede Gas is obligated to pay Pipeline approximately $1.0 million annually, at current rates. The agreement renews at the end of each contract year, unless terminated by either party upon provision of at least six months’ notice.

Leases and Guarantees

The lease agreement covering the headquarters office space of Laclede Gas extends through February 2015 with the option to renew for up to five additional years. The aggregate rental expense for fiscal years 2010, 2009, and 2008 was $909,000, $900,000, and $891,000, respectively. The annual minimum rental payment for fiscal year 2011 is anticipated to be approximately $917,000 with a maximum annual rental payment escalation of $8,800 per year for each year through fiscal year 2015. Laclede Gas has entered into various operating lease agreements for the rental of vehicles and power operated equipment. The rental costs will be approximately $3.6 million in fiscal year 2011, $2.5 million in fiscal year 2012, $1.5 million in fiscal year 2013, $0.9 million in fiscal year 2014, and $0.2 million in fiscal year 2015. Laclede Gas and LER have other relatively minor rental arrangements that provide for minimum rental payments.
Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2015. At September 30, 2010, the maximum guarantees under these leases are $1.3 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At September 30, 2010, the carrying value of the liability recognized for these guarantees was $0.3 million.
Laclede Group had guarantees totaling $105.3 million for performance and payment of certain wholesale gas supply purchases by LER, as of September 30, 2010. Since that date, total guarantees issued by Laclede Group on behalf of LER increased by $2.3 million bringing the total to $107.6 million in guarantees outstanding at November 19, 2010. No amounts have been recorded for these guarantees in the financial statements. As of September 30, 2010, management believes the probability is low that Laclede Group will be required to make payments under these guarantees.
A consolidated subsidiary is a general partner in an unconsolidated partnership that invests in real estate partnerships. The subsidiary and third parties are jointly and severally liable for the payment of mortgage loans in the aggregate outstanding amount of approximately $2.0 million incurred in connection with various real estate ventures. Laclede Group has no reason to believe that the other principal liable parties will not be able to meet their proportionate share of these obligations. Laclede Group further believes that the asset values of the real estate properties are sufficient to support these mortgage loans.

Contingencies and Indemnifications

Laclede Gas owns and operates natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs.


As with other companies, Laclede Gas faces the risk of environmental liabilities. In the natural gas industry, these are typically associated with sites formerly owned or operated by gas distribution companies like Laclede Gas and/or its predecessor companies at which manufactured gas operations took place. At this time, Laclede Gas has identified three former manufactured gas plant (MGP) sites located in Missouri: one in Shrewsbury and two in the City of St. Louis.
With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, EPA Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs.
The site in the City of St. Louis, which is currently owned by the City, has been enrolled in the Missouri Voluntary Cleanup Program (VCP). The VCP provides potential opportunities to minimize the cost of site cleanup while maximizing possibilities for site development. The City has selected a developer with whom it is negotiating a final site development contract which contemplates remediation and redevelopment of the property. In conjunction with the redevelopment, Laclede Gas and another former site owner have entered into an agreement with the owner and development agencies as well as their parent agency, the private developer of the property, and an environmental consultant (Remediation Agreement). Under the Remediation Agreement, the development agency and the private developer agreed to remediate the site, and Laclede Gas and the other former owner are to be released by the involved City agencies, the private developer, and the environmental consultant from certain liabilities for the past and current environmental condition of the property. Also under that agreement Laclede Gas and the former site owner agreed to pay, at the closing of the transaction, a small percentage of the cost of remediation (subject to a maximum amount). The transactions contemplated by the Remediation Agreement are expected to close during fiscal year 2011. The amount Laclede Gas expects to pay under the Remediation Agreement is not material and will not have a material impact on the future financial condition, results of operations, or cash flows of Laclede Gas or the Company.
The third former MGP site, also located in the City of St. Louis, is not currently and has not been owned by Laclede Gas for many years. At this time, it is not known whether Laclede Gas will incur any costs in connection with environmental investigations of or remediation at the site, and if it does incur any such costs, what the amount of those costs would be.
Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the three MGP sites identified above. In response, the majority of insurers have reserved their rights. While some of the insurers have denied coverage, Laclede Gas continues to discuss potential reimbursements with them, with one insurer making a settlement payment in exchange for a release of claims in June 2007. The Utility’s outside consultant completed an analysis of the MGP sites to determine cost estimates for a one-time contractual transfer of risk from each insurer to the Utility of environmental coverage for the MGP sites. That analysis demonstrated a range of possible future expenditures to investigate, monitor, and remediate these MGP sites from $5.8 million to $36.3 million based upon then currently available facts, technology, and laws and regulations. The actual costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remedial actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and governmental regulations, the ultimate ability of other potentially responsible parties to pay, and any insurance recoveries. Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable.
The amount of costs relative to future remedial actions at these and other sites is unknown and may be material. Laclede Gas anticipates that any costs it may incur in the future to remediate these sites, less any amounts received as insurance proceeds or as contributions from other potentially responsible parties, would be deferred and recovered in rates through periodic adjustments approved by the MoPSC. Accordingly, potential liabilities associated with remediating these sites are not expected to have a material impact on the future financial position and results of operations of Laclede Gas or the Company.
On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, LER. The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. On December 31, 2009, the MoPSC Staff proposed a number of non-monetary recommendations only, based on its review of gas costs for fiscal year 2008. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.


In its December 31, 2007 recommendation relating to fiscal year 2006 gas costs, the MoPSC Staff also raised questions regarding whether certain sales and capacity release transactions subject to the FERC’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Company commenced an internal review of the questions raised by the MoPSC Staff and notified the FERC Staff that it took this action. In June 2008, as a result of the internal review, the Company provided the FERC Staff with a self report regarding compliance of sales and capacity release activities with the FERC’s regulations and policies. On February 9, 2010, the FERC Staff informed the Company that it has closed its investigation of the Company’s self report without taking further action.
In connection with the affiliate transaction matters mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order approving a 2001 Stipulation and Agreement that permitted the Company’s corporate reorganization into a holding company structure. Also, on October 6, 2010, the MoPSC Staff filed a related complaint against Laclede Gas alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. Laclede Gas believes that neither of the complaints have merit and intends to vigorously oppose both of them. In addition, the Company had filed a counterclaim against the MoPSC Staff in the July 7 complaint case alleging that the Staff has failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and the provisions under which the Company allocates costs among affiliated companies. However, on November 3, 2010, the MoPSC issued an order dismissing the Utility’s counterclaim for failure to state a claim upon which relief may be granted.
As reported in Note 2 , Discontinued Operations, during the quarter ended March 31, 2008, the Company sold 100% of its interest in its wholly-owned subsidiary SM&P. The sales agreement (Agreement) includes representations and warranties customary for such transactions, including, among others, representations and warranties of the parties as to brokers’ fees; of SM&P as to its financial status, contracts, title to and condition of personal and real property, taxes, legal compliance, environmental matters, employee benefits, and intellectual property. The Agreement also includes customary indemnification provisions under which Laclede’s aggregate indemnification obligations are limited to a maximum of $7.0 million for most claims. Obligations subject to this maximum apply only in the event claims exceed a stated deductible, both individually and in the aggregate. However, this maximum limitation and deductible do not apply to obligations associated with taxes, employee benefits, title to personal property, and certain other fundamental representations and warranties. A maximum potential future payment amount cannot be estimated for these obligations. The terms of the indemnifications in the Agreement are generally dependent upon the statute of limitations applicable to the particular representations and warranties made by the Company, although certain representations and warranties have an indefinite life under the Agreement. As of September 30, 2010, the carrying amount of the liability recognized for these indemnification obligations was $0.1 million, based on the Company’s assessment of risk, which is believed to be low.
Laclede Group is involved in other litigation, claims, and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the consolidated financial position, results of operations, or cash flows of the Company.




17.
I NTERIM FINANCIAL INFORMATION (UNAUDITED)

In the opinion of Laclede Group, the quarterly information presented below for fiscal years 2010 and 2009 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in consolidated operations reported on a quarterly basis primarily reflect the seasonal nature of the business of Laclede Gas.

(Thousands, Except Per Share Amounts)
                             
Three Months Ended
 
Dec. 31
     
March 31
     
June 30
     
Sept. 30
 
                               
Fiscal Year 2010
                             
Total Operating Revenues
$
491,166
   
$
635,325
   
$
324,507
   
$
284,031
 
Operating Income
 
40,664
     
50,270
     
12,867
     
1,065
 
Net Income (Loss)
 
22,886
     
28,020
     
4,731
     
(1,597
)
Basic Earnings (Loss) Per Share of Common Stock
 
1.03
     
1.26
     
0.21
     
(0.07
)
Diluted Earnings (Loss) Per Share of Common Stock
 
1.03
     
1.26
     
0.21
     
(0.07
)
                               
Three Months Ended
 
Dec. 31
     
March 31
     
June 30
   
  
Sept. 30
 
                               
Fiscal Year 2009
                             
Total Operating Revenues
$
674,256
   
$
659,068
   
$
309,944
   
$
251,930
 
Operating Income (Loss)
 
56,688
     
55,240
     
16,203
     
(3,067
)
Net Income (Loss)
 
31,306
     
30,811
     
6,877
     
(4,747
)
Basic Earnings (Loss) Per Share of Common Stock
 
1.42
     
1.39
     
0.31
     
(0.22
)
Diluted Earnings (Loss) Per Share of Common Stock
 
1.41
     
1.39
     
0.31
     
(0.22
)


Laclede Gas Company’s financial statements and Notes to Financial Statements are included in Exhibit 99.1 .


Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

There have been no changes in and disagreements on accounting and financial disclosure with Laclede’s outside auditors that are required to be disclosed.

Item 9A . Controls and Procedures

As of the end of the period covered by this report, both The Laclede Group, Inc. and Laclede Gas Company carried out an evaluation, under the supervision and with participation of our management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures pursuant to Rule 13a-15e and Rule 15d-15e under the Securities Exchange Act of 1934, as amended. Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that the disclosure controls and procedures are effective.
There have been no changes in our internal control over financial reporting that occurred during the fourth fiscal quarter that have materially affected, or are reasonably likely to materially affect, the internal control over financial reporting for The Laclede Group, Inc. or Laclede Gas Company.
The Management Report on Internal Control Over Financial Reporting and the Reports of Independent Registered Public Accounting Firm are included under Item 8 , pages 45 through 47.

Item 9B . Other Information

None.


















Part III

Item 10 . Directors, Executive Officers and Corporate Governance

Information about:
   
our directors is incorporated by reference from the discussion under Proposal 1 of our proxy statement dated December 17, 2010 (2010 proxy statement);
   
our executive officers is reported in Part I of this Form 10-K;
   
compliance with Section 16(a) of the Exchange Act is incorporated by reference from the discussion in our 2010 proxy statement under the heading “Section 16(a) Beneficial Ownership Reporting Compliance”;
   
Financial Code of Ethics is posted on our website, www.thelacledegroup.com , in the Investor Services section under Governance Documents; and,
   
our audit committee, our audit committee financial experts, and submitting nominations to the Corporate Governance Committee is incorporated by reference from the discussion in our 2010 proxy statement under the heading “Corporate Governance.”
In addition, our Code of Business Conduct, Corporate Governance Guidelines, and charters for our audit, compensation and corporate governance committees are available on our website, and a copy will be sent to any shareholder upon written request.

Item 11 . Executive Compensation

Information about director and executive compensation is incorporated by reference from the discussion in our 2010 proxy statement under the headings: “Directors’ Compensation,” “Compensation Discussion and Analysis,” and “Executive Compensation.” The 2010 proxy statement also includes the “Compensation Committee Report,” which is deemed furnished and not filed.

Item 12 . Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Information about security ownership of certain beneficial owners and management is incorporated by reference from the discussion in our 2010 proxy statement under “Beneficial Ownership of Laclede Group Common Stock.”
Information regarding our equity compensation plans is incorporated by reference from our 2010 proxy statement.




Item 13 . Certain Relationships and Related Transactions, and Director Independence

Information about:
   
our policy and procedures for related party transactions and
   
the independence of our directors
is included in our 2010 proxy statement under “Corporate Governance” and is incorporated by reference. There were no related party transactions in fiscal year 2010.


Item 14 . Principal Accounting Fees and Services

Information about fees paid to our independent registered public accountant and our policy for pre-approval of services provided by our independent registered public accountant is incorporated by reference from our 2010 proxy statement under “Fees of Independent Registered Public Accountant” and “Corporate Governance,” respectively.


Part IV

Item 15 . Exhibits, Financial Statement Schedules
 
     
2010 10-K Page
(a)
1.
Financial Statements:
 
       
   
The Laclede Group, Inc.:
   
    See Item 8. Financial Statements and Supplementary Data, filed herewith, for a list of financial statements.
       
     
   
For Years Ended September 30, 2010, 2009, and 2008:
 
   
    Statements of Income
Ex. 99.1, p. 21
   
    Statements of Comprehensive Income
Ex. 99.1, p. 22
   
    Statements of Common Shareholder’s Equity
Ex. 99.1, p. 26
   
    Statements of Cash Flows
Ex. 99.1, p. 27
   
As of September 30, 2010 and 2009:
 
   
    Balance Sheets
Ex. 99.1, pp. 23-24
   
    Statements of Capitalization
Ex. 99.1, p. 25
   
Notes to Financial Statements
Ex. 99.1, pp. 28-54
   
Management Report on Internal Control Over Financial Reporting
Ex. 99.1, p. 18
   
Reports of Independent Registered Public Accounting Firm
Ex. 99.1, p. 19-20
       
 
2.
Supplemental Schedules
 
       
   
II – Reserves – The Laclede Group, Inc.
   
II – Reserves – Laclede Gas Company
       
   
Schedules not included have been omitted because they are not applicable or the
 
   
required data has been included in the financial statements or notes to financial
 
   
statements.
 
       
 
3.
Exhibits
 
       
   
Incorporated herein by reference to Index to Exhibits , page 100.
 
       
Item 15(a)(3) See the marked exhibits in the Index to Exhibits , page 100.
 
   
(b)
Incorporated herein by reference to Index to Exhibits , page 100.
 






SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

     
THE LACLEDE GROUP, INC.
       
       
November 19, 2010
 
By /s/
Mark D. Waltermire
     
Mark D. Waltermire
     
Chief Financial Officer


Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Date
Signature
Title
       
11/19/10
/s/
Douglas H. Yaeger
Chairman of the Board,
   
Douglas H. Yaeger
President and Chief Executive Officer
     
(Principal Executive Officer)
       
11/19/10
/s/
Mark D. Waltermire
Chief Financial Officer
   
Mark D. Waltermire
(Principal Financial and
     
Accounting Officer)
       
11/19/10
/s/
Arnold W. Donald
Director
   
Arnold W. Donald
 
       
11/19/10
/s/
Edward L. Glotzbach
Director
   
Edward L. Glotzbach
 
       
11/19/10
/s/
Anthony V. Leness
Director
   
Anthony V. Leness
 
       
11/19/10
/s/
W. Stephen Maritz
Director
   
W. Stephen Maritz
 
       
11/19/10
/s/
William E. Nasser
Director
   
William E. Nasser
 
       
11/19/10
/s/
Brenda D. Newberry
Director
   
Brenda D. Newberry
 
       
11/19/10
/s/
John P. Stupp, Jr.
Director
   
John P. Stupp, Jr.
 
       
11/19/10
/s/
MaryAnn Van Lokeren
Director
   
MaryAnn Van Lokeren
 







SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

     
LACLEDE GAS COMPANY
       
       
November 19, 2010
 
By /s/
Mark D. Waltermire
     
Mark D. Waltermire
     
Senior Vice President and
     
Chief Financial Officer


Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Date
Signature
Title
       
11/19/10
/s/
Douglas H. Yaeger
Chairman of the Board,
   
Douglas H. Yaeger
President and Chief Executive Officer
     
(Principal Executive Officer)
       
11/19/10
/s/
Mark D. Waltermire
Director, Senior Vice President
   
Mark D. Waltermire
and Chief Financial Officer
     
(Principal Financial and
     
Accounting Officer)
       
11/19/10
/s/
Michael R. Spotanski
Director, Senior Vice President
   
Michael R. Spotanski
Operations and Marketing
       
11/19/10
/s/
Richard A. Skau
Director, Senior Vice President
   
Richard A. Skau
Human Resources
       

























SCHEDULE II
THE LACLEDE GROUP, INC. AND SUBSIDIARY COMPANIES
RESERVES
FOR THE YEARS ENDED SEPTEMBER 30, 2010, 2009, AND 2008



COLUMN A
   
COLUMN B
 
COLUMN C
     
COLUMN D
     
COLUMN E
 
     
BALANCE AT
ADDITIONS
CHARGED
   
DEDUCTIONS
   
BALANCE
 
     
BEGINNING
 
TO
 
TO OTHER
     
FROM
     
AT CLOSE
 
DESCRIPTION
   
OF PERIOD
 
INCOME
 
ACCOUNTS
     
RESERVES
   
OF PERIOD
(Thousands of Dollars)
                               
YEAR ENDED
                               
SEPTEMBER 30, 2010:
                               
DOUBTFUL ACCOUNTS
 
$
11,160
$
8,609
$
12,018
 
(a)
$
21,492
 
(b)
$
10,295
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
3,653
$
2,313
$
   
$
2,738
 
(c)
$
3,228
 
Deferred compensation
   
11,905
 
1,702
 
     
1,036
     
12,571
 
Group medical claims
                               
  incurred but not reported
   
1,450
 
12,833
 
     
12,833
 
(c)
 
1,450
 
TOTAL
 
$
17,008
$
16,848
$
   
$
16,607
   
$
17,249
 
                                 
                                 
YEAR ENDED
                               
SEPTEMBER 30, 2009:
                               
DOUBTFUL ACCOUNTS
 
$
12,624
$
12,408
$
11,138
 
(a)
$
25,010
 
(b)
$
11,160
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
2,812
$
2,949
$
   
$
2,108
 
(c)
$
3,653
 
Deferred compensation
   
11,164
 
1,649
 
     
908
     
11,905
 
Group medical claims
                               
  incurred but not reported
   
1,500
 
12,305
 
     
12,355
 
(c)
 
1,450
 
TOTAL
 
$
15,476
$
16,903
$
   
$
15,371
   
$
17,008
 
                                 
                                 
YEAR ENDED
                               
SEPTEMBER 30, 2008:
                               
DOUBTFUL ACCOUNTS
 
$
11,268
$
13,100
$
9,850
 
(a)
$
21,594
 
(b)(d)
$
12,624
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
10,765
$
7,263
$
   
$
15,216
 
(c)(d)
$
2,812
 
Deferred compensation
   
10,949
 
1,446
 
     
1,231
     
11,164
 
Group medical claims
                               
  incurred but not reported
   
2,571
 
15,777
 
     
16,848
 
(c)(d)
 
1,500
 
TOTAL
 
$
24,285
$
24,486
$
   
$
33,295
   
$
15,476
 
                                 
                                 


(a)
Accounts reinstated, cash recoveries, etc.
(b)
Accounts written off.
(c)
Claims settled, less reimbursements from insurance companies.
(d)
Deductions include write-off of SM&P reserve balances at March 31, 2008 due to the sale of the subsidiary.




SCHEDULE II
LACLEDE GAS COMPANY
RESERVES
FOR THE YEARS ENDED SEPTEMBER 30, 2010, 2009, AND 2008


COLUMN A
   
COLUMN B
 
COLUMN C
     
COLUMN D
     
COLUMN E
 
     
BALANCE AT
 
ADDITIONS
 
CHARGED
     
DEDUCTIONS
     
BALANCE
 
     
BEGINNING
 
TO
 
TO OTHER
     
FROM
     
AT CLOSE
 
DESCRIPTION
   
OF PERIOD
 
INCOME
 
ACCOUNTS
     
RESERVES
     
OF PERIOD
 
(Thousands of Dollars)
                               
YEAR ENDED
                               
SEPTEMBER 30, 2010:
                               
DOUBTFUL ACCOUNTS
 
$
10,791
$
8,609
$
12,018
 
(a)
$
21,242
 
(b)
$
10,176
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
3,653
$
2,313
$
   
$
2,738
 
(c)
$
3,228
 
Deferred compensation
   
11,905
 
1,702
 
     
1,036
     
12,571
 
Group medical claims
                               
  incurred but not reported
   
1,450
 
12,833
 
     
12,833
 
(c)
 
1,450
 
TOTAL
 
$
17,008
$
16,848
$
   
$
16,607
   
$
17,249
 
                                 
                                 
YEAR ENDED
                               
SEPTEMBER 30, 2009:
                               
DOUBTFUL ACCOUNTS
 
$
12,476
$
12,155
$
11,138
 
(a)
$
24,978
 
(b)
$
10,791
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
2,812
$
2,949
$
   
$
2,108
 
(c)
$
3,653
 
Deferred compensation
   
11,164
 
1,649
 
     
908
     
11,905
 
Group medical claims
                               
  incurred but not reported
   
1,500
 
12,305
 
     
12,355
 
(c)
 
1,450
 
TOTAL
 
$
15,476
$
16,903
$
   
$
15,371
   
$
17,008
 
                                 
                                 
YEAR ENDED
                               
SEPTEMBER 30, 2008:
                               
DOUBTFUL ACCOUNTS
 
$
10,961
$
13,034
$
9,850
 
(a)
$
21,369
 
(b)
$
12,476
 
MISCELLANEOUS:
                               
Injuries and
                               
property damage
 
$
3,128
$
1,715
$
   
$
2,031
 
(c)
$
2,812
 
Deferred compensation
   
10,949
 
1,446
 
     
1,231
     
11,164
 
Group medical claims
                               
  incurred but not reported
   
1,150
 
12,192
 
     
11,842
 
(c)
 
1,500
 
TOTAL
 
$
15,227
$
15,353
$
   
$
15,104
   
$
15,476
 
                                 
                                 


(a)
Accounts reinstated, cash recoveries, etc.
(b)
Accounts written off.
(c)
Claims settled, less reimbursements from insurance companies.




     
Exhibit
   
No.
   
     
2.01*
-
Agreement and Plan of Merger and Reorganization; filed as Appendix A to proxy statement/prospectus contained in the Company’s registration statement on Form S-4, No. 333-48794.
3.01(i)*
-
Laclede’s Restated Articles of Incorporation effective March 18, 2002; filed as Exhibit 3.3 to Form 8-K filed May 29, 2002.
3.01(ii)*
-
Bylaws of Laclede effective January 18, 2002; filed as Exhibit 3.4 to Laclede’s Form 8-K filed May 29, 2002.
3.02(i)*
-
The Company’s Articles of Incorporation, as amended; filed as Exhibit 3.1 to the Company’s Form 8-K filed January 26, 2006.
3.02(ii)*
-
The Company’s Bylaws, as amended; filed as Exhibit 3.2 to the Company’s Form 8-K filed January 26, 2006.
4.01*
-
Mortgage and Deed of Trust, dated as of February 1, 1945; filed as Exhibit 7-A to registration statement No. 2-5586.
4.02*
-
Fourteenth Supplemental Indenture, dated as of October 26, 1976; filed on June 26, 1979 as Exhibit b-4 to registration statement No. 2-64857.
4.03*
-
Twenty-Second Supplemental Indenture dated as of November 15, 1995; filed on December 8, 1995 as Exhibit 4.01 to Laclede’s Form 8-K.
4.04*
-
Twenty-Third Supplemental Indenture dated as of October 15, 1997; filed on November 6, 1997 as Exhibit 4.01 to Laclede’s Form 8-K.
4.05*
-
Twenty-Fourth Supplemental Indenture dated as of June 1, 1999; filed on June 4, 1999 as Exhibit 4.01 to Laclede’s Form 8-K.
4.06*
-
Twenty-Fifth Supplemental Indenture dated as of September 15, 2000; filed on September 27, 2000 as Exhibit 4.01 to Laclede’s Form 8-K.
4.07*
-
Twenty-Seventh Supplemental Indenture dated as of April 15, 2004; filed on April 28, 2004 as Exhibit 4.01 to Laclede’s Form 8-K.
4.08*
-
Twenty-Eighth Supplemental Indenture dated as of April 15, 2004; filed on April 28, 2004 as Exhibit 4.02 to Laclede’s Form 8-K.
4.09*
-
Twenty-Ninth Supplemental Indenture dated as of June 1, 2006; filed on June 9, 2006, as Exhibit 4.1 to Laclede’s Form 8-K
4.10*
-
Thirtieth Supplemental Indenture dated as of September 15, 2008; filed on September 23, 2008 as Exhibit 4.1 to Laclede’s Form 8-K.
4.11*
-
Laclede Gas Company Board of Directors’ Resolution dated August 28, 1986 which generally provides that the Board may delegate its authority in the adoption of certain employee benefit plan amendments to certain designated Executive Officers; filed as Exhibit 4.12 to the Company’s 1991 10-K.
4.11a*
-
Company Board of Directors’ Resolutions dated March 27, 2003, updating authority delegated pursuant to August 28, 1986 Laclede Gas Company resolutions; filed as Exhibit 4.19(a) to the Company’s Form 10-K for the year ended September 30, 2003.
4.12*
-
Rights Agreement dated as of October 1, 2001; filed as Exhibit 4 to the Company’s Form 8-A on September 6, 2001.


*Incorporated herein by reference and made a part hereof. Laclede’s File No. 1-1822; the Company’s File No. 1-16681.

Bold items reflect management, contract or compensatory plan or arrangement.



INDEX TO EXHIBITS
     
Exhibit
   
No.
   
     
10.01*
-
Laclede Incentive Compensation Plan, amended and restated effective as of January 1, 2005; filed as Exhibit 10.3 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.02*
-
Laclede Incentive Compensation Plan II, effective as of January 1, 2005; filed as Exhibit 10.4 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.03*
-
Senior Officers’ Life Insurance Program of Laclede, as amended; filed as Exhibit 10.03 to the Company’s 1990 10-K.
10.03a*
-
Certified copy of resolutions of Laclede’s Board of Directors adopted on June 27, 1991 amending the Senior Officers’ Life Insurance Program; filed as Exhibit 10.01 to the Company’s 10-Q for the fiscal quarter ended June 30, 1991.
10.03b*
-
Certified copy of resolutions of Laclede’s Board of Directors adopted on January 28, 1993 amending the Senior Officers’ Life Insurance Program; filed as Exhibit 10.03 to the Company’s 10-Q for the fiscal quarter ended March 31, 1993.
10.04*
-
Restated Laclede Gas Company Supplemental Retirement Benefit Plan, as amended and restated effective as of November 1, 2005; filed as Exhibit 10.06 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.05*
-
Amended and Restated Storage Service Agreement For Rate Schedule FSS, Contract #3147 between Centerpoint Energy-Mississippi River Transmission Corporation (MRT) and Laclede dated March 18, 2008; filed as Exhibit 10.5 to the Company’s 10-Q for the fiscal quarter ended March 31, 2008.
10.05a*
-
Amended and Restated Transportation Service Agreement for Rate Schedule FTS, Contract #3310 between Laclede and MRT dated March 18, 2008; filed as Exhibit 10.6 to the Company’s 10-Q for the fiscal quarter ended March 31, 2008.
10.05b*
-
Amended and Restated Transportation Service Agreement for Rate Schedule FTS, Contract #3311, between Laclede and MRT dated March 18, 2008; filed as Exhibit 10.7 to the Company’s 10-Q for the fiscal quarter ended March 31, 2008.
10.06*
-
Laclede Supplemental Retirement Benefit Plan II, effective as of January 1, 2005; filed as Exhibit 10.7 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.07*
-
Amendment and Restatement of Retirement Plan for Non-Employee Directors as of November 1, 2002; filed as Exhibit 10.08c to the Company’s 10-K for the fiscal year ended September 30, 2002.
10.07a*
-
Amendment to Terms of Retirement Plan for Non-Employee Directors as of October 1, 2004; filed as Exhibit 10.w to the Company’s Form 10-Q for the fiscal quarter ended June 30, 2004.
10.08*
-
Salient Features of the Laclede Gas Company Deferred Income Plan for Directors and Selected Executives, including amendments adopted by the Board of Directors on July 26, 1990; filed as Exhibit 10.12 to the Company’s 1991 10-K.


*Incorporated herein by reference and made a part hereof. Laclede’s File No. 1-1822; the Company’s File No. 1-16681.

Bold items reflect management, contract or compensatory plan or arrangement.



INDEX TO EXHIBITS
     
Exhibit
   
No.
   
     
10.08a*
-
Amendment to Laclede’s Deferred Income Plan for Directors and Selected Executives, adopted by the Board of Directors on August 27, 1992; filed as Exhibit 10.12a to the Company’s 1992 10-K.
10.09*
-
Form of Indemnification Agreement between Laclede and its Directors and Officers; filed as Exhibit 10.13 to the Company’s 1990 10-K.
10.10*
-
The Laclede Group Management Continuity Protection Plan, effective as of January 1, 2005; filed as Exhibit 10.5 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.10a*
-
Form of Management Continuity Protection Agreement; Filed as Exhibit 10.05a to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.11*
-
Restricted Stock Plan for Non-Employee Directors as amended and effective January 29, 2009; filed as Exhibit 10.1 to the Company’s Form 10-Q for the fiscal quarter ended March 31, 2009.
10.12*
-
Salient Features of the Laclede Gas Company Deferred Income Plan II for Directors and Selected Executives (as amended and restated effective as of January 1, 2005); filed as Exhibit 10.1 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.13*
-
Salient Features of the Company’s Deferred Income Plan for Directors and Selected Executives (effective as of January 1, 2005); filed as Exhibit 10.2 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.14*
-
Amended and Restated Loan Agreement dated September 10, 2004 for Laclede with U.S. Bank National Association as administrative agent and lead arranger, Bank Hapoalim B.M., as syndication agent, and Southwest Bank of St. Louis as documentation agent; filed as Exhibit 10.1 on Form 8-K filed on September 13, 2004.
10.14a*
-
Amendment to loan agreement in Exhibit 10.12, dated December 23, 2005; filed as Exhibit 10.1 to Laclede’s Form 8-K filed December 23, 2005.
10.14b*
-
Second amendment dated February 8, 2008 to syndicated loan agreement of Laclede Gas Company dated September 10, 2004 and first amended December 23, 2005; filed as Exhibit 10.1 to Laclede’s Form 10-Q for the fiscal quarter ended March 31, 2008.
10.15*
-
The Laclede Group, Inc. 2002 Equity Incentive Plan; filed as Exhibit 10.22 to the Company’s Form 10-K for the year ended September 30, 2002.
10.15a*
-
Form of Non-Qualified Stock Option Award Agreement with Mandatory Retirement Provisions; filed as Exhibit 10.1 to the Company’s Form 8-K filed November 5, 2004.

*Incorporated herein by reference and made a part hereof. Laclede’s File No. 1-1822; the Company’s File No. 1-16681.

Bold items reflect management, contract or compensatory plan or arrangement.



INDEX TO EXHIBITS
     
Exhibit
   
No.
   
     
10.15b*
-
Form of Non-Qualified Stock Option Award Agreement without Mandatory Retirement Provisions; filed as Exhibit 10.2 to the Company’s Form 8-K filed November 5, 2004.
10.15c*
-
Form of Restricted Stock Award Agreement; filed as Exhibit 10.17 to the Company’s 10-Q for the fiscal quarter ended March 31, 2004.
10.15d*
-
Form of Performance – Contingent Restricted Stock Award Agreement; filed as Exhibit 10.2 to the Company’s Form 8-K filed
November 2, 2006.
10.16*
-
Lease between Laclede Gas Company, as Lessee and First National Bank in St. Louis, Trustee, as Lessor; filed as Exhibit 10.23 to the Company’s Form 10-K for the fiscal year ended September 30, 2002.
10.17*
-
Automated Meter Reading Services Agreement executed March 11, 2005; filed as Exhibit 10.1 to the Company’s Form 10-Q for the fiscal quarter ended March 31, 2005. Confidential portions of this exhibit have been omitted and filed separately with the Securities and Exchange Commission pursuant to a request for confidential treatment.
10.18*
-
Stock Ownership Guidelines and Holding Requirements; filed as Exhibit 10.1 to the Company’s Form 8-K filed November 1, 2005.
10.19*
-
The Laclede Group, Inc. Annual Incentive Plan; filed as Appendix 4 to the Company’s proxy statement filed December 19, 2005.
10.20*
-
The Laclede Group, Inc. 2006 Equity Incentive Plan; filed as Appendix 5 to the Company’s proxy statement, filed December 19, 2005.
10.20a*
-
Form of Restricted Stock Award Agreement; filed as Exhibit 10.1 to the Company’s Form 10-Q for the fiscal quarter ended December 31, 2007.
10.20b*
-
Form of Performance Contingent Restricted Stock Award Agreement for all participants except the Chief Executive Officer and the Executive Vice President-Energy and Administrative Services; filed as Exhibit 10.2 to the Company’s Form 10-Q for the fiscal quarter ended December 31, 2007.
10.20c*
-
Forms of Performance Contingent Restricted Stock Award Agreements for Chief Executive Officer; filed as Exhibit 10.3 to the Company’s Form 10-Q for the fiscal quarter ended December 31, 2007.
10.20d*
-
Form of Performance Contingent Restricted Stock Award Agreement for Executive Vice President-Energy and Administrative Services; filed as Exhibit 10.4 to the Company’s Form 10-Q for the fiscal quarter ended December 31, 2007.
10.20e*
-
Restricted Stock Unit Award Agreement with Douglas H. Yaeger dated February 14, 2008; filed as Exhibit 10.2 to the Company’s Form 10-Q for the fiscal quarter ended March 31, 2008.


*Incorporated herein by reference and made a part hereof. Laclede’s File No. 1-1822; the Company’s File No. 1-16681.

Bold items reflect management, contract or compensatory plan or arrangement.



INDEX TO EXHIBITS
     
Exhibit
   
No.
   
     
10.20f*
-
Form of Restricted Stock Award Agreement filed as Exhibit 10.8 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.20g*
-
Form of Performance Contingent Restricted Stock Award Agreement; filed as Exhibit 10.8 to the Company’s 10-Q for the fiscal quarter ended December 31, 2008.
10.20h*
-
Form of Performance Contingent Restricted Stock Award Agreement; filed as Exhibit 10.2 to the Company’s 10-Q for the fiscal quarter ended December 31, 2009.
10.21*
-
Supplemental Pension Agreement between Laclede Gas Company and Kenneth J. Neises dated March 7, 2008; filed as Exhibit 10.4 to the Company’s Form 10-Q for the fiscal quarter ended March 31, 2008.
10.21a*
-
Amendment dated January 7, 2010 to Supplemental Pension Agreement between Laclede Gas Company and Kenneth J. Neises; filed as Exhibit 10.1 to the Company’s 10-Q for the fiscal quarter ended December 31, 2009.
10.22*
-
Amended and Restated Firm (Rate Schedule FT) Transportation Service Agreement between Laclede Energy Resources, Inc. and Centerpoint Energy Gas Transmission Company TSA #1006667; filed as Exhibit 10.2 to the Company’s 10-Q for the fiscal quarter ended March 31, 2009.
-
Credit Agreement between the Company and U. S. Bank National Association, dated October 1, 2010.
-
Credit Agreement between the Company and PNC Bank, National Association, dated October 1, 2010.
-
The Laclede Group 2011 Management Continuity Protection Plan
-
Form of Agreement Under The Laclede Group 2011 Management Continuity Protection Plan
-
Ratio of Earnings to Fixed Charges.
-
Subsidiaries of the Registrant.
-
Consents of Independent Registered Public Accounting Firm.
-
Certificates under Rule 13a-14(a) of the CEO and CFO of The Laclede Group, Inc. and Laclede Gas Company.
-
Section 1350 Certifications under Rule 13a-14(b) of the CEO and CFO of The Laclede Group, Inc. and Laclede Gas Company.
-
Laclede Gas Company – Selected Financial Data, Management’s Discussion and Analysis of Financial Condition and Results of Operations, Notes to Financial Statements, Management Report on Internal Control Over Financial Reporting, and Reports of Independent Registered Public Accounting Firm.


*Incorporated herein by reference and made a part hereof. Laclede’s File No. 1-1822; the Company’s File No. 1-16681.

Bold items reflect management, contract or compensatory plan or arrangement.






Exhibit 10.23




 
REVOLVING CREDIT AGREEMENT
 

BY AND BETWEEN

U.S. BANK NATIONAL ASSOCIATION, Lender

and

THE LACLEDE GROUP, INC., Borrower







October 1, 2010


 
 
 
 

TABLE OF CONTENTS

     
PAGE
       
SECTION 1.  DEFINITIONS
1
         
 
1.01
Definitions
1
         
SECTION 2.  LOANS
5
         
 
2.01
Loans
5
         
 
2.02
Method of Borrowing
6
         
 
2.03
Note
7
         
 
2.04
Duration of Interest Periods and Selection of Interest Rates
7
         
 
2.05
Interest Rates and Interest Payments
8
         
 
2.06
Computation of Interest
8
         
 
2.07
Fees
8
         
 
2.08
Prepayments
9
         
 
2.09
General Provisions as to Payments
9
         
 
2.10
Funding Losses
9
         
 
2.11
Basis for Determining Interest Rate Inadequate of Unfair
9
         
 
2.12
Illegality
10
         
 
2.13
Increased Cost
10
         
 
2.14
Daily Reset Loans Substituted for Affected LIBOR Loans
11
         
 
2.15
Capital Adequacy
11
         
 
2.16
Survival of Indemnities
11
         
 
2.17
Discretion of Lender as to Manner of Funding
11
         
 
2.18
Letters of Credit
11
         
 
2.20
Taxes
13
         
SECTION 3.  PRECONDITIONS TO LOANS AND LETTERS OF CREDIT
13
         
 
3.01
Initial Loan
13


 
 
 
 


 
3.02
All Loans and Letters of Credit
14
         
SECTION 4.  REPRESENTATIONS AND WARRANTIES
15
         
 
4.01
Corporate Existence and Power
15
         
 
4.02
Corporate Authorization
15
         
 
4.03
Binding Effect
15
         
 
4.04
Financial Statements
15
         
 
4.05
Compliance With Other Instruments; None Burdensome
16
         
 
4.06
Regulation U
16
         
 
4.07
Investment Company Act of 1940; Public Utility Holding Company Act of 2005
16
         
 
4.08
No Default
16
         
SECTION 5.  COVENANTS
17
         
 
5.01
Covenants of Borrower
17
         
 
5.02
Use of Proceeds
19
         
SECTION 6.  EVENTS OF DEFAULT
19
         
SECTION 7. GENERAL
21
         
 
7.01
No Waiver
21
         
 
7.02
Right of Set-Off
21
         
 
7.03
Cost and Expenses
21
         
 
7.04
General Indemnity
21
         
 
7.05
Notices
22
         
 
7.06
Consent to Jurisdiction; Waiver of Jury Trial
22
         
 
7.07
Governing Law
23
       
 
7.08
Amendments and Waivers
23
       
 
7.09
References; Headings for Convenience
23
       
 
7.10
Successors and Assigns
23
       
 
7.11
Notice Required by Section 432.047 R.S.Mo.; Entire Agreement
23



- ii -
 
 
 
 


 
7.12
Severability
23
         
 
7.13
Counterparts
23
         
 
7.14
Confidentiality
23
         
 
7.15
USA PATRIOT Act
24




- iii -
 
 
 
 

REVOLVING CREDIT AGREEMENT
 
         THIS REVOLVING CREDIT AGREEMENT (this “ Agreement ”) is made and entered into as of October 1, 2010, by and between THE LACLEDE GROUP, INC. , a Missouri corporation (“ Borrower ”), and U. S. BANK NATIONAL ASSOCIATION , a national banking association (“ Lender ”); and has reference to the following facts and circumstances:
 
         A.      Borrower has applied for a revolving credit facility from Lender consisting of Loans in an aggregate principal amount of up to $30,000,000.00.
 
         B.      Lender is willing to make said revolving credit facility available to Borrower upon, and subject to, the terms, provisions and conditions hereinafter set forth.
 
         NOW, THEREFORE, in consideration of the premises and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Borrower and Lender hereby mutually covenant and agree as follows:

SECTION 1.  DEFINITIONS .
 
         1.01    Definitions .  In addition to the terms defined elsewhere in this Agreement or in any Exhibit or Schedule hereto, when used in this Agreement, the following terms shall have the following meanings (such meanings shall be equally applicable to the singular and plural forms of the terms used, as the context requires):
 
           Acquisition shall mean any transaction or series of related transactions, consummated on or after the date of this Agreement, by which Borrower or any Subsidiary directly or indirectly (a) acquires all or substantially all of the assets comprising one or more business units of any other Person at a purchase price of $5,000,000 or more, whether through purchase of assets, merger or otherwise or (b) acquires (in one transaction or as the most recent transaction in a series of transactions) at least (i) a majority (in number of votes) of the stock and/or other securities of a corporation having ordinary voting power for the  election of directors (other than stock and/or other securities having such power only by reason of the happening of a contingency), (ii) a majority (by percentage of voting power) of the outstanding partnership interests of a partnership, (iii) a majority (by percentage of voting power) of the outstanding membership interests of a limited liability company or (iv) a majority of the ownership interests in any organization or entity other than a corporation, partnership or limited liability company.
 
           Act shall have the meaning ascribed thereto in Section 7.15.
 
           Applicable Commitment Fee Rate shall mean an annual rate equal to 15/100 Percent (0.15%).
 
           Applicable Margin shall mean an annual rate equal to One and 25/100 Percent (1.25%).
 
           Borrower’s Obligations shall mean any and all present and future indebtedness (principal, interest, fees, collection costs and expenses, attorneys’ fees and other amounts), liabilities and obligations (including, without limitation, indemnity obligations) of Borrower to Lender evidenced by or arising under or in respect of this Agreement, the Note and/or any of the other Transaction Documents.
 
           Business Day shall mean any day except a Saturday, Sunday or legal holiday observed by Lender.
 
           Consolidated Capitalization shall mean, as of the date of any determination thereof, the sum of Consolidated Debt as of such date, plus Consolidated Net Worth as of such date, all determined on a consolidated basis and in accordance with GAAP.
 
 
 
 
 
 
 
           Consolidated Capitalization Ratio shall mean, as of the date of any determination thereof, the ratio (expressed as a percentage) of Consolidated Debt as of such date to Consolidated Capitalization as of such date, all determined on a consolidated basis and in accordance with GAAP; provided , that for purposes of calculating the Consolidated Capitalization Ratio, only Fifty Percent (50%) of the principal amount of any outstanding subordinated Debt issued by Borrower shall be included in Consolidated Debt.
 
           Consolidated Debt shall mean, as of the date of any determination thereof, all Debt of Borrower and its Subsidiaries as of such date, determined on a consolidated basis and in accordance with GAAP.
 
           Consolidated Net Worth shall mean, as of the date of any determination thereof, the amount of the capital stock accounts (net of treasury stock, at cost) of Borrower and its Subsidiaries as of such date plus (or minus in the case of a deficit) the surplus and retained earnings of Borrower and its Subsidiaries as of such date, all determined on a consolidated basis and in accordance with GAAP.
 
           Daily Reset LIBOR Rate shall mean the Applicable Margin plus the one-month LIBOR rate quoted by Lender from Reuters Screen LIBOR01 Page or any successor thereto, which shall be that one-month LIBOR rate in effect and reset each New York Banking Day, adjusted for any reserve requirement and any subsequent costs arising from a change in government regulation, such rate rounded up to the nearest one-sixteenth percent.
 
           Daily Reset Loan shall mean any portion of a Loan bearing interest based on the Daily Reset LIBOR Rate.
 
           Debt shall mean, as of the date of determination thereof, the sum of (a) all indebtedness, liabilities and/or obligations of Borrower or any of its Subsidiaries for borrowed money or that have been incurred in connection with the purchase or other acquisition of property (other than unsecured trade accounts payable incurred in the ordinary course of business), plus (b) all leases of property, whether real and/or personal, by Borrower or any of its Subsidiaries as lessee(s), that in accordance with GAAP are required to be capitalized on the balance sheet of such entity, plus (c) the aggregate undrawn face amount of all Letters of Credit and/or surety bonds issued for the account and/or upon the application of Borrower or any of its Subsidiaries together with all unreimbursed drawings with respect thereto, plus (d) all guarantees by Borrower or any of its Subsidiaries of Debt of other Persons (but not including any guarantees of Debt of Borrower or any of its Subsidiaries).
 
           Default shall mean any event or condition the occurrence of that would, with the lapse of time or the giving of notice or both, become an Event of Default.
 
           Event of Default shall have the meaning ascribed thereto in Section 6.
 
           Fitch shall mean Fitch Ratings, Ltd.
 
           GAAP shall mean, at any time, generally accepted accounting principles at such time in the United States.
 
           Guaranty shall mean the Guaranty dated as of the date hereof, executed by Laclede Energy in favor of Lender, as the same may from time to time be amended, modified, extended, renewed or restated.
 
           Indemnified Liabilities shall have the meaning ascribed thereto in section 7.04.
 
 
 
- 2 -
 
 
 
           Interest Period shall mean with respect to each LIBOR Loan:  (a) initially, the period commencing on the date selected by Borrower in the applicable Interest Rate Selection Notice and ending seven (7) days, one (1) month, two (2) months, three (3) months, or six (6) months thereafter, as Borrower may elect in the applicable Interest Rate Selection Notice; and (b) thereafter, each period commencing on the last day of the immediately preceding Interest Period applicable to such LIBOR Loan and ending seven (7) days, one (1) month, two (2) months, three (3) months, or six (6) months, as Borrower may elect in the applicable Interest Rate Selection Notice; provided that :  (c) no Interest Period for a LIBOR Loan shall extend beyond a date on which Borrower is required to make a scheduled payment of principal on the Loan unless the sum of (A) the aggregate principal amount of outstanding Daily Reset Loans plus (B) the aggregate principal amount of outstanding LIBOR Loans with Interest Periods expiring on or before the date such scheduled principal payment is due equals or exceeds the aggregate principal amount to be paid on the Loan on such principal payment date; (d) subject to clauses (e) and (f) below, any Interest Period that would otherwise end on a day that is not a New York Business Day shall be extended to the next succeeding New York Business Day unless such New York Business Day falls in another calendar month, in which case such Interest Period shall end on the immediately preceding New York Business Day; (e) subject to clause (f) below, any Interest Period that begins on the last New York Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last New York Business Day of a calendar month; and no Interest Period may extend beyond the maturity date of the Loan.
 
           Interest Rate Selection Notice shall have the meaning ascribed thereto in section 2.02(a).
 
           Investment shall mean any investment (including, without limitation, any loan or advance) of Borrower or any Subsidiary in or to any Person, whether payment therefor is made in cash or capital stock or other equity interests of Borrower or any Subsidiary, and whether such investment is by acquisition of stock or other equity interests or Indebtedness, or by loan, advance, transfer of property out of the ordinary course of business, capital contribution, equity or profit sharing interest, extension of credit on terms other than those normal in the ordinary course of business or otherwise.
 
           Laclede Energy shall mean Laclede Energy Resources, Inc., a Missouri corporation, and a Subsidiary of Borrower.
 
           Lender’s Revolving Credit Commitment shall mean the sum of Thirty Million Dollars ($30,000,000).
 
           Letter of Credit and Letters of Credit shall have the meanings ascribed to these terms in Section 2.18(a).
 
           Letter of Credit Application shall mean Lender’s standard form of application and agreement for irrevocable standby letter of credit, or Lender’s standard form of application and agreement for irrevocable commercial letter of credit, as the case may be, in either case executed by Borrower, or a Subsidiary of Borrower, as applicant and account party, and delivered to Lender pursuant to Section 2.18(a), as the same may from time to time be amended, modified, extended, renewed or restated.
 
           LGC shall mean Laclede Gas Company, a Missouri corporation, and a Subsidiary of Borrower.
 
           LIBOR Base Rate shall mean, with respect to the applicable Interest Period, (a) the LIBOR Index Rate for such Interest Period, if such rate is available or (b) if the LIBOR Index Rate is not available, the average (rounded upward, if necessary, to the next higher 1/10,000 of 1%) of the respective annual rates of interest at which deposits in U.S. Dollars are offered to Lender in the London interbank market by two (2) Eurodollar dealers of recognized standing, selected by Lender in its sole discretion, at or about 11:00 a.m. (London time) on the date two (2) New York Business Days before
 
 
 
- 3 -
 
 
 
the first day of such Interest Period, for delivery on the first day of the applicable Interest Period for a number of days comparable to the number of days in such Interest Period and in an amount approximately equal to the principal amount of the LIBOR Loan to which such Interest Period is to apply.
 
           LIBOR Index Rate shall mean, with respect to the applicable Interest Period, an annual rate (rounded upwards, if necessary, to the next higher 1/10,000 of 1%) equal to the British Bankers’ Association interest settlement rates for U.S. Dollar deposits for such Interest Period as of 11:00 a.m. (London time) on the day two (2) New York Business Days before the first day of such Interest Period as published by Bloomberg Financial Services, Dow Jones Market Service, Telerate, Reuters or any other service from time to time used by Lender.
 
           LIBOR Loan shall mean any portion of a Loan bearing interest based on the LIBOR Rate.
 
           LIBOR Rate shall mean (a) the quotient of the (i) LIBOR Base Rate divided by (ii) one minus the applicable LIBOR Reserve Percentage plus (b) the Applicable Margin.  The LIBOR Rate shall be adjusted automatically on and as of the effective date of any change in the LIBOR Reserve Percentage.
 
           LIBOR Reserve Percentage shall mean for any day that percentage (expressed as a decimal) which is in effect on such day, as prescribed by The Board of Governors of the Federal Reserve System (or any successor), for determining the maximum reserve requirement (including, without limitation, any basic, supplemental, emergency, special or marginal reserves) with respect to “Eurocurrency liabilities” as defined in Regulation D or with respect to any other category of liabilities which includes deposits by reference to which the interest rate on LIBOR Loans is determined, whether or not Lender has any Eurocurrency liabilities subject to such reserve requirement at such time. LIBOR Loans shall be deemed to constitute Eurocurrency liabilities and as such shall be deemed subject to reserve requirements without the benefit of any credits for proration, exceptions or offsets which may be available from time to time to Lender.
 
           Loan and Loans shall have the meaning ascribed thereto in Section 2.01(a).
 
           Loan Party shall mean each of Borrower and each Subsidiary that has executed the Guaranty (including, without limitation, Laclede Energy).
 
           Material Adverse Effect shall mean (a) a material adverse effect on the properties, assets, liabilities, business, operations, income or condition (financial or otherwise) of Borrower and its Subsidiaries taken as a whole, (b) material impairment of Borrower’s ability to perform any of its obligations under this Agreement, the Note or any of the other Transaction Documents or (c) material impairment of the enforceability of the rights of, or benefits available to, Lender under this Agreement, the Note or any of the other Transaction Documents.
 
           Moody’s shall mean Moody’s Investors Service, Inc.
 
           New York Business Day means any day (other than a Saturday or Sunday) on which commercial banks are open for business in New York, New York.
 
           Note shall have the meaning ascribed thereto in Section 2.03(a).
 
           Notice of Borrowing shall have the meaning ascribed thereto in Section 2.02(a).
 
           Other Taxes shall have the meaning ascribed thereto in Section 2.20(b).
 
 
 
 
- 4 -
 
 
 
           Permitted Investment shall mean any Investment or Acquisition, or any expenditure or any incurrence of any liability to make any expenditure for an Investment or Acquisition, other than (a) any Investment or Acquisition the result of which would be to change substantially the nature of the business engaged in by Borrower and its Subsidiaries, (b) any Investment that is in the nature of a hostile or contested Acquisition, and (c) any Investment that would result in a Default or Event of Default; provided , that it is expressly agreed that all Investments under Borrower’s or Subsidiaries’ gas supply risk management programs are Permitted Investments.
 
           Person shall mean any individual, sole proprietorship, partnership, joint venture, limited liability company, trust, unincorporated organization, association, corporation, institution, entity or government (whether national, Federal, state, county, city, municipal or otherwise, including, without limitation, any instrumentality, division, agency, body or department thereof).
 
           PNC Agreement shall mean the Credit Agreement by and between Borrower and PNC Bank, National Association, executed on the date hereof or within thirty (30) days following the date hereof, as amended, modified or restated from time to time.
 
           Regulation D shall mean Regulation D of the Board of Governors of the Federal Reserve System, as amended.
 
           Regulatory Change shall have the meaning ascribed thereto in Section 2.10.
 
           Revolving Credit Period shall mean the period commencing on the date of this Agreement and ending September 30, 2011; provided , however , that the Revolving Credit Period shall end on the date the Lender’s Revolving Credit Commitment is terminated pursuant to Section 6 or otherwise.
 
           S&P  shall mean Standard & Poor’s Ratings Group.
 
           Subsidiary shall mean any corporation or other entity of which more than Fifty Percent (50%) of the issued and outstanding capital stock or other equity interests entitled to vote for the election of directors or persons performing similar functions (other than by reason of default in the payment of dividends or other distributions) is at the time owned directly or indirectly by Borrower or any Subsidiary.
 
           Taxes shall have the meaning ascribed thereto in Section 2.20(a).
 
           Total Revolving Credit Outstandings  shall mean, as of any date, the sum of (a) the aggregate principal amount of all Loans outstanding as of such date, plus (b) the aggregate undrawn face amount of all Letters of Credit outstanding as of such date plus (c) all unreimbursed drawings with respect to all Letters of Credit.
 
           Transaction Documents shall mean this Agreement, the Note, the Guaranty, and any and all other agreements, documents and instruments heretofore, now or hereafter delivered to the Agent or any Bank with respect to or in connection with or pursuant to this Agreement, any Loans made hereunder or any of the other Borrower’s Obligations, and executed by or on behalf of any Loan Party, all as the same may from time to time be amended, modified, extended, renewed or restated.

SECTION 2.  LOANS .
 
         2.01    Loans .
 
         (a)      Subject to the terms and conditions set forth in this Agreement and so long as no Default or Event of Default has occurred and is continuing, during the Revolving Credit Period, Lender agrees
 
 
 
- 5 -
 
 
 
to make such loans to Borrower (individually, a “ Loan ” and collectively, the “ Loans ”) as Borrower may from time to time request pursuant to Section 2.02.  Each Loan under this Section 2.01(a) which is a Daily Reset Loan shall be for an aggregate principal amount of at least $50,000.00 or any larger multiple of $10,000.00.  Each Loan under this Section 2.01(a) which is a LIBOR Loan shall be for an aggregate principal amount of at least $1,000,000.00 or any larger multiple of $250,000.00; provided , that Borrower may not have outstanding and Lender shall not be obligated to make more than eight (8) LIBOR Loans at any one time.  The aggregate principal amount of Loans that Lender shall be required to have outstanding under this Agreement as of any date shall not exceed the amount of Lender’s Revolving Credit Commitment as of such date. Within the foregoing limits, Borrower may borrow under this Section 2.01(a), prepay under Section 2.08 and reborrow at any time during the Revolving Credit Period under this Section 2.01(a).  All Loans not paid prior to the last day of the Revolving Credit Period, together with all accrued and unpaid interest thereon and all fees and other amounts owing by Borrower to Lender with respect thereto, shall be due and payable on the last day of the Revolving Credit Period.
 
         (b)      If the amount of Lender’s Revolving Credit Commitment on any date is less than the Total Revolving Credit Outstandings on such date, whether as a result of Borrower’s election to decrease the amount of Lender’s Revolving Credit Commitment pursuant to Section 2.01(c) or otherwise, Borrower shall be automatically required (without demand or notice of any kind by Lender, all of which are hereby expressly waived by Borrower) to immediately repay the Loans in an amount sufficient to reduce the amount of the Total Revolving Credit Outstandings to an amount equal to or less than the amount of Lender’s Revolving Credit Commitment.
 
         (c)      Borrower may, upon five (5) Business Days’ prior written notice to Lender, terminate entirely at any time, or reduce from time to time by an aggregate amount of $1,000,000 or any larger multiple of $1,000,000 the unused portions of Lender’s Revolving Credit Commitment; provided , however , that (i) at no time shall the amount of Lender’s Revolving Credit Commitment be reduced to a figure less than the Total Revolving Credit Outstanding, (ii) at no time shall the amount of Lender’s Revolving Credit Commitment be reduced to a figure greater than zero (0) but less than $5,000,000 and (iii) any such termination or reduction shall be permanent and Borrower shall have no right to thereafter reinstate or increase, as the case may be, Lender’s Revolving Credit Commitment.
 
         2.02    Method of Borrowing .
 
         (a)      Borrower shall give Lender oral or written notice (a “ Notice of Borrowing ”) by 10:00 a.m. (St. Louis time) on the Business Day of each Daily Reset Loan to be made to Borrower, and by 10:00 a.m. (St. Louis time) at least three (3) New York Business Days before each LIBOR Loan to be made to Borrower, specifying:  (i) the date of such Loan, which shall be a Business Day during the Revolving Credit Period in the case of a Daily Reset Loan and a New York Business Day during the Revolving Credit Period in the case of a LIBOR Loan, (ii) the aggregate principal amount of such Loan, (iii) whether such Loan is to be a Daily Reset Loan or a LIBOR Loan, and (iv) in the case of a LIBOR Loan, the duration of the initial Interest Period applicable thereto, subject to the provisions of the definition of Interest Period.
 
         (b)      A Notice of Borrowing shall not be revocable by Borrower.
 
         (c)      Subject to the terms and conditions of this Agreement, provided that Lender has received the Notice of Borrowing, Lender shall (unless Lender determines that any applicable condition specified in Section 3 has not been satisfied) make the applicable Loan to Borrower by crediting the amount of such Loan to a demand deposit account of Borrower at Lender specified by Borrower (or such other account mutually agreed upon in writing between Lender and Borrower) not later than 2:30 p.m. (St. Louis time) on the Business Day specified in said Notice of Borrowing.
 
 
 
 
- 6 -
 
 
 
         (d)      If Lender makes a new Loan under this Agreement on a day on which Borrower is required to or has elected to repay all or any part of an outstanding Loan, Lender shall apply the proceeds of its new Loan to make such repayment and only an amount equal to the difference (if any) between the amount being borrowed and the amount being repaid shall be made available by Lender to Borrower.
 
         (e)      Borrower hereby irrevocably authorizes Lender to rely on telephonic, telegraphic, telecopy, telex or written instructions of any individual identifying himself or herself as one of the individuals listed on Schedule 2.02 attached hereto (or any other individual from time to time authorized to act on behalf of Borrower pursuant to a document signed by the President, Chief Financial Officer or Treasurer of Borrower and certified by the Secretary of Borrower and delivered to Lender) with respect to any request to make a Loan or a repayment under this Agreement, and on any signature that Lender reasonably believes to be genuine, and Borrower shall be bound thereby in the same manner as if such individual were actually authorized or such signature were genuine.  Borrower also hereby agrees to defend and indemnify Lender and hold Lender harmless from and against any and all claims, demands, damages, liabilities, losses and reasonable costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) relating to or arising out of or in connection with the acceptance of instructions for making Loans or repayments under this Agreement.
 
         2.03    Note .
 
         (a)      The Loans of Lender to Borrower shall be evidenced by the Revolving Credit Note of Borrower payable to the order of Lender in a principal amount equal to the maximum amount of Lender’s Revolving Credit Commitment, which Revolving Credit Note shall be in substantially the form of Exhibit A attached hereto and incorporated herein by reference (with appropriate insertions) (as the same may from time to time be amended, modified, extended, renewed or restated, the “ Note ”).
 
         (b)      Lender shall record in its books and records the date, amount, type and Interest Period (if any) of each Loan made by it to Borrower and the date and amount of each payment of principal and/or interest made by Borrower with respect thereto; provided , however , that the obligation of Borrower to repay each Loan made by Lender to Borrower under this Agreement shall be absolute and unconditional, notwithstanding any failure of Lender to make any such recordation or any mistake by Lender in connection with any such recordation.  The books and records of Lender showing the account between Lender and Borrower shall be conclusive in the absence of manifest error.
 
         2.04    Duration of Interest Periods and Selection of Interest Rates .
 
         (a)      The duration of the initial Interest Period for each LIBOR Loan shall be as specified in the applicable Notice of Borrowing.  Borrower shall elect the duration of each subsequent Interest Period applicable to such LIBOR Loan and the interest rate to be applicable during such subsequent Interest Period (and Borrower shall have the option (i) in the case of any Daily Reset Loan, to elect that such Loan become a LIBOR Loan and the Interest Period to be applicable thereto, and (ii) in the case of any LIBOR Loan, to elect that such Loan become a Daily Reset Loan), by giving notice of such election to Lender by 10:00 a.m. (St. Louis time) on the Business Day of, in the case of the election of the Daily Reset LIBOR Rate, and by 10:00 a.m. (St. Louis time) at least three (3) New York Business Days before, in the case of the election of the LIBOR Rate, the end of the immediately preceding Interest Period applicable thereto, if any; provided , however , that notwithstanding the foregoing, in addition to and without limiting the rights and remedies of Lender under Section 6 of this Agreement, so long as any Default or Event of Default under this Agreement has occurred and is continuing, Borrower shall not be permitted to renew any LIBOR Loan as a LIBOR Loan or to convert any Daily Reset Loan into a LIBOR Loan.  If Lender does not receive a notice of election for a Loan pursuant to this Section 2.04(a) within the applicable time limits specified herein, Borrower shall be deemed to have elected to
 
 
- 7 -
 
 
 
pay such Loan in whole pursuant to Section 2.08 on the last day of the current Interest Period with respect thereto and to reborrow the principal amount of such Loan on such date as a Daily Reset Loan.
 
         (b)      Borrower may not have outstanding and Lender shall not be obligated to make more than eight (8) LIBOR Loans at any one time.
 
         2.05    Interest Rates and Interest Payments .  (a) So long as no Event of Default has occurred and is continuing, each Daily Reset Loan shall bear interest on the outstanding principal amount thereof for each day until paid at an annual rate equal to the Daily Reset LIBOR Rate.  So long as any Event of Default has occurred and is continuing, each Daily Reset Loan shall bear interest on the outstanding principal amount thereof for each until it is paid, at an annual rate equal to Five Percent (5%) over and above the Daily Reset LIBOR Rate.  Such interest shall be payable monthly in arrears on the last day of each calendar month commencing October 31, 2010 and at the maturity of the Note (whether by reason of acceleration or otherwise).  From and after the maturity of the Note, whether by reason of acceleration or otherwise, each Daily Reset Loan shall bear interest, payable on demand, for each day until paid at an annual rate equal to Five Percent (5%) over and above the Daily Reset LIBOR Rate.
 
         (b)      So long as no Event of Default has occurred and is continuing, each LIBOR Loan shall bear interest on the outstanding principal amount thereof for each Interest Period applicable thereto at an annual rate equal to the LIBOR Rate.  So long as any Event of Default has occurred and is continuing, each LIBOR Loan shall bear interest on the outstanding principal amount thereof for each Interest Period applicable thereto at an annual rate equal to Five Percent (5%) over and above the LIBOR Rate.  Such interest shall be payable for each Interest Period on the last day thereof, unless the duration of such Interest Period exceeds three (3) months, in which case such interest shall be payable on the last day of each three (3) month period during such Interest Period and on the last day of such Interest Period, and at the maturity of the Note (whether by reason of acceleration or otherwise).  From and after the maturity of the Note, whether by reason of acceleration or otherwise, each LIBOR Loan shall bear interest, payable on demand, for each day until paid, at an annual rate equal to Five Percent (5%) over and above the higher of (i) the LIBOR Rate applicable to such LIBOR Loan for the immediately preceding Interest Period or (ii) the Daily Reset LIBOR Rate.
 
         (c)      Lender shall determine each interest rate applicable to the Daily Reset Loans and LIBOR Loans hereunder and its determination thereof shall be conclusive in the absence of manifest error.
 
         2.06    Computation of Interest .  Interest on Daily Reset Loans hereunder shall be computed on the basis of a year of 360 days and paid for the actual number of days elapsed (including the first day but excluding the last day).  Interest on LIBOR Loans shall be computed on the basis of a year of 360 days and paid for the actual number of days elapsed, calculated as to each Interest Period from and including the first day thereof to but excluding the last day thereof.
 
         2.07    Fees .
 
         (a)      Contemporaneously with the execution of this Agreement, Borrower shall pay Lender a nonrefundable upfront fee in the amount set forth in the fee letter provided by Lender to Borrower.
 
         (b)      Borrower shall pay to Lender a utilization fee equal to 25/100 Percent (0.25%) per annum times the Total Revolving Credit Outstandings on each day that the Total Revolving Credit Outstandings exceed Thirty Three Percent (33%) of the actual amount of Lender’s Revolving Credit Commitment then in effect (or, if terminated, in effect immediately prior to such termination).  Such utilization fee shall be due and payable quarterly in arrears on the last day of each calendar quarter, commencing with the first such date to occur after the effective date of this Agreement, and on the last day of the Revolving Credit Period (and if applicable, thereafter on demand).
 
 
 
- 8 -
 
 
 
         (c)      From and including the date of this Agreement to but excluding the last day of the Revolving Credit Period, Borrower shall pay a nonrefundable commitment fee on the unused portion of Lender’s Revolving Credit Commitment (determined by subtracting the Total Revolving Credit Outstandings from the amount of Lender’s Revolving Credit Commitment) at a percentage rate equal to the Applicable Commitment Fee Rate.  Said commitment fee shall be (i) calculated on a daily basis, (ii) payable quarterly in arrears on each June 30, September 30, December 31, and March 31 during the Revolving Credit Period commencing December 31, 2010, and on the last day of the Revolving Credit Period and (iii) calculated on an actual day, 360-day year basis.
 
         2.08    Prepayments .  Borrower may, upon notice to Lender specifying that it is paying any Daily Reset Loan, pay without penalty or premium such Daily Reset Loan in whole at any time or in part from time to time, by paying the principal amount to be paid, provided that partial prepayments shall be in an aggregate amount of at least $1,000,000.00 or any larger multiple of $500,000.00.  Borrower may, upon at least three (3) New York Business Day’s irrevocable prior written notice to Lender, prepay all at any time or any portion from time to time of the unpaid principal balance of any LIBOR Loan prior to maturity provided that (i) contemporaneously with each such prepayment Borrower shall pay all accrued and unpaid interest on the portion of the LIBOR Loan being prepaid to and including the date of prepayment; (ii) partial prepayments shall be in an aggregate amount of at least $2,000,000.00 or any larger multiple of $1,000,000.00; (iii) in no event may Borrower make any prepayment on any LIBOR Loan that results in the remaining LIBOR Loans with respect to which a given Interest Period applies being greater than $0.00 but less than $1,000,000.00 and (iv) if Borrower is making a prepayment of a LIBOR Loan, contemporaneously with such prepayment, Borrower shall pay Lender the funding losses and other amounts, if any, required under Section 2.10.
 
         2.09    General Provisions as to Payments .  Borrower shall make each payment of principal of, and interest on, the Loan and of fees and all other amounts payable by Borrower under this Agreement, not later than 12:00 noon (St. Louis time) on the date when due and payable in Federal or other funds immediately available in St. Louis, Missouri, to Lender at its address referred to in Section 7.05.  All payments received by Lender after 12:00 noon (St. Louis time) shall be deemed to have been received by Lender on the next succeeding Business Day. Whenever any payment of principal of, or interest on, the Loan or of fees shall be due on a day which is not a Business Day, the date for payment thereof shall be extended to the next succeeding Business Day.  If the date for any payment of principal is extended by operation of law or otherwise, interest thereon, at the then applicable rate, shall be payable for such extended time.
 
         2.10    Funding Losses .  Notwithstanding any provision contained in this Agreement to the contrary, (a) Borrower shall make any payment of principal with respect to any LIBOR Loan on any day other than the last day of the Interest Period applicable thereto, whether as a result of a scheduled payment, a voluntary prepayment, a mandatory prepayment, maturity, acceleration or otherwise or (b) any LIBOR Loan is converted to a Daily Reset Loan pursuant to Section 2.04, Section 2.11 or Section 2.12 on any day other than the last day of the Interest Period applicable thereto, contemporaneously with each such payment or conversion Borrower shall reimburse Lender on demand for any resulting losses and expenses incurred by Lender, including , without limitation, any losses incurred in obtaining, liquidating, or employing deposits from third parties, but excluding any loss of the Applicable Margin for the period after any such prepayment, provided that Lender shall have delivered to Borrower a certificate as to the amount of such losses and expenses, which certificate shall be conclusive in the absence of manifest error.
 
         2.11    Basis for Determining Interest Rate Inadequate or Unfair .  If with respect to any Interest Period:  (a) deposits in U.S. Dollars (in the applicable amounts) are not being offered to Lender in the relevant market for such Interest Period, or (b) Lender determines in good faith that the LIBOR Rate as determined pursuant to the definition thereof will not adequately and fairly reflect the cost to Lender of
 
 
 
- 9 -
 
 
 
maintaining or funding the LIBOR Loans for such Interest Period, Lender shall forthwith give notice thereof to Borrower whereupon until Lender notifies Borrower that the circumstances giving rise to such suspension no longer exist, (i) the LIBOR Rate shall not be available to Borrower as an interest rate option on any portion of the Loan and (ii) all of the then outstanding LIBOR Loans shall automatically convert to Daily Reset Loans on the last day of the then current Interest Period applicable to each such LIBOR Loan. Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10.
 
         2.12    Illegality .  If, after the date of this Agreement, the adoption of any applicable law, rule or regulation, or any change therein, or any change in the interpretation or administration thereof by any governmental or regulatory authority, central bank or comparable agency charged with the interpretation or administration thereof, or compliance by Lender with any request or directive (whether or not having the force of law) of any such governmental or regulatory authority, central bank or comparable agency (a “ Regulatory Change ”) shall make it unlawful or impossible for Lender to make, maintain or fund its LIBOR Loans to Borrower, Lender shall forthwith give notice thereof to Borrower.  Upon receipt of such notice, Borrower shall convert all of its then outstanding LIBOR Loans on either (a) the last day of the then current Interest Period applicable to such LIBOR Loan if Lender may lawfully continue to maintain and fund such LIBOR Loan to such day or (b) immediately if Lender may not lawfully continue to fund and maintain such LIBOR Loan to such day, to a Daily Reset Loan in an equal principal amount.  Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10.
 
         2.13    Increased Cost .  (a)  If (i) Regulation D or (ii)  a Regulatory Change:  (A) shall subject Lender to any tax, duty or other charge with respect to the LIBOR Loans, the Note or its obligation to make LIBOR Loans, or shall change the basis of taxation of payments to Lender of the principal of or interest on its LIBOR Loans or any other amounts due under this Agreement in respect of its LIBOR Loans or its obligation to make LIBOR Loans (except for taxes on or changes in the rate of tax on the overall net income of Lender); or (B) shall impose, modify or deem applicable any reserve (including, without limitation, any reserve imposed by the Board of Governors of the Federal Reserve System), special deposit, capital or similar requirement against assets of, deposits with or for the account of, or credit extended or committed to be extended by, Lender or shall, with respect to Lender impose, modify or deem applicable any other condition affecting Lender’s LIBOR Loans, the Note or Lender’s obligation to make LIBOR Loans; and the result of any of the foregoing is to increase the cost to (or in the case of Regulation D, to impose a cost on or increase the cost to) Lender of making or maintaining any LIBOR Loan, or to reduce the amount of any sum received or receivable by Lender under this Agreement or under its Note with respect thereto, by an amount deemed by Lender to be material, and if Lender is not otherwise fully compensated for such increase in cost or reduction in amount received or receivable by virtue of the inclusion of the reference to “LIBOR Reserve Percentage” in the calculation of the LIBOR Rate, then upon notice by Lender to Borrower, which notice shall set forth Lender’s supporting calculations and the details of the Regulatory Change, Borrower shall pay Lender, as additional interest, such additional amount or amounts as will compensate Lender for such increased cost or reduction.  The determination by Lender under this Section of the additional amount or amounts to be paid to it hereunder shall be conclusive in the absence of manifest error.  In determining such amount or amounts, Lender may use any reasonable averaging and attribution methods.
 
         (b)      If Lender demands compensation under Section 2.13(a) above, Borrower may at any time, upon at least three (3) New York Business Day’s prior notice to Lender, convert its then outstanding LIBOR Loans to Daily Reset Loans in an equal principal amount.  Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10 and this Section 2.13.
 
 
 
- 10 -
 
 
 
         2.14    Daily Reset Loans Substituted for Affected LIBOR Loans .  If notice has been given by Lender  pursuant to Sections 2.11 or 2.12 or by Borrower pursuant to Section 2.04 requiring LIBOR Loans to be repaid or converted to Daily Reset Loans, then, unless and until Lender notifies Borrower that the circumstances giving rise to such repayment or conversion no longer apply, any portion of the Loans that would otherwise be made by Lender to Borrower as LIBOR Loans shall be made instead as Daily Reset Loans.  Lender shall promptly notify Borrower if and when the circumstances giving rise to such repayment no longer apply.
 
         2.15    Capital Adequacy .  If, after the date of this Agreement, Lender shall have determined in good faith that a Regulatory Change has occurred which has or will have the effect of reducing the rate of return on Lender’s capital in respect of its obligations hereunder to a level below that which Lender could have achieved but for such adoption, change or compliance (taking into consideration Lender’s policies with respect to capital adequacy), then from time to time Borrower shall pay to Lender upon demand such additional amount or amounts as will compensate Lender for such reduction.  All determinations made in good faith by Lender of the additional amount or amounts required to compensate it in respect of the foregoing shall be conclusive in the absence of manifest error.  In determining such amount or amounts, Lender may use any reasonable averaging and attribution methods.
 
         2.16    Survival of Indemnities .  All indemnities and all provisions relating to reimbursement to Lender of amounts sufficient to protect the yield to Lender with respect to the Loan, including, without limitation, Sections 2.10, 2.13 and 2.15 hereof, shall survive the payment of the Note and the other Borrower’s Obligations and the expiration or termination of this Agreement.  Notwithstanding the foregoing, if Lender fails to notify Borrower of any event that will entitle Lender to compensation pursuant to Sections 2.10, 2.13 and/or 2.15 hereof within one hundred eighty (180) days after Lender obtains knowledge of such event, then Lender shall not be entitled to any compensation from Borrower for any loss, expense, increased cost and/or reduction of return arising from such event.
 
         2.17    Discretion of Lender as to Manner of Funding .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall be entitled to fund and maintain its funding of all or any part of its LIBOR Loans in any manner it elects, it being understood, however, that for purposes of this Agreement all determinations hereunder (including, without limitation, the determination of Lender’s funding losses and expenses under Section 2.10) shall be made as if Lender had actually funded and maintained each LIBOR Loan through the purchase of deposits having a maturity corresponding to the maturity of the applicable Interest Period relating to the applicable LIBOR Loan and bearing an interest rate equal to the applicable LIBOR Base Rate.
 
         2.18    Letters of Credit .
 
         (a)      Subject to the terms and conditions of this Agreement and so long as no Default or Event of Default has occurred and is continuing, during the Revolving Credit Period, Lender agrees to issue irrevocable commercial and/or standby letters of credit for the account of Borrower and/or any Subsidiary (individually, a “ Letter of Credit ”, and collectively, “ Letters of Credit ”) in an amount and for the term specifically requested by Borrower by notice in writing to Lender at least two (2) Business Days prior to the requested issuance thereof; provided , however , that: (i) Borrower shall have executed and delivered to Lender a Letter of Credit Application with respect to such Letter of Credit; (ii) the term of any such Letter of Credit shall not extend beyond the earlier of (A) the date one (1) year after the date of issuance thereof, or (B) the last day of the Revolving Credit Period; (iii) any Letter of Credit may only be utilized to guaranty the payment of obligations of Borrower or a Subsidiary to third parties; (iv) Total Revolving Credit Outstandings shall not as of any date exceed Lender’s Revolving Credit Commitment; and (v) the text of any such Letter of Credit is provided to Lender no less than two (2)
 
 
 
- 11 -
 
 
 
Business Days prior to the requested issuance date, which text must be acceptable to Lender in its sole and absolute discretion.
 
         (b)      The payment of drafts under each Letter of Credit shall be made in accordance with the terms thereof and, in that connection, Lender shall be entitled to honor any drafts and accept any documents presented to it by the beneficiary of such Letter of Credit in accordance with the terms of such Letter of Credit and the related Letter of Credit Application and believed in good faith by Lender to be genuine.  Lender shall not have any duty to inquire as to the accuracy or authenticity of any draft or other drawing document that may be presented to it other than the duties contemplated by the applicable Letter of Credit Application.
 
         (c)      In the event of any payment by Lender of a draft presented under a Letter of Credit, Borrower agrees to pay to Lender in immediately available funds at the time of such drawing an amount equal to the sum of such drawing plus the negotiation, processing and other fees related thereto, as may be agreed between Lender and Borrower from time to time.  Borrower hereby authorizes Lender to charge or cause to be charged one or more of Borrower’s deposit accounts at Lender to the extent there are balances of immediately available funds therein, in an aggregate amount equal to the sum of such drawing plus the negotiation, processing and other fees related thereto as may be agreed between Lender and Borrower from time to time, and Borrower agrees to pay the amount of any such drawing (and/or Lender’s customary negotiation, processing and other fees related thereto) not so charged prior to the close of business of Lender on the day of such drawing.  In the event any payment under a Letter of Credit is made by Lender prior to receipt of payment from Borrower, such payment by Lender shall constitute a request by Borrower for a Daily Reset Loan under Sections 2.01 and 2.02 above (and Lender will make such Daily Reset Loan to Borrower regardless of whether any Default or Event of Default under this Agreement has occurred and is continuing and regardless of whether such Daily Reset Loan would otherwise be permitted under the requirements of this Agreement) and the proceeds of such Daily Reset Loan shall be paid directly to Lender and applied by Lender to the payment of any amounts owed by Borrower to Lender under this Section 2.18.
 
         (d)      Borrower hereby further agrees to pay to the order of Lender with respect to each Letter of Credit: (i) a nonrefundable commitment fee at an annual rate equal to the Applicable Margin (calculated on an actual day, 360-day year basis) on the face amount (taking into account any scheduled increases or decreases therein during the period in question) of each Letter of Credit, due and payable quarterly, in arrears, on the last day of each fiscal quarter; and  (ii) a nonrefundable issuance fee, a nonrefundable negotiation fee and such other fees as may be charged by Lender from time to time in accordance with Lender’s published schedule of fees in effect from time to time, which fees shall be due and payable on demand by Lender.
 
         (e)      Notwithstanding any provision contained in this Agreement to the contrary, if any Letters of Credit remain outstanding on the last day of the Revolving Credit Period, Borrower shall, on or before 12:00 noon (St. Louis time) on the last day of the Revolving Credit Period, (i) surrender the originals of the applicable Letter(s) of Credit to Lender for cancellation, or (ii) provide Lender with cash collateral (or other collateral acceptable to Lender in its sole and absolute discretion) in an amount at least equal to the aggregate undrawn face amount of all outstanding Letter(s) of Credit plus all unreimbursed drawings with respect thereto, and execute and deliver to Lender such agreements as Lender may require to grant Lender a first priority perfected security interest in such cash or other collateral.  Any such cash collateral received by Lender pursuant to this Section 2.18(e) shall be held by Lender in a separate account at Lender appropriately designated as a cash collateral account in relation to this Agreement and the Letters of Credit and retained by Lender as collateral security for the payment of Borrower’s Obligations.  Cash amounts delivered to Lender pursuant to the foregoing requirements of this Section 2.18(e) shall be invested, at the request and for the account of Borrower in investments of a type and nature and with a term acceptable to Lender.  Such amounts, including in the case of cash amounts invested in the manner set forth above, shall not be used by Lender to pay any amounts
 
 
 
- 12 -
 
 
 
drawn or paid under or pursuant to any Letter of Credit, but may be applied to reimburse Lender for drawings or payments under or pursuant to such Letters of Credit which Lender has paid, or if no such reimbursement is required to the payment of such of the other Borrower’s Obligations as Lender shall determine.  Any amounts remaining in any cash collateral account established pursuant to this Section 2.18(e) after the payment in full of all of the Borrower’s Obligations and the expiration or cancellation of all of the Letters of Credit shall be returned to Borrower (after deduction of Lender’s reasonable expenses, if any).
 
         2.20    Taxes .
 
         (a)      Any and all payments by Borrower to or for the account of Lender under any Transaction Document shall be made free and clear of and without deduction for any and all present or future taxes, duties, levies, imposts, deductions, charges or withholdings, and all liabilities with respect thereto, excluding , in the case of Lender, taxes imposed on or measured by its net income, and franchise taxes imposed on it, by the jurisdiction under the laws of which Lender is organized or any political subdivision thereof (all such non-excluded taxes, duties, levies, imposts, deductions, charges, withholdings and liabilities being hereinafter referred to as “ Taxes ”).  If Borrower shall be required by law to deduct any Taxes from or in respect of any sum payable under any Transaction Document to Lender, (i) the sum payable shall be increased as necessary so that after making all required deductions (including deductions applicable to additional sums payable under this Section 2.20(a)) Lender receives an amount equal to the sum it would have received had no such deduction of Taxes been made, (ii) Borrower shall make such deductions, (iii) Borrower shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law and (iv) Borrower shall furnish to Lender the original or a certified copy of a receipt evidencing payment thereof.
 
         (b)      In addition, Borrower agrees to pay any present or future stamp or documentary taxes and any other excise or property taxes, or charges or similar levies which arise from any payment made under any of the Transaction Documents or from the execution or delivery of, or otherwise with respect to, any of the Transaction Documents (hereinafter referred to as “ Other Taxes ”).
 
         (c)      Borrower agrees to indemnify Lender for the full amount of Taxes or Other Taxes, respectively (including, without limitation, any Taxes or Other Taxes imposed or asserted by any jurisdiction on amounts payable under this Section 2.20), paid by Lender and any liability (including penalties, interest and expenses) arising therefrom or with respect thereto.  This indemnification shall be made within fifteen (15) days from the date Lender makes demand therefor, accompanied by a certificate of Lender setting forth in reasonable detail its computation of the amount or amounts to be paid to it hereunder.
 
         (d)      The provisions of this Section 2.20 shall survive any expiration or termination of this Agreement and the payment of the Note and the other Borrower’s Obligations.

SECTION 3.  PRECONDITIONS TO LOANS AND LETTERS OF CREDIT .
 
         3.01    Initial Loan .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall have no obligation to make the initial Loan or issue the initial Letter of Credit under this Agreement unless Lender shall have first received:
 
         (a)      this Agreement and the Note, each duly executed by Borrower;
 
         (b)      the Guaranty, duly executed by Laclede Energy;

 
- 13 -
 
 
 
         (c)      a copy of resolutions (including an incumbency certificate) of the Board of Directors of Borrower, duly adopted, which authorize the execution, delivery and performance of this Agreement, the Note and the other Transaction Documents, certified by the Secretary of Borrower;
 
         (d)      a copy of resolutions of the Board of Directors (including an incumbency certificate) of Laclede Energy, duly adopted, which authorize the execution, delivery and performance of its Guaranty, certified by the Secretary of Laclede Energy;
 
         (e)      copies of the Articles of Incorporation of Borrower and Laclede Energy, including any amendments thereto, certified by the Secretary of State of the states of their respective incorporations;
 
         (f)       copies of the Bylaws of Borrower and Laclede Energy, including any amendments thereto, certified by the Secretaries of Borrower and Laclede Energy;
 
         (g)      certificates of corporate good standing of Borrower and Laclede Energy issued by the Secretary of State of the states of their respective incorporations;
 
         (h)      an opinion of the General Counsel of Borrower and Laclede Energy, in form and substance satisfactory to Lender and Lender’s counsel;
 
         (i)     UCC search results from the Missouri Secretary of State for Borrower and Laclede Energy;
 
         (j)       copies of all financial statements and other exhibits and schedules required by this Agreement and the other Transaction Documents;
 
         (k)      a letter of direction from Borrower with respect to the disbursement of the proceeds of the initial Loan under this Agreement;
 
         (l)       a fee letter, duly executed by Borrower and Lender; and
 
         (m)     such other agreements, documents, instruments and certificates as Lender may reasonably request.
 
         3.02    All Loans and Letters of Credit .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall have no obligation to make any Loan or issue any Letter of Credit under this Agreement unless:
 
         (a)      Lender shall have received a Notice of Borrowing for such Loan as required by Section 2.02(a), or a Letter of Credit Application as required under Section 2.18(a);
 
         (b)      both immediately before and immediately after giving effect to such Loan or Letter of Credit, no Default or Event of Default shall have occurred and be continuing; and


 
 
- 14 -
 
 
 
         (c)      all of the representations and warranties made by Borrower in this Agreement (but after the making or issuance of the initial Loan or Letter of Credit hereunder, not including the representation set forth in Section 4.04(b)) and/or in any other Transaction Document shall be true and correct in all material respects on and as of the date of such Loan as if made or such Letter of Credit is issued on and as of the date of such Loan or Letter of Credit (and for purposes of this Section 3.02(c), the representations and warranties made by Borrower in Section 4.04 shall be deemed to refer to the most recent financial statements of Borrower delivered to Lender pursuant to Section 5.01(a)).

Each request for a Loan or Letter of Credit by Borrower under this Agreement shall be deemed to be a representation and warranty by Borrower on the date of such Loan or Letter of Credit as to the facts specified in clauses (b) and (c) of this Section 3.02.

SECTION 4.  REPRESENTATIONS AND WARRANTIES .
 
         Borrower hereby represents and warrants to Lender that:
 
         4.01    Corporate Existence and Power .  Each Loan Party: (a) is duly incorporated, validly existing and in good standing under the laws of the State of Missouri; (b) has all requisite corporate powers required to carry on its business as now conducted; (c) has all requisite governmental and regulatory licenses, authorizations, consents and approvals required to carry on its business as now conducted, except such licenses, authorizations, consents and approvals the failure to have could not reasonably be expected to have a Material Adverse Effect; and (d) is qualified to transact business as a foreign corporation in, and is in good standing under the laws of, all states in which it is required by applicable law to maintain such qualification and good standing except for those states in which the failure to qualify or maintain good standing could not reasonably be expected to have a Material Adverse Effect.
 
         4.02    Corporate Authorization .  The execution, delivery and performance by each Loan Party of this Agreement, the Note and the other Transaction Documents, as applicable, are within the corporate powers of each Loan Party and have been duly authorized by all necessary corporate and other action on the part of each Loan Party.
 
         4.03    Binding Effect .  This Agreement, the Note and the other Transaction Documents to which a Loan Party is a party have been duly executed and delivered by such Loan Party and constitute the legal, valid and binding obligations of such Loan Party enforceable against such Loan Party in accordance with their respective terms, except as such enforceability may be limited by bankruptcy, insolvency or other similar laws affecting creditors’ rights generally and by general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).
 
         4.04    Financial Statements .  Borrower has furnished Lender with the consolidated balance sheets and statements of income, retained earnings and cash flows of Borrower and its Subsidiaries as of and for the fiscal year of Borrower ended September 30, 2009, all certified by Borrower’s independent certified public accountants, which financial statements have been prepared in accordance with GAAP consistently applied.  Borrower further represents and warrants to Lender that (a) said balance sheets and their accompanying notes (if any) fairly present the condition of Borrower and its Subsidiaries as of the dates thereof, (b) there has been no material adverse change in the condition or operation, financial or otherwise, of Borrower and its Subsidiaries taken as a whole since September 30, 2009 except as disclosed in Borrower’s filings with the Securities and Exchange Commission since such date, and (c) neither Borrower nor any of its Subsidiaries had any direct or contingent liabilities which were not disclosed on said financial statements or the notes thereto (to the extent such disclosure is required by GAAP).
 
 
 
- 15 -
 
 
 
         4.05    Compliance With Other Instruments; None Burdensome .  None of the execution and delivery by a Loan Party of any of the Transaction Documents, the performance by a Loan Party of its obligations under the Transaction Documents or the borrowing and/or repayment of the Loan by Borrower under this Agreement will conflict with, or result in a breach of the terms, conditions or provisions of, or constitute a default under or result in any violation of, any law, rule, regulation, order, writ, judgment, injunction, decree or award binding on such Loan Party, any of the provisions of the Articles of Incorporation or Bylaws (or other applicable organizational documents) of such Loan Party or any of the provisions of any indenture, agreement, document, instrument or undertaking to which such Loan Party is a party or subject, or by which such Loan Party or any property or assets of such Loan Party is bound, or result in the creation or imposition of any security interest, lien or encumbrance on any of the property or assets of such Loan Party pursuant to the terms of any such indenture, agreement, document, instrument or undertaking.  No order, consent, approval, license, authorization or validation of, or filing, recording or registration with, or exemption by, any governmental, regulatory, administrative or public body, instrumentality, authority, agency or official, or any subdivision thereof, or any other Person is required to authorize, or is required in connection with, (a) the execution, delivery or performance of, or the legality, validity, binding effect or enforceability of, any of the Transaction Documents, and/or (b) the borrowing and/or repayment of the Loan by Borrower under this Agreement.
 
         4.06    Regulation U .  Borrower is not engaged principally, or as one of its important activities, in the business of extending credit for the purpose of purchasing or carrying margin stock (within the meaning of Regulation U of The Board of Governors of the Federal Reserve System, as amended) and no part of the proceeds of the Loan will be used, whether directly or indirectly, and whether immediately, incidentally or ultimately (a) to purchase or carry margin stock or to extend credit to others for the purpose of purchasing or carrying margin stock, or to refund or repay indebtedness originally incurred for such purpose or (b) for any purpose that entails a violation of, or which is inconsistent with, the provisions of any of the Regulations of The Board of Governors of the Federal Reserve System, including, without limitation, Regulations U, T or X thereof, as amended.  If requested by Lender, Borrower shall furnish to Lender a statement in conformity with the requirements of Federal Reserve Form U-1 referred to in Regulation U.
 
         4.07    Investment Company Act of 1940; Public Utility Holding Company Act of 2005 .  Borrower is not an “investment company” as that term is defined in, and is not otherwise subject to regulation under, the Investment Company Act of 1940, as amended. Borrower is a holding company for which compliance with the accounting, record retention and reporting sections of the Public Utility Holding Company Act of 2005 has been waived.
 
         4.08    No Default .  No Default or Event of Default under this Agreement has occurred and is continuing.  There is no existing default or event of default under or with respect to any indenture, contract, agreement, lease or other instrument to which Borrower is a party or by which any property or assets of any Loan Party is bound or affected, a default under which could reasonably be expected to have a Material Adverse Effect.  Each Loan Party has and is in full compliance with and in good standing with respect to all governmental permits, licenses, certificates, consents and franchises necessary to continue to conduct its business as previously conducted by it and to own or lease and operate its properties and assets as now owned or leased by it, the failure to have or noncompliance with which could reasonably be expected to have a Material Adverse Effect.  No Loan Party is in violation of any applicable statute, law, rule, regulation or ordinance of the United States of America, of any state, city, town, municipality, county or of any other jurisdiction, or of any agency thereof, a violation of which could reasonably be expected to have a Material Adverse Effect.



 
 
- 16 -
 
 

SECTION 5.  COVENANTS .
 
         5.01    Covenants of Borrower .  Borrower covenants and agrees that, so long as any of the Borrower’s Obligations remain unpaid:
 
         (a)      Information.  Borrower will make available, deliver, or cause to be delivered to Lender:
 
         (i)       within one hundred twenty (120) days after the end of each fiscal year of Borrower the consolidated balance sheet of Borrower and its Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, retained earnings and cash flows for such fiscal year, setting forth in each case, in comparative form, the figures for the previous fiscal year, all such financial statements to be prepared in accordance with GAAP consistently applied and reported on by and accompanied by the unqualified opinion of independent certified public accountants selected by Borrower and reasonably acceptable to Lender; provided, however, that delivery to Lender of the Annual Report on Form 10-K of Borrower for such fiscal year filed with the Securities and Exchange Commission shall be deemed to satisfy the requirements of this Section 5.01(a)(i);
 
         (ii)      within one hundred twenty (120) days after the end of each fiscal year of Laclede Energy the consolidated balance sheets of Laclede Energy and its Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, retained earnings and cash flows for such fiscal year, setting forth in each case, in comparative form, the figures for the previous fiscal year, all such financial statements to be prepared internally by Laclede Energy in accordance with GAAP consistently applied.
 
         (iii)      within fifty (50) days after the end of the first three (3) fiscal quarters of each fiscal year of Borrower, a consolidated balance sheet of Borrower and its Subsidiaries as of the end of such fiscal quarter and the related consolidated statements of income, retained earnings and cash flows for such fiscal quarter and for the portion of Borrower’s fiscal year ended at the end of such fiscal quarter, setting forth in each case in comparative form, the figures for the corresponding fiscal quarter and the corresponding portion of Borrower’s previous fiscal year, all in reasonable detail and satisfactory in form to Lender and certified (subject to normal year-end adjustments and absence of footnote disclosures) as to fairness of presentation, consistency and compliance with GAAP by the chief financial officer of Borrower; provided, however, that delivery to Lender of copies of the Quarterly Report on Form 10-Q of Borrower for such fiscal quarter filed with the Securities and Exchange Commission shall be deemed to satisfy the requirements of this Section 5.01(a)(iii);
 
         (iv)      within the time frames outlined in Sections 5.01(a)(i) and 5.01(a)(iii) above, a certificate of an authorized officer of Borrower in the form attached hereto as Exhibit B and incorporated herein by reference (A) stating whether there exists on the date of such certificate any Default or Event of Default and, if any Default or Event of Default then exists, setting forth the details thereof and the action which Borrower is taking or proposes to take with respect thereto, (B) certifying that all of the representations and warranties made by Borrower in this Agreement and/or in any other Transaction Document are true and correct in all material respects on and as of the date of such certificate as if made on and as of the date of such certificate, and (C) setting forth the Consolidated Capitalization Ratio for the relevant reporting period;
 
         (v)      with reasonable promptness, such further information regarding the business, affairs and financial condition of Borrower as Lender may from time to time reasonably request.
 
         (b)      Corporate Existence.  Borrower will do all things necessary to (i) preserve and keep in full force and effect at all times its corporate existence and all permits, licenses, franchises and other rights material to its business and (ii) be duly qualified to do business and be in good standing in all jurisdictions where the nature of its business or its ownership of property or assets requires such
 
 
- 17 -
 
 
 
qualification except for those jurisdictions in which the failure to qualify or be in good standing could not reasonably be expected to have a Material Adverse Effect.
 
         (c)     Compliance with Laws, Regulations, Etc.   Borrower will comply with any and all laws, ordinances and governmental and regulatory rules and regulations to which Borrower is subject and obtain any and all licenses, permits, franchises and other governmental and regulatory authorizations necessary to the ownership of its properties or assets or to the conduct of its business, which violation or failure to obtain could reasonably be expected to have a Material Adverse Effect.
 
         (d)     Further Assurances .  Borrower will execute and deliver to Lender, at any time and from time to time, any and all further agreements, documents and instruments, and take any and all further actions which may be required under applicable law, or which Lender may from time to time reasonably request, in order to effectuate the transactions contemplated by this Agreement and the other Transaction Documents.
 
         (e)     Consolidation or Merger .  Borrower will not directly or indirectly merge or consolidate with or into any other Person.
 
         (f)     Stock and Assets of Subsidiaries .  Unless the prior written consent of Lender is obtained which such consent shall not be unreasonably withheld (in Lender’s commercially reasonable judgment) or unreasonably delayed, Borrower will not create, incur or assume or suffer to be incurred or to exist any security interest, lien or encumbrance on any of the common stock of LGC, Laclede Energy, or any other Subsidiary, or on the inventory or accounts receivable of LGC.
 
         (g)     Sale of Property .  Borrower will not, and will not cause or permit any Subsidiary to, (i) sell, assign, lease, transfer, abandon or otherwise dispose of any of its property (including, without limitation, any shares of capital stock or other equity interests of a Subsidiary owned by Borrower or another Subsidiary) or (ii) issue, sell or otherwise dispose of any shares of capital stock or other equity interests of any Subsidiary; provided , however , that Borrower and each Subsidiary may sell, assign, lease, transfer, abandon or otherwise dispose of (A) any of its natural gas inventory or past-due accounts receivable in the ordinary course of business, (B) any of its property to Borrower or any Subsidiary, provided that , if at anytime more than Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries are transferred to a Subsidiary, such Subsidiary shall then execute a guaranty agreement with respect to Borrower’s Obligations in a form reasonably acceptable to Lender, (C) any of its property subject to LGC’s Mortgage and Deed of Trust dated as of February 1, 1945, as heretofore amended and supplemented, as may be permitted to be sold, assigned, leased, transferred, abandoned or otherwise disposed of under said Mortgage and Deed of Trust, (D) any of its other property (whether in one transaction or a series of transactions) so long as the value of such property sold, assigned, leased, transferred, abandoned or otherwise disposed of in any fiscal year under this subsection (D) shall not exceed Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries as determined on a consolidated basis as of the last day of the immediately preceding fiscal year, and (E) any shares of capital stock sold to Borrower by a Subsidiary; and provided further , however, that nothing in this Agreement shall limit or restrict Borrower’s or any Subsidiary’s use of financial instruments or natural gas contracts under their gas supply risk management programs.
 
         (h)     Changes in Nature of Business .  Borrower will not, and it will not cause or permit any Subsidiary to, engage in any business if, as a result, the general nature of the business that would then be engaged in by Borrower and its Subsidiaries, considered as a whole, would be substantially changed from the general nature of the business engaged in by Borrower and its Subsidiaries as of the date of this Agreement.
 
 
 
- 18 -
 
 
 
         (i)     Permitted Investments; Acquisitions .  Borrower will not, and it will not cause or permit any Subsidiary to, directly or indirectly, make any Investments except for Permitted Investments.  Borrower will not, and it will not cause or permit any Subsidiary to, directly or indirectly, make any Acquisition the result of which would be to change substantially the general nature of the business engaged in by Borrower and its Subsidiaries.
 
         (j)     Maximum Consolidated Capitalization Ratio .  Borrower will at all times maintain a Consolidated Capitalization Ratio of not more than Seventy Percent (70%).
 
         (k)     Subsidiaries .  If Borrower creates, forms or acquires any Subsidiary which owns more than Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries on or after the date of this Agreement, Borrower will, contemporaneously with the creation, formation or acquisition of such Subsidiary, cause such Subsidiary to execute a guaranty agreement with respect to Borrower’s Obligations in a form reasonably acceptable to Lender.
 
         5.02    Use of Proceeds .  Borrower covenants and agrees that (a) the proceeds of the Loan will be used solely for general corporate purposes, (b) no part of the proceeds of the Loan will be used in violation of any applicable law, rule or regulation and (c) no part of the proceeds of the Loan will be used, whether directly or indirectly, and whether immediately, incidentally or ultimately (i) to purchase or carry margin stock or to extend credit to others for the purpose of purchasing or carrying margin stock, or to refund or repay indebtedness originally incurred for such purpose or (ii) for any purpose which entails a violation of, or which is inconsistent with, the provisions of any of the Regulations of The Board of Governors of the Federal Reserve System, including, without limitation, Regulations U, T or X thereof, as amended.

SECTION 6.  EVENTS OF DEFAULT .
 
         If any of the following (each of the following herein sometimes called an “ Event of Default ”) shall occur and be continuing:
 
         6.01     Borrower shall fail to pay any of Borrower’s Obligations constituting interest, fees or other amounts (other than principal due under the Loan) within ten (10) Business Days after the date the same shall first become due and payable, whether by reason of demand, maturity, acceleration or otherwise;
 
         6.02     Any representation or warranty made by any Loan Party in this Agreement, in any other Transaction Document or in any certificate, agreement, instrument or written statement furnished or made or delivered pursuant hereto or thereto or in connection herewith or therewith, shall prove to have been untrue or incorrect in any material respect when made or effected;
 
         6.03     Borrower shall fail to perform or observe any term, covenant or provision contained in Section 5.01(e) or Section 5.02;
 
         6.04     Borrower shall fail to perform or observe any other term, covenant or provision contained in this Agreement (other than those specified in Sections 6.01 or 6.02 above) and any such failure shall remain unremedied for thirty (30) days after the earlier of (i) written notice of default is given to Borrower by Lender or (ii) any officer of Borrower obtaining actual knowledge of such default;
 
         6.05     This Agreement or any of the other Transaction Documents shall at any time for any reason (other than termination of this Agreement or such other Transaction Documents, as the case may be, in accordance with its terms) cease to be in full force and effect or shall be declared to be null and void by a court of competent jurisdiction, or if the validity or enforceability thereof shall be contested or denied by any Loan Party, or if the transactions completed hereunder or thereunder shall be
 
 
- 19 -
 
 
 
contested by any such Loan Party or if any Loan Party shall deny that it has any further liability or obligation hereunder or thereunder;
 
         6.06     A Loan Party shall (i) voluntarily commence any proceeding or file any petition seeking relief under Title 11 of the United States Code or any other Federal, state or foreign bankruptcy, insolvency, receivership, liquidation or similar law, (ii) consent to the institution of, or fail to contravene in a timely and appropriate manner, any such proceeding or the filing of any such petition, (iii) apply for or consent to the appointment of a receiver, trustee, custodian, sequestrator or similar official of itself or of a substantial part of its property or assets, (iv) file an answer admitting the material allegations of a petition filed against itself in any such proceeding, (v) make a general assignment for the benefit of creditors, (vi) become unable, admit in writing its inability or fail generally to pay its debts as they become due or (vii) take any corporate or other action for the purpose of effecting any of the foregoing;
 
         6.07     An involuntary proceeding shall be commenced or an involuntary petition shall be filed in a court of competent jurisdiction seeking (i) relief in respect of a Loan Party, or of a substantial part of the property or assets of a Loan Party, under Title 11 of the United States Code or any other Federal, state or foreign bankruptcy, insolvency, receivership, liquidation or similar law, (ii) the appointment of a receiver, trustee, custodian, sequestrator or similar official of Borrower or of a substantial part of the property or assets of a Loan Party or (iii) the winding-up or liquidation of a Loan Party, and such proceeding or petition shall continue undismissed for sixty (60) consecutive days or an order or decree approving or ordering any of the foregoing shall continue unstayed and in effect for sixty (60) consecutive days;
 
         6.08     Any Loan Party shall be declared by Lender to be in default under or in respect of (i) any other present or future obligation to Lender, including, without limitation, any other loan, line of credit, revolving credit, guaranty or letter of credit reimbursement obligation, or (ii) any other present or future agreement purporting to convey to Lender a security interest in, or a lien or encumbrance upon, upon any property or assets of any Loan Party;
 
         6.09     Any default occurs under any other financing agreement any Loan Party has with Lender or any affiliate of Lender, after giving effect to any applicable grace or cure periods; the occurrence of any default or event of default under or within the meaning of any agreement, document or instrument evidencing, securing, guaranteeing the payment of or otherwise relating to any indebtedness of any Loan Party for borrowed money (other than Borrower’s Obligations) having an aggregate outstanding principal balance in excess of $10,000,000.00 that is not cured or waived in writing within any applicable cure or grace period; or
 
         6.10      Any Loan Party shall have a judgment in an amount in excess of $15,000,000.00 entered against it by a court having jurisdiction in the premises and such judgment shall not be appealed in good faith (and execution of such judgment stayed during such appeal) or satisfied by such Loan Party within thirty (30) days after the entry of such judgment;

THEN, and in each such event (other than an event described in Sections 6.06 or 6.07), Lender may declare the entire outstanding principal balance of and all accrued and unpaid interest on the Note and all of the other Borrower’s Obligations to be forthwith due and payable, whereupon all of the unpaid principal balance of and all accrued and unpaid interest on the Note and all of such other Borrower’s Obligations shall become and be immediately due and payable, without presentment, demand, protest or further notice of any kind, all of which are hereby expressly waived by Borrower, and Lender may exercise any and all other rights and remedies which it may have under any of the other Transaction Documents or under applicable law; provided , however , that upon the occurrence of any event described in Sections 6.06 or 6.07, the entire outstanding principal balance of and all accrued and unpaid interest on the Note and all of the other Borrower’s Obligations shall automatically become immediately due and payable, without presentment, demand, protest or further notice of any kind, all of
 
 
- 20 -
 
 
 
which are hereby expressly waived by Borrower, and Lender may exercise any and all other rights and remedies which it may have under any of the other Transaction Documents or under applicable law.

SECTION 7.  GENERAL .
 
         7.01    No Waiver .  No failure or delay by Lender in exercising any right, remedy, power or privilege under this Agreement or under any other Transaction Document shall operate as a waiver thereof; nor shall any single or partial exercise thereof preclude any other or further exercise thereof or the exercise of any other right, remedy, power or privilege.  The rights and remedies provided in this Agreement and in the other Transaction Documents are cumulative and not exclusive of any remedies provided by law.  Nothing herein contained shall in any way affect the right of Lender to exercise any statutory or common law right of banker’s lien or set-off.
 
         7.02    Right of Set-Off .  Upon the occurrence and during the continuance of any Event of Default, Lender is hereby authorized at any time and from time to time, without notice to Borrower (any such notice being expressly waived by Borrower) and to the fullest extent permitted by law, to set-off and apply any and all deposits (general or special, time or demand, provisional or final, but specifically excluding any trust or segregated accounts) at any time held by Lender and any and all other indebtedness at any time owing by Lender to or for the credit or account of Borrower against any and all of the Borrower’s Obligations irrespective of whether or not Lender shall have made any demand under this Agreement or under any of the other Transaction Documents and although such obligations may be contingent or unmatured.  Lender agrees to promptly notify Borrower after any such set-off and application made by Lender, provided , however , that the failure to give such notice shall not affect the validity of such set-off and application.  The rights of Lender under this Section 7.02 are in addition to any other rights and remedies (including, without limitation, other rights of set-off) which Lender may have.  Nothing contained in this Agreement or any other Transaction Document shall impair the right of Lender to exercise any right of set-off or counterclaim it may have against Borrower and to apply the amount subject to such exercise to the payment of indebtedness of Borrower unrelated to this Agreement or the other Transaction Documents.
 
         7.03    Cost and Expenses .  Borrower agrees, whether or not any Loan is made under this Agreement, to pay or reimburse Lender upon demand for (a) all out-of-pocket costs and expenses incurred by Lender in connection with the preparation, documentation, negotiation and/or execution of this Agreement and/or any of the other Transaction Documents, (b) all recording, filing and search fees and expenses incurred by Lender in connection with this Agreement and/or any of the other Transaction Documents, (c) all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Lender in connection with the (i) the preparation, documentation, negotiation and execution of any amendment, modification, extension, renewal or restatement of this Agreement and/or any of the other Transaction Documents or (ii) the preparation of any waiver or consent under this Agreement or under any of the other Transaction Documents and (d) if an Event of Default occurs, all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Lender in connection with such Event of Default and collection and other enforcement proceedings resulting therefrom. Borrower further agrees to pay or reimburse Lender upon demand for any stamp or other similar taxes which may be payable with respect to the execution, delivery, recording and/or filing of this Agreement and/or any of the other Transaction Documents.  All of the obligations of Borrower under this Section 7.03 shall survive the satisfaction and payment of the Borrower’s Obligations and the termination of this Agreement.
 
         7.04    General Indemnity .  In addition to the payment of expenses pursuant to Section 7.03, whether or not the transactions contemplated hereby shall be consummated, Borrower hereby agrees to defend, indemnify, pay and hold Lender and any holders of the Note, and the officers, directors, employees, agents and affiliates of Lender and such holders (collectively, the “ Indemnitees ”) harmless from and against any and all other liabilities, obligations, losses, damages, penalties, actions,
 
 
- 21 -
 
 
 
judgments, suits, claims, disbursements, costs and expenses of any kind or nature whatsoever (including, without limitation, the reasonable fees and disbursements of counsel for such Indemnitees in connection with any investigative, administrative or judicial proceeding commenced or threatened, whether or not such Indemnitees shall be designated a party thereto, provided that the Indemnitees shall share counsel to defend their interests to the extent legally practicable), that may be imposed on, incurred by or asserted against the Indemnitees, in any manner relating to or arising out of this Agreement, any of the other Transaction Documents or any other agreement, document or instrument executed and delivered by Borrower in connection herewith or therewith, the statements contained in any commitment letters delivered by Lender, the agreement of Lender to make the Loans under this Agreement or the use or intended use of the proceeds of any Loan under this Agreement (collectively, the “ Indemnified Liabilities ”); provided that (a) the Indemnitees shall promptly (and in any event within fifteen (15) Business Days after receiving notice of the existence of any potential Indemnified Liabilities) notify Borrower in writing of the existence of any potential Indemnified Liabilities; (b) Borrower shall have the right to assume and thereafter conduct the defense of any Indemnified Liabilities with counsel of its choice reasonably satisfactory to the Indemnitees, provided that Borrower will not consent to the entry of any judgment or enter into any settlement with respect to any Indemnified Liabilities without the prior written consent of the Indemnitees (not to be unreasonably withheld) unless the judgment or proposed settlement fully releases such Indemnitees and involves only the payment of money damages that are covered in full by this indemnity and does not impose an injunction or other equitable relief upon any Indemnitee and is subject to confidentiality provisions acceptable to the Indemnitees (which approval will not be unreasonably withheld by the Indemnitees); and (c) Borrower shall have no obligation to an Indemnitee hereunder with respect to Indemnified Liabilities directly resulting from the gross negligence or willful misconduct of that Indemnitee as determined by a court of competent jurisdiction in a final, nonappealable order.  To the extent that the undertaking to indemnify, pay and hold harmless set forth in the preceding sentence may be unenforceable because it is violative of any law or public policy, Borrower shall contribute the maximum portion that it is permitted to pay and satisfy under applicable law to the payment and satisfaction of all Indemnified Liabilities incurred by the Indemnitees or any of them.  The provisions of the undertakings and indemnification set out in this Section 7.04 shall survive satisfaction and payment of Borrower’s Obligations and the termination of this Agreement.
 
         7.05    Notices .  Each notice, request, demand, consent, confirmation or other communication under this Agreement shall be in writing and delivered in person or sent by facsimile or registered or certified mail, return receipt requested and postage prepaid, to the applicable party at its address or facsimile number set forth on the signature pages hereof, or at such other address or facsimile number as any party hereto may designate as its address for communications hereunder by notice so given.  Such notices shall be deemed effective on the day on which delivered or sent if delivered in person or sent by facsimile (with answerback confirmation received), or on the fourth (4th) Business Day after the day on which mailed, if sent by registered or certified mail.
 
         7.06    Consent to Jurisdiction; Waiver of Jury Trial .  BORROWER IRREVOCABLY SUBMITS TO THE NON-EXCLUSIVE JURISDICTION OF ANY MISSOURI STATE COURT SITTING IN THE COUNTY OF ST. LOUIS, MISSOURI OR ANY UNITED STATES OF AMERICA COURT SITTING IN THE EASTERN DISTRICT OF MISSOURI, EASTERN DISTRICT, AS LENDER MAY ELECT, IN ANY SUIT, ACTION OR PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT OR ANY OTHER TRANSACTION DOCUMENT.  BORROWER HEREBY IRREVOCABLY AGREES THAT ALL CLAIMS IN RESPECT TO SUCH SUIT, ACTION OR PROCEEDING MAY BE HELD AND DETERMINED IN ANY OF SUCH COURTS.  BORROWER IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY LAW, ANY OBJECTION THAT BORROWER MAY NOW OR HEREAFTER HAVE TO THE LAYING OF VENUE OF ANY SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT, AND BORROWER FURTHER IRREVOCABLY WAIVES ANY CLAIM THAT SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT HAS BEEN BROUGHT IN AN INCONVENIENT FORUM. BORROWER AUTHORIZES THE SERVICE OF
 
 
- 22 -
 
 
 
PROCESS UPON BORROWER BY REGISTERED MAIL SENT TO BORROWER AT ITS ADDRESS DETERMINED PURSUANT TO SECTION 7.05.   BORROWER AND LENDER HEREBY IRREVOCABLY WAIVE THE RIGHT TO TRIAL BY JURY WITH RESPECT TO ANY ACTION IN WHICH BORROWER AND LENDER ARE PARTIES RELATING TO OR ARISING OUT OF OR IN CONNECTION WITH THIS AGREEMENT OR ANY OF THE OTHER TRANSACTION DOCUMENTS.
 
         7.07    Governing Law .  This Agreement shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).
 
         7.08    Amendments and Waivers .  Any provision of this Agreement, the Note or any of the other Transaction Documents to which Borrower is a party may be amended or waived if, but only if, such amendment or waiver is in writing and is signed by Borrower and Lender.
 
         7.09    References; Headings for Convenience .  Unless otherwise specified herein, all references herein to Section numbers refer to Section numbers of this Agreement, all references herein to Exhibits A and B refer to annexed Exhibits A and B that are hereby incorporated herein by reference and all references herein to Schedule 2.02 refers to annexed Schedule 2.02 that is hereby incorporated herein by reference.  The Section headings are furnished for the convenience of the parties and are not to be considered in the construction or interpretation of this Agreement.

7.10        Successors and Assigns .  The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns, except that Borrower may not assign or otherwise transfer any of its rights or delegate any of its obligations or duties under this Agreement.
 
         7.11    Notice Required by Section 432.047 R.S.Mo.; Entire Agreement .  This notice is provided pursuant to Section 432.047 R.S.Mo.  As used herein, “creditor” means Lender and “this writing” means this Agreement and the other Transaction Documents.   ORAL AGREEMENTS OR COMMITMENTS TO LOAN MONEY, EXTEND CREDIT OR TO FORBEAR FROM ENFORCING REPAYMENT OF A DEBT INCLUDING PROMISES TO EXTEND OR RENEW SUCH DEBT ARE NOT ENFORCEABLE, REGARDLESS OF THE LEGAL THEORY UPON WHICH IT IS BASED THAT IS IN ANY WAY RELATED TO THE CREDIT AGREEMENT. TO PROTECT YOU (BORROWER(S)) AND US (CREDITOR) FROM MISUNDERSTANDING OR DISAPPOINTMENT, ANY AGREEMENTS WE REACH COVERING SUCH MATTERS ARE CONTAINED IN THIS WRITING, WHICH IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN US, EXCEPT AS WE MAY LATER AGREE IN WRITING TO MODIFY IT.   This Agreement embodies the entire agreement and understanding between the parties hereto and supersedes all prior agreements and understandings (oral or written) relating to the subject matter hereof.
 
         7.12    Severability .  In the event any one or more of the provisions contained in this Agreement should be invalid, illegal or unenforceable in any respect, the validity, legality and enforceability of the remaining provisions contained herein shall not in any way be affected or impaired thereby.
 
         7.13    Counterparts .  This Agreement may be executed in any number of counterparts (including facsimile counterparts), each of which shall be deemed an original, but all of which together shall constitute one and the same instrument.
 
         7.14    Confidentiality .  Any information received by Lender from Borrower and clearly marked as confidential shall be treated as confidential by Lender in accordance with its customary practices and procedures.  Notwithstanding such agreement, nothing herein contained shall limit or impair the right or obligation of Lender to disclose such information: (a) to its auditors, attorneys, trustees, employees, directors, officers, advisors, affiliates or agents,  (b) when and as required by any law, ordinance, subpoena or governmental order, rule or regulation, (c) as may be required, requested or
 
 
- 23 -
 
 
 
otherwise appropriate in any report, statement or testimony submitted to any municipal, state, provincial or federal regulatory body or any self-regulatory body having or claiming to have jurisdiction over Lender, (d) which is publicly available or readily ascertainable from public sources, or which is received by Lender from a third Person which or which is not known by Lender to be bound to keep the same confidential, (e) in connection with any proceeding, case or matter pending (or on its face purported to be pending) before any court, tribunal or any governmental agency, commission, authority, board or similar entity, (f) in connection with protection of its interests under this Agreement, the Note or any of the other Transaction Documents, including, without limitation, the enforcement of the terms and conditions of this Agreement, the Note and the other Transaction Documents, or (g) to any entity utilizing such information to rate the creditworthiness of Lender or to rate or classify the debt or equity securities of Lender or report to the public concerning the industry of which such Lender is a part.  It is agreed and understood that Lender shall not be liable to Borrower or any other Person for failure to comply with the foregoing except in any case involving Lender’s gross negligence or willful misconduct as determined by a court of competent jurisdiction in a final, nonappealable order.
 
         7.15    USA PATRIOT Act Lender hereby notifies Borrower that pursuant to the requirements of the USA Patriot Act, Title III of Pub. L. 107-56 (signed into law October 26, 2001) (the “ Act ”), it is required to obtain, verify and record information that identifies Borrower, which information includes the name and address of Borrower and other information that will allow Lender to identify Borrower in accordance with the Act.

IN WITNESS WHEREOF, Borrower and Lender have executed this Agreement as of the day and year first above written.




[SIGNATURES ON FOLLOWING PAGE]




 
 
- 24 -
 
 

SIGNATURE PAGE-
REVOLVING CREDIT AGREEMENT



Borrower:
 
THE LACLEDE GROUP, INC.
   
By:
/s/ Lynn D. Rawlings
 
 
Lynn D. Rawlings, Treasurer and Assistant Secretary
   
Address:
 
720 Olive Street, Suite 1525
St. Louis, Missouri 63101
Attention: Treasurer
 
Facsimile No.: (314) 421-1979
 
Lender:
   
U.S. BANK NATIONAL ASSOCIATION
   
By:
/s/ Shawn O’ Hara
 
 
Shawn O’Hara, Managing Director
   
Address:
   
461 Fifth Avenue, 8th Floor
New York, New York 10017
Attention: Corporate Banking-Utilities Division
 
Facsimile No.: (917) 256-2805



 
 
 
 

SCHEDULE 2.02

Authorized Individuals


Douglas H. Yaeger

Mark D. Waltermire

Steven P. Rasche

Lynn D. Rawlings

Kent H. Sturhahn

Delfina Myers


 
 
 
 
EXHIBIT A

(Form of Note)

REVOLVING CREDIT NOTE

$30,000,000.00
 
St. Louis, Missouri
October 1, 2010
 
         FOR VALUE RECEIVED, THE LACLEDE GROUP, INC. , a Missouri corporation (“ Borrower ”), hereby promises to pay to the order of U. S. BANK NATIONAL ASSOCIATION , a national banking association (“ Lender ”), on the last day of the Revolving Credit Period, the principal sum of Thirty Million Dollars ($30,000,000.00), or such lesser sum as may then constitute the aggregate unpaid principal amount of all Loans made by Lender to Borrower pursuant to the Agreement (defined below).  The aggregate principal amount of Revolving Credit Loans that Lender shall be committed to have outstanding under this Revolving Credit Note (this “ Note ”) at any one time shall not exceed Thirty Million Dollars ($30,000,000.00), which amount may be borrowed, paid, reborrowed and repaid, in whole or in part, subject to the terms and conditions of this Note and of the Agreement.
 
         All payments received by Lender under this Note shall be allocated among the principal, interest, collection costs and expenses and other amounts due under this Note in such order and manner as Lender shall elect.  The amount of interest accruing under this Note shall be computed on an actual day, 360-day year basis.

All payments of principal and interest under this Note shall be made in lawful currency of the United States in Federal or other immediately available funds at the office of Lender located at 461 Fifth Avenue, 8 th Floor, New York, New York 10017 , or such other place as Lender may from time to time designate in writing.
 
         This Note is the “Note” referred to in the Revolving Credit Agreement dated as of the date hereof by and between Borrower and Lender, as the same may from time to time be amended, modified, extended, renewed or restated (the “ Agreement ”; all capitalized terms used and not otherwise defined in this Note shall have the respective meanings ascribed to them in the Agreement.).  The Agreement, among other things, contains provisions for acceleration of the maturity of this Note upon the occurrence of certain stated events and also for prepayments on account of principal of this Note and interest on this Note prior to the maturity of this Note upon the terms and conditions specified therein.
 
         If Borrower shall fail to make any payment of any principal or interest due under this Note as and when the same shall become due, then the entire outstanding principal balance of this Note and all accrued and unpaid interest thereon may be declared to be immediately due and payable in the manner and with the effect as provided in the Loan Agreement.
 
         In the event that any payment of any principal or interest due under this Note is not paid when due, whether by reason of maturity, acceleration or otherwise, and this Note is placed in the hands of an attorney or attorneys for collection, or if this Note is placed in the hands of an attorney or attorneys for representation of Lender in connection with bankruptcy or insolvency proceedings relating to or affecting this Note, Borrower hereby promises to pay to the order of Lender, in addition to all other amounts otherwise due on, under or in respect of this Note, the costs and expenses of such collection and representation, including, without limitation, reasonable attorneys’ fees and expenses (whether or
 
 
 
 
 
 
not litigation shall be commenced in aid thereof).  Borrower hereby waives presentment for payment, demand for payment, protest, notice of protest and notice of dishonor.
 
         This Note shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).


Borrower:
 
THE LACLEDE GROUP, INC .
   
By:
   
 
Lynn D. Rawlings, Treasurer and Assistant Secretary
 
  - 2 -
 
 
 

EXHIBIT B

(Form of Compliance Certificate)

[Date]


U.S. Bank National Association
461 Fifth Avenue, 8 th Floor
New York, New York 10017
Attention:  Corporate Banking- Utilities Division

Ladies and Gentlemen:

Reference is hereby made to the Revolving Credit Agreement dated as of October 1, 2010, by and between The Laclede Group, Inc. and U.S. Bank National Association, as the same may from time to time amended, modified, extended, renewed or restated (the “ Agreement ”).  All capitalized terms used and not otherwise defined herein shall have the respective meanings ascribed to them in the Agreement.

Borrower hereby certifies to Lender that as of the date hereof:

(a)         except as set forth below, all of the representations and warranties made by Borrower in the Agreement and/or in any of the other Transaction Documents are true and correct in all material respects on and as of the date of this Certificate as if made on and as of the date of this Certificate:
 
  Exceptions:  
    ;
 
(b)         except as set forth below, no Default or Event of Default under or within the meaning of the Agreement has occurred and is continuing:
 
  Exceptions:      
    ; and

(c)         the financial statements of Borrower and its Subsidiaries made available to you are true, correct and complete in all material respects and have been prepared in accordance with GAAP (subject, in the case of any interim financial statements, to normal year-end adjustments and absence of footnote disclosures).

(d)         Borrower had a Consolidated Capitalization Ratio of not more than Seventy Percent (70%) at all times during the period commencing _________, 201_, and ending _________, 201_.

                                          Very truly yours,

THE LACLEDE GROUP, INC.
   
By:
 
Name:
 
Title:
 


 
 
 
 



Exhibit 10.24




 
REVOLVING CREDIT AGREEMENT
 

BY AND BETWEEN

PNC BANK, NATIONAL ASSOCIATION, Lender

and

THE LACLEDE GROUP, INC., Borrower







October 1, 2010


 
 
 
 

TABLE OF CONTENTS

     
PAGE
       
SECTION 1.  DEFINITIONS
1
         
 
1.01
Definitions
1
         
SECTION 2.  LOANS
6
         
 
2.01
Loans
6
         
 
2.02
Method of Borrowing
6
         
 
2.03
Note
7
         
 
2.04
Duration of Interest Periods and Selection of Interest Rates
7
         
 
2.05
Interest Rates and Interest Payments
8
         
 
2.06
Computation of Interest
8
         
 
2.07
Fees
9
         
 
2.08
Prepayments
9
         
 
2.09
General Provisions as to Payments
9
         
 
2.10
Funding Losses
9
         
 
2.11
Basis for Determining Interest Rate Inadequate of Unfair
10
         
 
2.12
Illegality
10
         
 
2.13
Increased Cost
10
         
 
2.14
Prime Rate Loans Substituted for Affected LIBOR Loans or Daily LIBOR Loans
11
         
 
2.15
Capital Adequacy
11
         
 
2.16
Survival of Indemnities
11
         
 
2.17
Discretion of Lender as to Manner of Funding
11
         
 
2.18
Letters of Credit
12
         
 
2.20
Taxes
13
         
SECTION 3.  PRECONDITIONS TO LOANS AND LETTERS OF CREDIT
14
         
 
3.01
Initial Loan
14


 
 
 
 


 
3.02
All Loans and Letters of Credit
14
         
SECTION 4.  REPRESENTATIONS AND WARRANTIES
15
         
 
4.01
Corporate Existence and Power
15
         
 
4.02
Corporate Authorization
15
         
 
4.03
Binding Effect
15
         
 
4.04
Financial Statements
16
         
 
4.05
Compliance With Other Instruments; None Burdensome
16
         
 
4.06
Regulation U
16
         
 
4.07
Investment Company Act of 1940; Public Utility Holding Company Act of 2005
16
         
 
4.08
No Default
17
         
SECTION 5.  COVENANTS
17
         
 
5.01
Covenants of Borrower
19
         
 
5.02
Use of Proceeds
19
         
SECTION 6.  EVENTS OF DEFAULT
21
         
SECTION 7. GENERAL
21
         
 
7.01
No Waiver
21
         
 
7.02
Right of Set-Off
21
         
 
7.03
Cost and Expenses
21
         
 
7.04
General Indemnity
22
         
 
7.05
Notices
22
         
 
7.06
Consent to Jurisdiction; Waiver of Jury Trial
22
         
 
7.07
Governing Law
23
       
 
7.08
Amendments and Waivers
23
       
 
7.09
References; Headings for Convenience
23
       
 
7.10
Successors and Assigns
23
       
 
7.11
Notice Required by Section 432.047 R.S.Mo.; Entire Agreement
23




- ii -
 
 
 
 

REVOLVING CREDIT AGREEMENT

THIS REVOLVING CREDIT AGREEMENT (this “ Agreement ”) is made and entered into as of October 1, 2010, by and between THE LACLEDE GROUP, INC. , a Missouri corporation (“ Borrower ”), and PNC BANK, NATIONAL ASSOCIATION , a national banking association (“ Lender ”); and has reference to the following facts and circumstances:

A.           Borrower has applied for a revolving credit facility from Lender consisting of Loans in an aggregate principal amount of up to $20,000,000.00.

B.           Lender is willing to make said revolving credit facility available to Borrower upon, and subject to, the terms, provisions and conditions hereinafter set forth.

NOW, THEREFORE, in consideration of the premises and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Borrower and Lender hereby mutually covenant and agree as follows:

SECTION 1.  DEFINITIONS .

1.01         Definitions .  In addition to the terms defined elsewhere in this Agreement or in any Exhibit or Schedule hereto, when used in this Agreement, the following terms shall have the following meanings (such meanings shall be equally applicable to the singular and plural forms of the terms used, as the context requires):

Acquisition shall mean any transaction or series of related transactions, consummated on or after the date of this Agreement, by which Borrower or any Subsidiary directly or indirectly (a) acquires all or substantially all of the assets comprising one or more business units of any other Person at a purchase price of $5,000,000 or more, whether through purchase of assets, merger or otherwise or (b) acquires (in one transaction or as the most recent transaction in a series of transactions) at least (i) a majority (in number of votes) of the stock and/or other securities of a corporation having ordinary voting power for the  election of directors (other than stock and/or other securities having such power only by reason of the happening of a contingency), (ii) a majority (by percentage of voting power) of the outstanding partnership interests of a partnership, (iii) a majority (by percentage of voting power) of the outstanding membership interests of a limited liability company or (iv) a majority of the ownership interests in any organization or entity other than a corporation, partnership or limited liability company.

Act shall have the meaning ascribed thereto in Section 7.15.

Applicable Commitment Fee Rate shall mean an annual rate equal to 15/100 Percent (0.15%).

Applicable Margin shall mean with respect to (a) LIBOR Loans or Daily LIBOR Loans, an annual rate equal to One and 25/100 Percent (1.25%); and (b) Prime Loans, an annual rate equal to Zero Percent (0%).

Borrower’s Obligations shall mean any and all present and future indebtedness (principal, interest, fees, collection costs and expenses, attorneys’ fees and other amounts), liabilities and obligations (including, without limitation, indemnity obligations) of Borrower to Lender evidenced by or arising under or in respect of this Agreement, the Note and/or any of the other Transaction Documents.

Business Day shall mean any day other than a Saturday or Sunday or a legal holiday on which commercial banks are authorized or required by law to be closed for business in St. Louis, Missouri.
 
 
 
 
 
 
Consolidated Capitalization shall mean, as of the date of any determination thereof, the sum of Consolidated Debt as of such date, plus Consolidated Net Worth as of such date, all determined on a consolidated basis and in accordance with GAAP.

Consolidated Capitalization Ratio shall mean, as of the date of any determination thereof, the ratio (expressed as a percentage) of Consolidated Debt as of such date to Consolidated Capitalization as of such date, all determined on a consolidated basis and in accordance with GAAP; provided , that for purposes of calculating the Consolidated Capitalization Ratio, only Fifty Percent (50%) of the principal amount of any outstanding subordinated Debt issued by Borrower shall be included in Consolidated Debt.

Consolidated Debt shall mean, as of the date of any determination thereof, all Debt of Borrower and its Subsidiaries as of such date, determined on a consolidated basis and in accordance with GAAP.

Consolidated Net Worth shall mean, as of the date of any determination thereof, the amount of the capital stock accounts (net of treasury stock, at cost) of Borrower and its Subsidiaries as of such date plus (or minus in the case of a deficit) the surplus and retained earnings of Borrower and its Subsidiaries as of such date, all determined on a consolidated basis and in accordance with GAAP.

Daily LIBOR Rate shall mean, for any day, the Applicable Margin plus the annual rate determined by Lender by dividing (i) the Published Rate, by (ii) a number equal to 1.00 minus the LIBOR Reserve Percentage.  The Daily LIBOR Rate shall be adjusted automatically on and as of the effective date of any change in the LIBOR Reserve Percentage.

Daily LIBOR Loan shall mean any portion of a Loan bearing interest based on the Daily LIBOR Rate.

Debt shall mean, as of the date of determination thereof, the sum of (a) all indebtedness, liabilities and/or obligations of Borrower or any of its Subsidiaries for borrowed money or that have been incurred in connection with the purchase or other acquisition of property (other than unsecured trade accounts payable incurred in the ordinary course of business), plus (b) all leases of property, whether real and/or personal, by Borrower or any of its Subsidiaries as lessee(s), that in accordance with GAAP are required to be capitalized on the balance sheet of such entity, plus (c) the aggregate undrawn face amount of all Letters of Credit and/or surety bonds issued for the account and/or upon the application of Borrower or any of its Subsidiaries together with all unreimbursed drawings with respect thereto, plus (d) all guarantees by Borrower or any of its Subsidiaries of Debt of other Persons (but not including any guarantees of Debt of Borrower or any of its Subsidiaries).

Default shall mean any event or condition the occurrence of that would, with the lapse of time or the giving of notice or both, become an Event of Default.

Event of Default shall have the meaning ascribed thereto in Section 6.

Fitch shall mean Fitch Ratings, Ltd.

GAAP shall mean, at any time, generally accepted accounting principles at such time in the United States.

Guaranty shall mean the Guaranty dated as of the date hereof, executed by Laclede Energy in favor of Lender, as the same may from time to time be amended, modified, extended, renewed or restated.
 
 
- 2 -
 
 
 
Indemnified Liabilities shall have the meaning ascribed thereto in section 7.04.

Interest Period shall mean with respect to each LIBOR Loan:  (a) initially, the period commencing on the date selected by Borrower in the applicable Interest Rate Selection Notice and ending seven (7) days, one (1) month, two (2) months, three (3) months, or six (6) months thereafter, as Borrower may elect in the applicable Interest Rate Selection Notice; and (b) thereafter, each period commencing on the last day of the immediately preceding Interest Period applicable to such LIBOR Loan and ending seven (7) days, one (1) month, two (2) months, three (3) months, or six (6) months, as Borrower may elect in the applicable Interest Rate Selection Notice; provided that :  (c) no Interest Period for a LIBOR Loan shall extend beyond a date on which Borrower is required to make a scheduled payment of principal on the Loan unless the sum of (A) the aggregate principal amount of outstanding Daily LIBOR Loans plus (B) the aggregate principal amount of outstanding LIBOR Loans with Interest Periods expiring on or before the date such scheduled principal payment is due equals or exceeds the aggregate principal amount to be paid on the Loan on such principal payment date; (d) subject to clauses (e) and (f) below, any Interest Period that would otherwise end on a day that is not a Business Day shall be extended to the next succeeding Business Day unless such Business Day falls in another calendar month, in which case such Interest Period shall end on the immediately preceding Business Day; (e) subject to clause (f) below, any Interest Period that begins on the last Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last Business Day of a calendar month; and no Interest Period may extend beyond the maturity date of the Loan.

Interest Rate Selection Notice shall have the meaning ascribed thereto in section 2.02(a).

Investment shall mean any investment (including, without limitation, any loan or advance) of Borrower or any Subsidiary in or to any Person, whether payment therefor is made in cash or capital stock or other equity interests of Borrower or any Subsidiary, and whether such investment is by acquisition of stock or other equity interests or Indebtedness, or by loan, advance, transfer of property out of the ordinary course of business, capital contribution, equity or profit sharing interest, extension of credit on terms other than those normal in the ordinary course of business or otherwise.

Laclede Energy shall mean Laclede Energy Resources, Inc., a Missouri corporation, and a Subsidiary of Borrower.

Lender’s Revolving Credit Commitment shall mean the sum of Twenty Million Dollars ($20,000,000).

Letter of Credit and Letters of Credit shall have the meanings ascribed to these terms in Section 2.18(a).

Letter of Credit Application shall mean Lender’s standard form of application and agreement for irrevocable standby letter of credit, or Lender’s standard form of application and agreement for irrevocable commercial letter of credit, as the case may be, in either case executed by Borrower, or a Subsidiary of Borrower, as applicant and account party, and delivered to Lender pursuant to Section 2.18(a), as the same may from time to time be amended, modified, extended, renewed or restated.

LGC shall mean Laclede Gas Company, a Missouri corporation, and a Subsidiary of Borrower.

LIBOR Base Rate shall mean, with respect to any LIBOR Loan for the applicable Interest Period, (a) the LIBOR Index Rate for such Interest Period, if such rate is available, or (b) if the LIBOR Index Rate is not available, the annual interest rate determined by the Lender in accordance with its usual procedures (which determination shall be conclusive absent manifest error) to be the Eurodollar
 
 
- 3 -
 
 
 
rate two (2) Business Days prior to the first day of such Interest Period for an amount comparable to such LIBOR Loan and having a borrowing date and a maturity comparable to such Interest Period.

LIBOR Index Rate shall mean, with respect to the applicable Interest Period, an annual rate (rounded upwards, if necessary, to the next higher 1/10,000 of 1%) equal to the British Bankers’ Association interest settlement rates for U.S. Dollar deposits for such Interest Period as of 11:00 a.m. (London time) on the day two (2) Business Days before the first day of such Interest Period as published by Bloomberg Financial Services, Dow Jones Market Service, Telerate, Reuters or any other service from time to time used by Lender.

LIBOR Loan shall mean any portion of a Loan bearing interest based on the LIBOR Rate.

LIBOR Rate shall mean (a) the quotient of the (i) LIBOR Base Rate divided by (ii) one minus the applicable LIBOR Reserve Percentage plus (b) the Applicable Margin.  The LIBOR Rate shall be adjusted automatically on and as of the effective date of any change in the LIBOR Reserve Percentage.

LIBOR Reserve Percentage shall mean for any day that percentage (expressed as a decimal) which is in effect on such day, as prescribed by The Board of Governors of the Federal Reserve System (or any successor), for determining the maximum reserve requirement (including, without limitation, any basic, supplemental, emergency, special or marginal reserves) with respect to “Eurocurrency liabilities” as defined in Regulation D or with respect to any other category of liabilities which includes deposits by reference to which the interest rate on LIBOR Loans is determined, whether or not Lender has any Eurocurrency liabilities subject to such reserve requirement at such time. LIBOR Loans shall be deemed to constitute Eurocurrency liabilities and as such shall be deemed subject to reserve requirements without the benefit of any credits for proration, exceptions or offsets which may be available from time to time to Lender.

Loan and Loans shall have the meaning ascribed thereto in Section 2.01(a).

Loan Party shall mean each of Borrower and each Subsidiary that has executed the Guaranty (including, without limitation, Laclede Energy).

Material Adverse Effect shall mean (a) a material adverse effect on the properties, assets, liabilities, business, operations, income or condition (financial or otherwise) of Borrower and its Subsidiaries taken as a whole, (b) material impairment of Borrower’s ability to perform any of its obligations under this Agreement, the Note or any of the other Transaction Documents or (c) material impairment of the enforceability of the rights of, or benefits available to, Lender under this Agreement, the Note or any of the other Transaction Documents.

Moody’s shall mean Moody’s Investors Service, Inc.

Note shall have the meaning ascribed thereto in Section 2.03(a).

Notice of Borrowing shall have the meaning ascribed thereto in Section 2.02(a).

Other Taxes shall have the meaning ascribed thereto in Section 2.20(b).

Permitted Investment shall mean any Investment or Acquisition, or any expenditure or any incurrence of any liability to make any expenditure for an Investment or Acquisition, other than (a) any Investment or Acquisition the result of which would be to change substantially the nature of the business engaged in by Borrower and its Subsidiaries, (b) any Investment that is in the nature of a hostile or contested Acquisition, and (c) any Investment that would result in a Default or Event of
 
 
- 4 -
 
 
 
Default; provided , that it is expressly agreed that all Investments under Borrower’s or Subsidiaries’ gas supply risk management programs are Permitted Investments.

Person shall mean any individual, sole proprietorship, partnership, joint venture, limited liability company, trust, unincorporated organization, association, corporation, institution, entity or government (whether national, Federal, state, county, city, municipal or otherwise, including, without limitation, any instrumentality, division, agency, body or department thereof).

Prime Rate shall mean the rate publicly announced by Lender from time to time as its prime rate.  The Prime Rate is determined from time to time by Lender as a means of pricing some loans to its borrowers, is not tied to any external rate of interest or index, and does not necessarily reflect the lowest rate of interest actually charged by Lender to any particular class or category of customers.

Prime Rate Loan shall mean any portion of a Loan bearing interest based on the Prime Rate.

Published Rate shall mean the rate of interest published each Business Day in the Wall Street Journal, “Money Rates” listing, under the caption entitled “London Interbank Offered Rates”, for a one-month period (or, if no such rate is published therein for any reason, then the Published Rate shall be the eurodollar rate for a one-month period as published in another publication selected by Lender.

Regulation D shall mean Regulation D of the Board of Governors of the Federal Reserve System, as amended.

Regulatory Change shall have the meaning ascribed thereto in Section 2.10.

Revolving Credit Period shall mean the period commencing on the date of this Agreement and ending September 30, 2011, or such later date as may be designated by Lender by written notice from Lender to Borrower; provided , that Borrower acknowledges and agrees that in no event will Lender be under any obligation to extend or renew the Agreement beyond September 30, 2011; provided , however , that the Revolving Credit Period shall end on the date the Lender’s Revolving Credit Commitment is terminated pursuant to Section 6 or otherwise.

S&P shall mean Standard & Poor’s Ratings Group.

Subsidiary shall mean any corporation or other entity of which more than Fifty Percent (50%) of the issued and outstanding capital stock or other equity interests entitled to vote for the election of directors or persons performing similar functions (other than by reason of default in the payment of dividends or other distributions) is at the time owned directly or indirectly by Borrower or any Subsidiary.

Taxes shall have the meaning ascribed thereto in Section 2.20(a).

Total Revolving Credit Outstandings shall mean, as of any date, the sum of (a) the aggregate principal amount of all Loans outstanding as of such date, plus (b) the aggregate undrawn face amount of all Letters of Credit outstanding as of such date plus (c) all unreimbursed drawings with respect to all Letters of Credit.

Transaction Documents shall mean this Agreement, the Note, the Guaranty, and any and all other agreements, documents and instruments heretofore, now or hereafter delivered to the Agent or any Bank with respect to or in connection with or pursuant to this Agreement, any Loans made hereunder or any of the other Borrower’s Obligations, and executed by or on behalf of any Loan Party, all as the same may from time to time be amended, modified, extended, renewed or restated.
 
 
- 5 -
 
 
 
SECTION 2.  LOANS .

2.01         Loans .

(a) Subject to the terms and conditions set forth in this Agreement and so long as no Default or Event of Default has occurred and is continuing, during the Revolving Credit Period, Lender agrees to make such loans to Borrower (individually, a “ Loan ” and collectively, the “ Loans ”) as Borrower may from time to time request pursuant to Section 2.02.  Each Loan under this Section 2.01(a) which is a Daily LIBOR Loan shall be for an aggregate principal amount of at least $50,000.00 or any larger multiple of $10,000.00.  Each Loan under this Section 2.01(a) which is a LIBOR Loan shall be for an aggregate principal amount of at least $1,000,000.00 or any larger multiple of $250,000.00; provided , that Borrower may not have outstanding and Lender shall not be obligated to make more than eight (8) LIBOR Loans at any one time.  The aggregate principal amount of Loans that Lender shall be required to have outstanding under this Agreement as of any date shall not exceed the amount of Lender’s Revolving Credit Commitment as of such date. Within the foregoing limits, Borrower may borrow under this Section 2.01(a), prepay under Section 2.08 and reborrow at any time during the Revolving Credit Period under this Section 2.01(a).  All Loans not paid prior to the last day of the Revolving Credit Period, together with all accrued and unpaid interest thereon and all fees and other amounts owing by Borrower to Lender with respect thereto, shall be due and payable on the last day of the Revolving Credit Period.

(b)          If the amount of Lender’s Revolving Credit Commitment on any date is less than the Total Revolving Credit Outstandings on such date, whether as a result of Borrower’s election to decrease the amount of Lender’s Revolving Credit Commitment pursuant to Section 2.01(c) or otherwise, Borrower shall be automatically required (without demand or notice of any kind by Lender, all of which are hereby expressly waived by Borrower) to immediately repay the Loans in an amount sufficient to reduce the amount of the Total Revolving Credit Outstandings to an amount equal to or less than the amount of Lender’s Revolving Credit Commitment.

(c)          Borrower may, upon five (5) Business Days’ prior written notice to Lender, terminate entirely at any time, or reduce from time to time by an aggregate amount of $1,000,000 or any larger multiple of $1,000,000 the unused portions of Lender’s Revolving Credit Commitment; provided , however , that (i) at no time shall the amount of Lender’s Revolving Credit Commitment be reduced to a figure less than the Total Revolving Credit Outstanding, (ii) at no time shall the amount of Lender’s Revolving Credit Commitment be reduced to a figure greater than zero (0) but less than $5,000,000 and (iii) any such termination or reduction shall be permanent and Borrower shall have no right to thereafter reinstate or increase, as the case may be, Lender’s Revolving Credit Commitment.

2.02         Method of Borrowing .

(a)          Borrower shall give Lender oral or written notice (a “ Notice of Borrowing ”) by 10:00 a.m. (St. Louis time) on the Business Day of each Daily LIBOR Loan to be made to Borrower, and by 10:00 a.m. (St. Louis time) at least three (3) Business Days before each LIBOR Loan to be made to Borrower, specifying:  (i) the date of such Loan, which shall be a Business Day during the Revolving Credit Period in the case of a Daily LIBOR Loan and a Business Day during the Revolving Credit Period in the case of a LIBOR Loan, (ii) the aggregate principal amount of such Loan, (iii) whether such Loan is to be a Daily LIBOR Loan or a LIBOR Loan, and (iv) in the case of a LIBOR Loan, the duration of the initial Interest Period applicable thereto, subject to the provisions of the definition of Interest Period.

(b)          A Notice of Borrowing shall not be revocable by Borrower.

(c)          Subject to the terms and conditions of this Agreement, provided that Lender has received the Notice of Borrowing, Lender shall (unless Lender determines that any applicable condition
 
 
- 6 -
 
 
 
specified in Section 3 has not been satisfied) make the applicable Loan to Borrower by crediting the amount of such Loan to a demand deposit account of Borrower at Lender specified by Borrower (or such other account mutually agreed upon in writing between Lender and Borrower) not later than 2:30 p.m. (St. Louis time) on the Business Day specified in said Notice of Borrowing.

(d)          If Lender makes a new Loan under this Agreement on a day on which Borrower is required to or has elected to repay all or any part of an outstanding Loan, Lender shall apply the proceeds of its new Loan to make such repayment and only an amount equal to the difference (if any) between the amount being borrowed and the amount being repaid shall be made available by Lender to Borrower.

(e)          Borrower hereby irrevocably authorizes Lender to rely on telephonic, telegraphic, telecopy, telex or written instructions of any individual identifying himself or herself as one of the individuals listed on Schedule 2.02 attached hereto (or any other individual from time to time authorized to act on behalf of Borrower pursuant to a document signed by the President, Chief Financial Officer or Treasurer of Borrower and certified by the Secretary of Borrower and delivered to Lender) with respect to any request to make a Loan or a repayment under this Agreement, and on any signature that Lender reasonably believes to be genuine, and Borrower shall be bound thereby in the same manner as if such individual were actually authorized or such signature were genuine.  Borrower also hereby agrees to defend and indemnify Lender and hold Lender harmless from and against any and all claims, demands, damages, liabilities, losses and reasonable costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) relating to or arising out of or in connection with the acceptance of instructions for making Loans or repayments under this Agreement.

2.03         Note .

(a)          The Loans of Lender to Borrower shall be evidenced by the Revolving Credit Note of Borrower payable to the order of Lender in a principal amount equal to the maximum amount of Lender’s Revolving Credit Commitment, which Revolving Credit Note shall be in substantially the form of Exhibit A attached hereto and incorporated herein by reference (with appropriate insertions) (as the same may from time to time be amended, modified, extended, renewed or restated, the “ Note ”).

(b)          Lender shall record in its books and records the date, amount, type and Interest Period (if any) of each Loan made by it to Borrower and the date and amount of each payment of principal and/or interest made by Borrower with respect thereto; provided , however , that the obligation of Borrower to repay each Loan made by Lender to Borrower under this Agreement shall be absolute and unconditional, notwithstanding any failure of Lender to make any such recordation or any mistake by Lender in connection with any such recordation.  The books and records of Lender showing the account between Lender and Borrower shall be conclusive in the absence of manifest error.

2.04         Duration of Interest Periods and Selection of Interest Rates .

(a)          The duration of the initial Interest Period for each LIBOR Loan shall be as specified in the applicable Notice of Borrowing.  Borrower shall elect the duration of each subsequent Interest Period applicable to such LIBOR Loan and the interest rate to be applicable during such subsequent Interest Period (and Borrower shall have the option (i) in the case of any Daily LIBOR Loan, to elect that such Loan become a LIBOR Loan and the Interest Period to be applicable thereto, and (ii) in the case of any LIBOR Loan, to elect that such Loan become a Daily LIBOR Loan), by giving notice of such election to Lender by 10:00 a.m. (St. Louis time) on the Business Day of, in the case of the election of the Daily LIBOR Rate, and by 10:00 a.m. (St. Louis time) at least three (3) Business Days before, in the case of the election of the LIBOR Rate, the end of the immediately preceding Interest Period applicable thereto, if any; provided , however , that notwithstanding the foregoing, in addition to and without limiting the rights and remedies of Lender under Section 6 of this Agreement, so long as any Default or Event
 
 
- 7 -
 
 
 
of Default under this Agreement has occurred and is continuing, Borrower shall not be permitted to renew any LIBOR Loan as a LIBOR Loan or to convert any Daily LIBOR Loan into a LIBOR Loan.  If Lender does not receive a notice of election for a Loan pursuant to this Section 2.04(a) within the applicable time limits specified herein, Borrower shall be deemed to have elected to pay such Loan in whole pursuant to Section 2.08 on the last day of the current Interest Period with respect thereto and to reborrow the principal amount of such Loan on such date as a Daily LIBOR Loan.

(b)          Borrower may not have outstanding and Lender shall not be obligated to make more than eight (8) LIBOR Loans at any one time.

2.05         Interest Rates and Interest Payments .  (a) So long as no Event of Default has occurred and is continuing, each Daily LIBOR Loan shall bear interest on the outstanding principal amount thereof for each day until paid at an annual rate equal to the Daily LIBOR Rate.  So long as any Event of Default has occurred and is continuing, each Daily LIBOR Loan shall bear interest on the outstanding principal amount thereof for each until it is paid, at an annual rate equal to Five Percent (5%) over and above the Daily LIBOR Rate.  Such interest shall be payable monthly in arrears on the last day of each calendar month commencing October 31, 2010 and at the maturity of the Note (whether by reason of acceleration or otherwise).  From and after the maturity of the Note, whether by reason of acceleration or otherwise, each Daily LIBOR Loan shall bear interest, payable on demand, for each day until paid at an annual rate equal to Five Percent (5%) over and above the Daily LIBOR Rate.

(b)          So long as no Event of Default has occurred and is continuing, each LIBOR Loan shall bear interest on the outstanding principal amount thereof for each Interest Period applicable thereto at an annual rate equal to the LIBOR Rate.  So long as any Event of Default has occurred and is continuing, each LIBOR Loan shall bear interest on the outstanding principal amount thereof for each Interest Period applicable thereto at an annual rate equal to Five Percent (5%) over and above the LIBOR Rate.  Such interest shall be payable for each Interest Period on the last day thereof, unless the duration of such Interest Period exceeds three (3) months, in which case such interest shall be payable on the last day of each three (3) month period during such Interest Period and on the last day of such Interest Period, and at the maturity of the Note (whether by reason of acceleration or otherwise).  From and after the maturity of the Note, whether by reason of acceleration or otherwise, each LIBOR Loan shall bear interest, payable on demand, for each day until paid, at an annual rate equal to Five Percent (5%) over and above the higher of (i) the LIBOR Rate applicable to such LIBOR Loan for the immediately preceding Interest Period or (ii) the Daily LIBOR Rate.

(c)          Lender shall determine each interest rate applicable to the Daily LIBOR Loans and LIBOR Loans hereunder and its determination thereof shall be conclusive in the absence of manifest error.

(d)          If Lender determines (which determination shall be final and conclusive) that, by reason of circumstances affecting the Eurodollar market generally, deposits in dollars (in the applicable amounts) are not being offered to banks in the Eurodollar market for the selected term, or adequate means do not exist for ascertaining the LIBOR Rate or Daily LIBOR Rate, then Lender shall give notice thereof to Borrower, and thereafter, until Lender notifies Borrower that the circumstances giving rise to such suspension no longer exist, (i) the availability of the LIBOR Rate or Daily LIBOR Rate shall be suspended, and (ii) the interest rate for all Loans then bearing interest based on the LIBOR Rate or Daily LIBOR Rate shall be converted at the expiration of the then current LIBOR Interest Period(s) with respect to any LIBOR Loan, and immediately with respect to any Daily LIBOR Loan, to Prime Rate Loans bearing interest at the Prime Rate plus the Applicable Margin.

2.06         Computation of Interest .  Interest on Daily LIBOR Loans hereunder shall be computed on the basis of a year of 360 days and paid for the actual number of days elapsed (including the first day but excluding the last day).  Interest on LIBOR Loans shall be computed on the basis of a year of
 
 
- 8 -
 
 
 
360 days and paid for the actual number of days elapsed, calculated as to each Interest Period from and including the first day thereof to but excluding the last day thereof.

2.07         Fees .

(a)          Contemporaneously with the execution of this Agreement, Borrower shall pay Lender a nonrefundable upfront fee in the amount set forth in the fee letter provided by Lender to Borrower.

(b)          Borrower shall pay to Lender a utilization fee equal to 25/100 Percent (0.25%) per annum times the Total Revolving Credit Outstandings on each day that the Total Revolving Credit Outstandings exceed Thirty Three Percent (33%) of the actual amount of Lender’s Revolving Credit Commitment then in effect (or, if terminated, in effect immediately prior to such termination).  Such utilization fee shall be due and payable quarterly in arrears on the last day of each calendar quarter, commencing with the first such date to occur after the effective date of this Agreement, and on the last day of the Revolving Credit Period (and if applicable, thereafter on demand).

(c)          From and including the date of this Agreement to but excluding the last day of the Revolving Credit Period, Borrower shall pay a nonrefundable commitment fee on the unused portion of Lender’s Revolving Credit Commitment (determined by subtracting the Total Revolving Credit Outstandings from the amount of Lender’s Revolving Credit Commitment) at a percentage rate equal to the Applicable Commitment Fee Rate.  Said commitment fee shall be (i) calculated on a daily basis, (ii) payable quarterly in arrears on each June 30, September 30, December 31, and March 31 during the Revolving Credit Period commencing December 31, 2010, and on the last day of the Revolving Credit Period and (iii) calculated on an actual day, 360-day year basis.

2.08         Prepayments .  Borrower may, upon notice to Lender specifying that it is paying any Daily LIBOR Loan, pay without penalty or premium such Daily LIBOR Loan in whole at any time or in part from time to time, by paying the principal amount to be paid, provided that partial prepayments shall be in an aggregate amount of at least $1,000,000.00 or any larger multiple of $500,000.00.  Borrower may, upon at least three (3) Business Day’s irrevocable prior written notice to Lender, prepay all at any time or any portion from time to time of the unpaid principal balance of any LIBOR Loan prior to maturity provided that (i) contemporaneously with each such prepayment Borrower shall pay all accrued and unpaid interest on the portion of the LIBOR Loan being prepaid to and including the date of prepayment; (ii) partial prepayments shall be in an aggregate amount of at least $2,000,000.00 or any larger multiple of $1,000,000.00; (iii) in no event may Borrower make any prepayment on any LIBOR Loan that results in the remaining LIBOR Loans with respect to which a given Interest Period applies being greater than $0.00 but less than $1,000,000.00 and (iv) if Borrower is making a prepayment of a LIBOR Loan, contemporaneously with such prepayment, Borrower shall pay Lender the funding losses and other amounts, if any, required under Section 2.10.

2.09         General Provisions as to Payments .  Borrower shall make each payment of principal of, and interest on, the Loan and of fees and all other amounts payable by Borrower under this Agreement, not later than 12:00 noon (St. Louis time) on the date when due and payable in Federal or other funds immediately available in St. Louis, Missouri, to Lender at its address referred to in Section 7.05.  All payments received by Lender after 12:00 noon (St. Louis time) shall be deemed to have been received by Lender on the next succeeding Business Day. Whenever any payment of principal of, or interest on, the Loan or of fees shall be due on a day which is not a Business Day, the date for payment thereof shall be extended to the next succeeding Business Day.  If the date for any payment of principal is extended by operation of law or otherwise, interest thereon, at the then applicable rate, shall be payable for such extended time.

2.10         Funding Losses .  Notwithstanding any provision contained in this Agreement to the contrary, if (a) Borrower shall make any payment of principal with respect to any LIBOR Loan on any
 
 
- 9 -
 
 
 
day other than the last day of the Interest Period applicable thereto, whether as a result of a scheduled payment, a voluntary prepayment, a mandatory prepayment, maturity, acceleration or otherwise or (b) any LIBOR Loan is converted to a Prime Rate Loan pursuant to Sections 2.04, 2.05(d), 2.11 or 2.12, on any day other than the last day of the Interest Period applicable thereto, contemporaneously with each such payment or conversion Borrower shall reimburse Lender on demand for any resulting losses and expenses incurred by Lender, including , without limitation, any losses incurred in obtaining, liquidating, or employing deposits from third parties, but excluding any loss of the Applicable Margin for the period after any such prepayment, provided that Lender shall have delivered to Borrower a certificate as to the amount of such losses and expenses, which certificate shall be conclusive in the absence of manifest error.

2.11         Basis for Determining Interest Rate Inadequate or Unfair .  If with respect to any Interest Period:  (a) deposits in U.S. Dollars (in the applicable amounts) are not being offered to Lender in the relevant market for such Interest Period, or (b) Lender determines in good faith that the LIBOR Rate as determined pursuant to the definition thereof will not adequately and fairly reflect the cost to Lender of maintaining or funding the LIBOR Loans for such Interest Period, Lender shall forthwith give notice thereof to Borrower whereupon until Lender notifies Borrower that the circumstances giving rise to such suspension no longer exist, (i) the LIBOR Rate shall not be available to Borrower as an interest rate option on any portion of the Loan and (ii) all of the then outstanding LIBOR Loans shall automatically convert to Prime Rate Loans (bearing interest at the Prime Rate plus the Applicable Margin) on the last day of the then current Interest Period applicable to each such LIBOR Loan. Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10.
 
 
2.12         Illegality .  If, after the date of this Agreement, the adoption of any applicable law, rule or regulation, or any change therein, or any change in the interpretation or administration thereof by any governmental or regulatory authority, central bank or comparable agency charged with the interpretation or administration thereof, or compliance by Lender with any request or directive (whether or not having the force of law) of any such governmental or regulatory authority, central bank or comparable agency (a “ Regulatory Change ”) shall make it unlawful or impossible for Lender to make, maintain or fund its LIBOR Loans to Borrower, Lender shall forthwith give notice thereof to Borrower.  Upon receipt of such notice, Borrower shall convert all of its then outstanding LIBOR Loans on either (a) the last day of the then current Interest Period applicable to such LIBOR Loan if Lender may lawfully continue to maintain and fund such LIBOR Loan to such day or (b) immediately if Lender may not lawfully continue to fund and maintain such LIBOR Loan to such day, to a Prime Rate Loan (bearing interest at the Prime Rate plus the Applicable Margin) in an equal principal amount.  Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10.

2.13         Increased Cost .  (a)  If (i) Regulation D or (ii)  a Regulatory Change:  (A) shall subject Lender to any tax, duty or other charge with respect to the LIBOR Loans, the Note or its obligation to make LIBOR Loans, or shall change the basis of taxation of payments to Lender of the principal of or interest on its LIBOR Loans or any other amounts due under this Agreement in respect of its LIBOR Loans or its obligation to make LIBOR Loans (except for taxes on or changes in the rate of tax on the overall net income of Lender); or (B) shall impose, modify or deem applicable any reserve (including, without limitation, any reserve imposed by the Board of Governors of the Federal Reserve System), special deposit, capital or similar requirement against assets of, deposits with or for the account of, or credit extended or committed to be extended by, Lender or shall, with respect to Lender impose, modify or deem applicable any other condition affecting Lender’s LIBOR Loans, the Note or Lender’s obligation to make LIBOR Loans; and the result of any of the foregoing is to increase the cost to (or in the case of Regulation D, to impose a cost on or increase the cost to) Lender of making or maintaining any LIBOR Loan, or to reduce the amount of any sum received or receivable by Lender under this Agreement or under its Note with respect thereto, by an amount deemed by Lender to be material, and if Lender is
 
 
- 10 -
 
 
 
not otherwise fully compensated for such increase in cost or reduction in amount received or receivable by virtue of the inclusion of the reference to “LIBOR Reserve Percentage” in the calculation of the LIBOR Rate, then upon notice by Lender to Borrower, which notice shall set forth Lender’s supporting calculations and the details of the Regulatory Change, Borrower shall pay Lender, as additional interest, such additional amount or amounts as will compensate Lender for such increased cost or reduction.  The determination by Lender under this Section of the additional amount or amounts to be paid to it hereunder shall be conclusive in the absence of manifest error.  In determining such amount or amounts, Lender may use any reasonable averaging and attribution methods.

(b)          If Lender demands compensation under Section 2.13(a) above, Borrower may at any time, upon at least three (3) Business Day’s prior notice to Lender, convert its then outstanding LIBOR Loans to Prime Rate Loans (bearing interest at the Prime Rate plus the Applicable Margin) in an equal principal amount.  Interest accrued on each such LIBOR Loan prior to any such conversion shall be due and payable on the date of such conversion together with any funding losses and other amounts due under Section 2.10 and this Section 2.13.

2.14         Prime Rate Loans Substituted for Affected LIBOR Loans or Daily LIBOR Loans .  If notice has been given by Lender  pursuant to Sections 2.05(d), 2.11 or 2.12 requiring or by Borrower pursuant to Section 2.04 requiring LIBOR Loans or Daily LIBOR Loans to be repaid or converted to Prime Rate Loans, then, unless and until Lender notifies Borrower that the circumstances giving rise to such repayment or conversion no longer apply, any portion of the Loans that would otherwise be made by Lender to Borrower as LIBOR Loans or Daily LIBOR Loans shall be made instead as Prime Rate Loans (bearing interest at the Prime Rate plus the Applicable Margin).  Lender shall promptly notify Borrower if and when the circumstances giving rise to such repayment no longer apply.

2.15         Capital Adequacy .  If, after the date of this Agreement, Lender shall have determined in good faith that a Regulatory Change has occurred which has or will have the effect of reducing the rate of return on Lender’s capital in respect of its obligations hereunder to a level below that which Lender could have achieved but for such adoption, change or compliance (taking into consideration Lender’s policies with respect to capital adequacy), then from time to time Borrower shall pay to Lender upon demand such additional amount or amounts as will compensate Lender for such reduction.  All determinations made in good faith by Lender of the additional amount or amounts required to compensate it in respect of the foregoing shall be conclusive in the absence of manifest error.  In determining such amount or amounts, Lender may use any reasonable averaging and attribution methods.

2.16        Survival of Indemnities .  All indemnities and all provisions relating to reimbursement to Lender of amounts sufficient to protect the yield to Lender with respect to the Loan, including, without limitation, Sections 2.10, 2.13 and 2.15 hereof, shall survive the payment of the Note and the other Borrower’s Obligations and the expiration or termination of this Agreement.  Notwithstanding the foregoing, if Lender fails to notify Borrower of any event that will entitle Lender to compensation pursuant to Sections 2.10, 2.13 and/or 2.15 hereof within one hundred eighty (180) days after Lender obtains knowledge of such event, then Lender shall not be entitled to any compensation from Borrower for any loss, expense, increased cost and/or reduction of return arising from such event.

2.17         Discretion of Lender as to Manner of Funding .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall be entitled to fund and maintain its funding of all or any part of its LIBOR Loans in any manner it elects, it being understood, however, that for purposes of this Agreement all determinations hereunder (including, without limitation, the determination of Lender’s funding losses and expenses under Section 2.10) shall be made as if Lender had actually funded and maintained each LIBOR Loan through the purchase of deposits having a maturity corresponding to the maturity of the applicable Interest Period relating to the applicable LIBOR Loan and bearing an interest rate equal to the applicable LIBOR Base Rate.
 
 
- 11 -
 
 
 
2.18         Letters of Credit .

(a)          Subject to the terms and conditions of this Agreement and so long as no Default or Event of Default has occurred and is continuing, during the Revolving Credit Period, Lender agrees to issue irrevocable commercial and/or standby letters of credit for the account of Borrower and/or any Subsidiary (individually, a “ Letter of Credit ”, and collectively, “ Letters of Credit ”) in an amount and for the term specifically requested by Borrower by notice in writing to Lender at least two (2) Business Days prior to the requested issuance thereof; provided , however , that: (i) Borrower shall have executed and delivered to Lender a Letter of Credit Application with respect to such Letter of Credit; (ii) the term of any such Letter of Credit shall not extend beyond the earlier of (A) the date one (1) year after the date of issuance thereof, or (B) the last day of the Revolving Credit Period; (iii) any Letter of Credit may only be utilized to guaranty the payment of obligations of Borrower or a Subsidiary to third parties; (iv) Total Revolving Credit Outstandings shall not as of any date exceed Lender’s Revolving Credit Commitment; and (v) the text of any such Letter of Credit is provided to Lender no less than two (2) Business Days prior to the requested issuance date, which text must be acceptable to Lender in its sole and absolute discretion.

(b)          The payment of drafts under each Letter of Credit shall be made in accordance with the terms thereof and, in that connection, Lender shall be entitled to honor any drafts and accept any documents presented to it by the beneficiary of such Letter of Credit in accordance with the terms of such Letter of Credit and the related Letter of Credit Application and believed in good faith by Lender to be genuine.  Lender shall not have any duty to inquire as to the accuracy or authenticity of any draft or other drawing document that may be presented to it other than the duties contemplated by the applicable Letter of Credit Application.

(c)          In the event of any payment by Lender of a draft presented under a Letter of Credit, Borrower agrees to pay to Lender in immediately available funds at the time of such drawing an amount equal to the sum of such drawing plus the negotiation, processing and other fees related thereto, as may be agreed between Lender and Borrower from time to time.  Borrower hereby authorizes Lender to charge or cause to be charged one or more of Borrower’s deposit accounts at Lender to the extent there are balances of immediately available funds therein, in an aggregate amount equal to the sum of such drawing plus the negotiation, processing and other fees related thereto as may be agreed between Lender and Borrower from time to time, and Borrower agrees to pay the amount of any such drawing (and/or Lender’s customary negotiation, processing and other fees related thereto) not so charged prior to the close of business of Lender on the day of such drawing.  In the event any payment under a Letter of Credit is made by Lender prior to receipt of payment from Borrower, such payment by Lender shall constitute a request by Borrower for a Daily LIBOR Loan under Sections 2.01 and 2.02 above (and Lender will make such Daily LIBOR Loan to Borrower regardless of whether any Default or Event of Default under this Agreement has occurred and is continuing and regardless of whether such Daily LIBOR Loan would otherwise be permitted under the requirements of this Agreement) and the proceeds of such Daily LIBOR Loan shall be paid directly to Lender and applied by Lender to the payment of any amounts owed by Borrower to Lender under this Section 2.18.

(d)          Borrower hereby further agrees to pay to the order of Lender with respect to each Letter of Credit: (i) a nonrefundable commitment fee at an annual rate equal to the Applicable Margin (calculated on an actual day, 360-day year basis) on the face amount (taking into account any scheduled increases or decreases therein during the period in question) of each Letter of Credit, due and payable quarterly, in arrears, on the last day of each fiscal quarter; and  (ii) a nonrefundable issuance fee, a nonrefundable negotiation fee and such other fees as may be charged by Lender from time to time in accordance with Lender’s published schedule of fees in effect from time to time, which fees shall be due and payable on demand by Lender.
 
 
- 12 -
 
 
 
(e)          Notwithstanding any provision contained in this Agreement to the contrary, if any Letters of Credit remain outstanding on the last day of the Revolving Credit Period, Borrower shall, on or before 12:00 noon (St. Louis time) on the last day of the Revolving Credit Period, (i) surrender the originals of the applicable Letter(s) of Credit to Lender for cancellation, or (ii) provide Lender with cash collateral (or other collateral acceptable to Lender in its sole and absolute discretion) in an amount at least equal to the aggregate undrawn face amount of all outstanding Letter(s) of Credit plus all unreimbursed drawings with respect thereto, and execute and deliver to Lender such agreements as Lender may require to grant Lender a first priority perfected security interest in such cash or other collateral.  Any such cash collateral received by Lender pursuant to this Section 2.18(e) shall be held by Lender in a separate account at Lender appropriately designated as a cash collateral account in relation to this Agreement and the Letters of Credit and retained by Lender as collateral security for the payment of Borrower’s Obligations.  Cash amounts delivered to Lender pursuant to the foregoing requirements of this Section 2.18(e) shall be invested, at the request and for the account of Borrower in investments of a type and nature and with a term acceptable to Lender.  Such amounts, including in the case of cash amounts invested in the manner set forth above, shall not be used by Lender to pay any amounts drawn or paid under or pursuant to any Letter of Credit, but may be applied to reimburse Lender for drawings or payments under or pursuant to such Letters of Credit which Lender has paid, or if no such reimbursement is required to the payment of such of the other Borrower’s Obligations as Lender shall determine.  Any amounts remaining in any cash collateral account established pursuant to this Section 2.18(e) after the payment in full of all of the Borrower’s Obligations and the expiration or cancellation of all of the Letters of Credit shall be returned to Borrower (after deduction of Lender’s reasonable expenses, if any).

2.20         Taxes .

(a)          Any and all payments by Borrower to or for the account of Lender under any Transaction Document shall be made free and clear of and without deduction for any and all present or future taxes, duties, levies, imposts, deductions, charges or withholdings, and all liabilities with respect thereto, excluding , in the case of Lender, taxes imposed on or measured by its net income, and franchise taxes imposed on it, by the jurisdiction under the laws of which Lender is organized or any political subdivision thereof (all such non-excluded taxes, duties, levies, imposts, deductions, charges, withholdings and liabilities being hereinafter referred to as “ Taxes ”).  If Borrower shall be required by law to deduct any Taxes from or in respect of any sum payable under any Transaction Document to Lender, (i) the sum payable shall be increased as necessary so that after making all required deductions (including deductions applicable to additional sums payable under this Section 2.20(a)) Lender receives an amount equal to the sum it would have received had no such deduction of Taxes been made, (ii) Borrower shall make such deductions, (iii) Borrower shall pay the full amount deducted to the relevant taxation authority or other authority in accordance with applicable law and (iv) Borrower shall furnish to Lender the original or a certified copy of a receipt evidencing payment thereof.

(b)          In addition, Borrower agrees to pay any present or future stamp or documentary taxes and any other excise or property taxes, or charges or similar levies which arise from any payment made under any of the Transaction Documents or from the execution or delivery of, or otherwise with respect to, any of the Transaction Documents (hereinafter referred to as “ Other Taxes ”).

(c)          Borrower agrees to indemnify Lender for the full amount of Taxes or Other Taxes, respectively (including, without limitation, any Taxes or Other Taxes imposed or asserted by any jurisdiction on amounts payable under this Section 2.20), paid by Lender and any liability (including penalties, interest and expenses) arising therefrom or with respect thereto.  This indemnification shall be made within fifteen (15) days from the date Lender makes demand therefor, accompanied by a certificate of Lender setting forth in reasonable detail its computation of the amount or amounts to be paid to it hereunder.
 
 
- 13 -
 
 
 
(d)          The provisions of this Section 2.20 shall survive any expiration or termination of this Agreement and the payment of the Note and the other Borrower’s Obligations.

SECTION 3.  PRECONDITIONS TO LOANS AND LETTERS OF CREDIT

3.01         Initial Loan .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall have no obligation to make the initial Loan or issue the initial Letter of Credit under this Agreement unless Lender shall have first received:

(a)          this Agreement and the Note, each duly executed by Borrower;

(b)          the Guaranty, duly executed by Laclede Energy;

(c)          a copy of resolutions (including an incumbency certificate) of the Board of Directors of Borrower, duly adopted, which authorize the execution, delivery and performance of this Agreement, the Note and the other Transaction Documents, certified by the Secretary of Borrower;

(d)          a copy of resolutions of the Board of Directors (including an incumbency certificate) of Laclede Energy, duly adopted, which authorize the execution, delivery and performance of its Guaranty, certified by the Secretary of Laclede Energy;

(e)          copies of the Articles of Incorporation of Borrower and Laclede Energy, including any amendments thereto, certified by the Secretary of State of the states of their respective incorporations;

(f)           copies of the Bylaws of Borrower and Laclede Energy, including any amendments thereto, certified by the Secretaries of Borrower and Laclede Energy;

(g)          certificates of corporate good standing of Borrower and Laclede Energy issued by the Secretary of State of the states of their respective incorporations;
 
            (h)          an opinion of the General Counsel of Borrower and Laclede Energy, in form and substance satisfactory to Lender and Lender’s counsel;

(i)           UCC search results from the Missouri Secretary of State for Borrower and Laclede Energy;

(j)           copies of all financial statements and other exhibits and schedules required by this Agreement and the other Transaction Documents;

(k)          a letter of direction from Borrower with respect to the disbursement of the proceeds of the initial Loan under this Agreement;

(l)           a fee letter, duly executed by Borrower and Lender; and

(m)         such other agreements, documents, instruments and certificates as Lender may reasonably request.

3.02         All Loans and Letters of Credit .  Notwithstanding any provision contained in this Agreement to the contrary, Lender shall have no obligation to make any Loan or issue any Letter of Credit under this Agreement unless:

(a)          Lender shall have received a Notice of Borrowing for such Loan as required by Section 2.02(a), or a Letter of Credit Application as required under Section 2.18(a);
 
 
- 14 -
 
 
 
(b)          both immediately before and immediately after giving effect to such Loan or Letter of Credit, no Default or Event of Default shall have occurred and be continuing; and

(c)          all of the representations and warranties made by Borrower in this Agreement (but after the making or issuance of the initial Loan or Letter of Credit hereunder, not including the representation set forth in Section 4.04(b)) and/or in any other Transaction Document shall be true and correct in all material respects on and as of the date of such Loan as if made or such Letter of Credit is issued on and as of the date of such Loan or Letter of Credit (and for purposes of this Section 3.02(c), the representations and warranties made by Borrower in Section 4.04 shall be deemed to refer to the most recent financial statements of Borrower delivered to Lender pursuant to Section 5.01(a)).

Each request for a Loan or Letter of Credit by Borrower under this Agreement shall be deemed to be a representation and warranty by Borrower on the date of such Loan or Letter of Credit as to the facts specified in clauses (b) and (c) of this Section 3.02.

SECTION 4.  REPRESENTATIONS AND WARRANTIES .

Borrower hereby represents and warrants to Lender that:

4.01         Corporate Existence and Power .  Each Loan Party: (a) is duly incorporated, validly existing and in good standing under the laws of the State of Missouri; (b) has all requisite corporate powers required to carry on its business as now conducted; (c) has all requisite governmental and regulatory licenses, authorizations, consents and approvals required to carry on its business as now conducted, except such licenses, authorizations, consents and approvals the failure to have could not reasonably be expected to have a Material Adverse Effect; and (d) is qualified to transact business as a foreign corporation in, and is in good standing under the laws of, all states in which it is required by applicable law to maintain such qualification and good standing except for those states in which the failure to qualify or maintain good standing could not reasonably be expected to have a Material Adverse Effect.

4.02         Corporate Authorization .  The execution, delivery and performance by each Loan Party of this Agreement, the Note and the other Transaction Documents, as applicable, are within the corporate powers of each Loan Party and have been duly authorized by all necessary corporate and other action on the part of each Loan Party.

4.03         Binding Effect .  This Agreement, the Note and the other Transaction Documents to which a Loan Party is a party have been duly executed and delivered by such Loan Party and constitute the legal, valid and binding obligations of such Loan Party enforceable against such Loan Party in accordance with their respective terms, except as such enforceability may be limited by bankruptcy, insolvency or other similar laws affecting creditors’ rights generally and by general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).

4.04         Financial Statements .  Borrower has furnished Lender with the consolidated balance sheets and statements of income, retained earnings and cash flows of Borrower and its Subsidiaries as of and for the fiscal year of Borrower ended September 30, 2009, all certified by Borrower’s independent certified public accountants, which financial statements have been prepared in accordance with GAAP consistently applied.  Borrower further represents and warrants to Lender that (a) said balance sheets and their accompanying notes (if any) fairly present the condition of Borrower and its Subsidiaries as of the dates thereof, (b) there has been no material adverse change in the condition or operation, financial or otherwise, of Borrower and its Subsidiaries taken as a whole since September 30, 2009 except as disclosed in Borrower’s filings with the Securities and Exchange Commission since
 
 
- 15 -
 
 
 
such date, and (c) neither Borrower nor any of its Subsidiaries had any direct or contingent liabilities which were not disclosed on said financial statements or the notes thereto (to the extent such disclosure is required by GAAP).

4.05         Compliance With Other Instruments; None Burdensome .  None of the execution and delivery by a Loan Party of any of the Transaction Documents, the performance by a Loan Party of its obligations under the Transaction Documents or the borrowing and/or repayment of the Loan by Borrower under this Agreement will conflict with, or result in a breach of the terms, conditions or provisions of, or constitute a default under or result in any violation of, any law, rule, regulation, order, writ, judgment, injunction, decree or award binding on such Loan Party, any of the provisions of the Articles of Incorporation or Bylaws (or other applicable organizational documents) of such Loan Party or any of the provisions of any indenture, agreement, document, instrument or undertaking to which such Loan Party is a party or subject, or by which such Loan Party or any property or assets of such Loan Party is bound, or result in the creation or imposition of any security interest, lien or encumbrance on any of the property or assets of such Loan Party pursuant to the terms of any such indenture, agreement, document, instrument or undertaking.  No order, consent, approval, license, authorization or validation of, or filing, recording or registration with, or exemption by, any governmental, regulatory, administrative or public body, instrumentality, authority, agency or official, or any subdivision thereof, or any other Person is required to authorize, or is required in connection with, (a) the execution, delivery or performance of, or the legality, validity, binding effect or enforceability of, any of the Transaction Documents, and/or (b) the borrowing and/or repayment of the Loan by Borrower under this Agreement.

4.06         Regulation U .  Borrower is not engaged principally, or as one of its important activities, in the business of extending credit for the purpose of purchasing or carrying margin stock (within the meaning of Regulation U of The Board of Governors of the Federal Reserve System, as amended) and no part of the proceeds of the Loan will be used, whether directly or indirectly, and whether immediately, incidentally or ultimately (a) to purchase or carry margin stock or to extend credit to others for the purpose of purchasing or carrying margin stock, or to refund or repay indebtedness originally incurred for such purpose or (b) for any purpose that entails a violation of, or which is inconsistent with, the provisions of any of the Regulations of The Board of Governors of the Federal Reserve System, including, without limitation, Regulations U, T or X thereof, as amended.  If requested by Lender, Borrower shall furnish to Lender a statement in conformity with the requirements of Federal Reserve Form U-1 referred to in Regulation U.

4.07         Investment Company Act of 1940; Public Utility Holding Company Act of 2005 .  Borrower is not an “investment company” as that term is defined in, and is not otherwise subject to regulation under, the Investment Company Act of 1940, as amended. Borrower is a holding company for which compliance with the accounting, record retention and reporting sections of the Public Utility Holding Company Act of 2005 has been waived.

4.08         No Default .  No Default or Event of Default under this Agreement has occurred and is continuing.  There is no existing default or event of default under or with respect to any indenture, contract, agreement, lease or other instrument to which Borrower is a party or by which any property or assets of any Loan Party is bound or affected, a default under which could reasonably be expected to have a Material Adverse Effect.  Each Loan Party has and is in full compliance with and in good standing with respect to all governmental permits, licenses, certificates, consents and franchises necessary to continue to conduct its business as previously conducted by it and to own or lease and operate its properties and assets as now owned or leased by it, the failure to have or noncompliance with which could reasonably be expected to have a Material Adverse Effect.  No Loan Party is in violation of any applicable statute, law, rule, regulation or ordinance of the United States of America, of any state, city, town, municipality, county or of any other jurisdiction, or of any agency thereof, a violation of which could reasonably be expected to have a Material Adverse Effect.
 
 
- 16 -
 
 
 
SECTION 5.  COVENANTS .

5.01         Covenants of Borrower .  Borrower covenants and agrees that, so long as any of the Borrower’s Obligations remain unpaid:

(a)          Information.  Borrower will make available, deliver, or cause to be delivered to Lender:

(i)           within one hundred twenty (120) days after the end of each fiscal year of Borrower the consolidated balance sheet of Borrower and its Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, retained earnings and cash flows for such fiscal year, setting forth in each case, in comparative form, the figures for the previous fiscal year, all such financial statements to be prepared in accordance with GAAP consistently applied and reported on by and accompanied by the unqualified opinion of independent certified public accountants selected by Borrower and reasonably acceptable to Lender; provided, however, that delivery to Lender of the Annual Report on Form 10-K of Borrower for such fiscal year filed with the Securities and Exchange Commission shall be deemed to satisfy the requirements of this Section 5.01(a)(i);

(ii)           within one hundred twenty (120) days after the end of each fiscal year of Laclede Energy the consolidated balance sheets of Laclede Energy and its Subsidiaries as of the end of such fiscal year and the related consolidated statements of income, retained earnings and cash flows for such fiscal year, setting forth in each case, in comparative form, the figures for the previous fiscal year, all such financial statements to be prepared internally by Laclede Energy in accordance with GAAP consistently applied.

(iii)          within fifty (50) days after the end of the first three (3) fiscal quarters of each fiscal year of Borrower, a consolidated balance sheet of Borrower and its Subsidiaries as of the end of such fiscal quarter and the related consolidated statements of income, retained earnings and cash flows for such fiscal quarter and for the portion of Borrower’s fiscal year ended at the end of such fiscal quarter, setting forth in each case in comparative form, the figures for the corresponding fiscal quarter and the corresponding portion of Borrower’s previous fiscal year, all in reasonable detail and satisfactory in form to Lender and certified (subject to normal year-end adjustments and absence of footnote disclosures) as to fairness of presentation, consistency and compliance with GAAP by the chief financial officer of Borrower; provided, however, that delivery to Lender of copies of the Quarterly Report on Form 10-Q of Borrower for such fiscal quarter filed with the Securities and Exchange Commission shall be deemed to satisfy the requirements of this Section 5.01(a)(iii);

(iv)          within the time frames outlined in Sections 5.01(a)(i) and 5.01(a)(iii) above, a certificate of an authorized officer of Borrower in the form attached hereto as Exhibit B and incorporated herein by reference (A) stating whether there exists on the date of such certificate any Default or Event of Default and, if any Default or Event of Default then exists, setting forth the details thereof and the action which Borrower is taking or proposes to take with respect thereto, (B) certifying that all of the representations and warranties made by Borrower in this Agreement and/or in any other Transaction Document are true and correct in all material respects on and as of the date of such certificate as if made on and as of the date of such certificate, and (C) setting forth the Consolidated Capitalization Ratio for the relevant reporting period;

(v)          with reasonable promptness, such further information regarding the business, affairs and financial condition of Borrower as Lender may from time to time reasonably request.

(b)           Corporate Existence .  Borrower will do all things necessary to (i) preserve and keep in full force and effect at all times its corporate existence and all permits, licenses, franchises and other rights material to its business and (ii) be duly qualified to do business and be in good standing in all jurisdictions where the nature of its business or its ownership of property or assets requires such
 
 
- 17 -
 
 
 
qualification except for those jurisdictions in which the failure to qualify or be in good standing could not reasonably be expected to have a Material Adverse Effect.

(c)           Compliance with Laws, Regulations, Etc.   Borrower will comply with any and all laws, ordinances and governmental and regulatory rules and regulations to which Borrower is subject and obtain any and all licenses, permits, franchises and other governmental and regulatory authorizations necessary to the ownership of its properties or assets or to the conduct of its business, which violation or failure to obtain could reasonably be expected to have a Material Adverse Effect.

(d)           Further Assurances .  Borrower will execute and deliver to Lender, at any time and from time to time, any and all further agreements, documents and instruments, and take any and all further actions which may be required under applicable law, or which Lender may from time to time reasonably request, in order to effectuate the transactions contemplated by this Agreement and the other Transaction Documents.

(e)           Consolidation or Merger .  Borrower will not directly or indirectly merge or consolidate with or into any other Person.

(f)            Stock and Assets of Subsidiaries .  Unless the prior written consent of Lender is obtained which such consent shall not be unreasonably withheld (in Lender’s commercially reasonable judgment) or unreasonably delayed, Borrower will not create, incur or assume or suffer to be incurred or to exist any security interest, lien or encumbrance on any of the common stock of LGC, Laclede Energy, or any other Subsidiary, or on the inventory or accounts receivable of LGC.

(g)           Sale of Property .  Borrower will not, and will not cause or permit any Subsidiary to, (i) sell, assign, lease, transfer, abandon or otherwise dispose of any of its property (including, without limitation, any shares of capital stock or other equity interests of a Subsidiary owned by Borrower or another Subsidiary) or (ii) issue, sell or otherwise dispose of any shares of capital stock or other equity interests of any Subsidiary; provided , however , that Borrower and each Subsidiary may sell, assign, lease, transfer, abandon or otherwise dispose of (A) any of its natural gas inventory or past-due accounts receivable in the ordinary course of business, (B) any of its property to Borrower or any Subsidiary, provided that , if at anytime more than Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries are transferred to a Subsidiary, such Subsidiary shall then execute a guaranty agreement with respect to Borrower’s Obligations in a form reasonably acceptable to Lender, (C) any of its property subject to LGC’s Mortgage and Deed of Trust dated as of February 1, 1945, as heretofore amended and supplemented, as may be permitted to be sold, assigned, leased, transferred, abandoned or otherwise disposed of under said Mortgage and Deed of Trust, (D) any of its other property (whether in one transaction or a series of transactions) so long as the value of such property sold, assigned, leased, transferred, abandoned or otherwise disposed of in any fiscal year under this subsection (D) shall not exceed Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries as determined on a consolidated basis as of the last day of the immediately preceding fiscal year, and (E) any shares of capital stock sold to Borrower by a Subsidiary; and provided further , however, that nothing in this Agreement shall limit or restrict Borrower’s or any Subsidiary’s use of financial instruments or natural gas contracts under their gas supply risk management programs.

(h)           Changes in Nature of Business .  Borrower will not, and it will not cause or permit any Subsidiary to, engage in any business if, as a result, the general nature of the business that would then be engaged in by Borrower and its Subsidiaries, considered as a whole, would be substantially changed from the general nature of the business engaged in by Borrower and its Subsidiaries as of the date of this Agreement.
 
 
- 18 -
 
 
 
(i)            Permitted Investments; Acquisitions .  Borrower will not, and it will not cause or permit any Subsidiary to, directly or indirectly, make any Investments except for Permitted Investments.  Borrower will not, and it will not cause or permit any Subsidiary to, directly or indirectly, make any Acquisition the result of which would be to change substantially the general nature of the business engaged in by Borrower and its Subsidiaries.

(j)            Maximum Consolidated Capitalization Ratio .  Borrower will at all times maintain a Consolidated Capitalization Ratio of not more than Seventy Percent (70%).

(k)           Subsidiaries .  If Borrower creates, forms or acquires any Subsidiary which owns more than Ten Percent (10%) of the consolidated assets of Borrower and all of its Subsidiaries on or after the date of this Agreement, Borrower will, contemporaneously with the creation, formation or acquisition of such Subsidiary, cause such Subsidiary to execute a guaranty agreement with respect to Borrower’s Obligations in a form reasonably acceptable to Lender.

5.02         Use of Proceeds .  Borrower covenants and agrees that (a) the proceeds of the Loan will be used solely for general corporate purposes, (b) no part of the proceeds of the Loan will be used in violation of any applicable law, rule or regulation and (c) no part of the proceeds of the Loan will be used, whether directly or indirectly, and whether immediately, incidentally or ultimately (i) to purchase or carry margin stock or to extend credit to others for the purpose of purchasing or carrying margin stock, or to refund or repay indebtedness originally incurred for such purpose or (ii) for any purpose which entails a violation of, or which is inconsistent with, the provisions of any of the Regulations of The Board of Governors of the Federal Reserve System, including, without limitation, Regulations U, T or X thereof, as amended.

SECTION 6.  EVENTS OF DEFAULT .

If any of the following (each of the following herein sometimes called an “ Event of Default ”) shall occur and be continuing:

6.01        Borrower shall fail to pay any of Borrower’s Obligations constituting interest, fees or other amounts (other than principal due under the Loan) within ten (10) Business Days after the date the same shall first become due and payable, whether by reason of demand, maturity, acceleration or otherwise;

6.02        Any representation or warranty made by any Loan Party in this Agreement, in any other Transaction Document or in any certificate, agreement, instrument or written statement furnished or made or delivered pursuant hereto or thereto or in connection herewith or therewith, shall prove to have been untrue or incorrect in any material respect when made or effected;

6.03        Borrower shall fail to perform or observe any term, covenant or provision contained in Section 5.01(e) or Section 5.02;

6.04        Borrower shall fail to perform or observe any other term, covenant or provision contained in this Agreement (other than those specified in Sections 6.01 or 6.02 above) and any such failure shall remain unremedied for thirty (30) days after the earlier of (i) written notice of default is given to Borrower by Lender or (ii) any officer of Borrower obtaining actual knowledge of such default;

6.05        This Agreement or any of the other Transaction Documents shall at any time for any reason (other than termination of this Agreement or such other Transaction Documents, as the case may be, in accordance with its terms) cease to be in full force and effect or shall be declared to be null and void by a court of competent jurisdiction, or if the validity or enforceability thereof shall be contested or denied by any Loan Party, or if the transactions completed hereunder or thereunder shall be
 
 
- 19 -
 
 
 
contested by any such Loan Party or if any Loan Party shall deny that it has any further liability or obligation hereunder or thereunder;

6.06        A Loan Party shall (i) voluntarily commence any proceeding or file any petition seeking relief under Title 11 of the United States Code or any other Federal, state or foreign bankruptcy, insolvency, receivership, liquidation or similar law, (ii) consent to the institution of, or fail to contravene in a timely and appropriate manner, any such proceeding or the filing of any such petition, (iii) apply for or consent to the appointment of a receiver, trustee, custodian, sequestrator or similar official of itself or of a substantial part of its property or assets, (iv) file an answer admitting the material allegations of a petition filed against itself in any such proceeding, (v) make a general assignment for the benefit of creditors, (vi) become unable, admit in writing its inability or fail generally to pay its debts as they become due or (vii) take any corporate or other action for the purpose of effecting any of the foregoing;

6.07        An involuntary proceeding shall be commenced or an involuntary petition shall be filed in a court of competent jurisdiction seeking (i) relief in respect of a Loan Party, or of a substantial part of the property or assets of a Loan Party, under Title 11 of the United States Code or any other Federal, state or foreign bankruptcy, insolvency, receivership, liquidation or similar law, (ii) the appointment of a receiver, trustee, custodian, sequestrator or similar official of Borrower or of a substantial part of the property or assets of a Loan Party or (iii) the winding-up or liquidation of a Loan Party, and such proceeding or petition shall continue undismissed for sixty (60) consecutive days or an order or decree approving or ordering any of the foregoing shall continue unstayed and in effect for sixty (60) consecutive days;

6.08        Any Loan Party shall be declared by Lender to be in default under or in respect of (i) any other present or future obligation to Lender, including, without limitation, any other loan, line of credit, revolving credit, guaranty or letter of credit reimbursement obligation, or (ii) any other present or future agreement purporting to convey to Lender a security interest in, or a lien or encumbrance upon, upon any property or assets of any Loan Party;

6.09        Any default occurs under any other financing agreement any Loan Party has with Lender or any affiliate of Lender, after giving effect to any applicable grace or cure periods; the occurrence of any default or event of default under or within the meaning of any agreement, document or instrument evidencing, securing, guaranteeing the payment of or otherwise relating to any indebtedness of any Loan Party for borrowed money (other than Borrower’s Obligations) having an aggregate outstanding principal balance in excess of $10,000,000.00 that is not cured or waived in writing within any applicable cure or grace period; or

6.10        Any Loan Party shall have a judgment in an amount in excess of $15,000,000.00 entered against it by a court having jurisdiction in the premises and such judgment shall not be appealed in good faith (and execution of such judgment stayed during such appeal) or satisfied by such Loan Party within thirty (30) days after the entry of such judgment;

THEN, and in each such event (other than an event described in Sections 6.06 or 6.07), Lender may declare the entire outstanding principal balance of and all accrued and unpaid interest on the Note and all of the other Borrower’s Obligations to be forthwith due and payable, whereupon all of the unpaid principal balance of and all accrued and unpaid interest on the Note and all of such other Borrower’s Obligations shall become and be immediately due and payable, without presentment, demand, protest or further notice of any kind, all of which are hereby expressly waived by Borrower, and Lender may exercise any and all other rights and remedies which it may have under any of the other Transaction Documents or under applicable law; provided , however , that upon the occurrence of any event described in Sections 6.06 or 6.07, the entire outstanding principal balance of and all accrued and unpaid interest on the Note and all of the other Borrower’s Obligations shall automatically become immediately due and payable, without presentment, demand, protest or further notice of any kind, all of
 
 
- 20 -
 
 
 
which are hereby expressly waived by Borrower, and Lender may exercise any and all other rights and remedies which it may have under any of the other Transaction Documents or under applicable law.

SECTION 7.  GENERAL .

7.01         No Waiver .  No failure or delay by Lender in exercising any right, remedy, power or privilege under this Agreement or under any other Transaction Document shall operate as a waiver thereof; nor shall any single or partial exercise thereof preclude any other or further exercise thereof or the exercise of any other right, remedy, power or privilege.  The rights and remedies provided in this Agreement and in the other Transaction Documents are cumulative and not exclusive of any remedies provided by law.  Nothing herein contained shall in any way affect the right of Lender to exercise any statutory or common law right of banker’s lien or set-off.

7.02         Right of Set-Off .  Upon the occurrence and during the continuance of any Event of Default, Lender is hereby authorized at any time and from time to time, without notice to Borrower (any such notice being expressly waived by Borrower) and to the fullest extent permitted by law, to set-off and apply any and all deposits (general or special, time or demand, provisional or final, but specifically excluding any trust or segregated accounts) at any time held by Lender and any and all other indebtedness at any time owing by Lender to or for the credit or account of Borrower against any and all of the Borrower’s Obligations irrespective of whether or not Lender shall have made any demand under this Agreement or under any of the other Transaction Documents and although such obligations may be contingent or unmatured.  Lender agrees to promptly notify Borrower after any such set-off and application made by Lender, provided , however , that the failure to give such notice shall not affect the validity of such set-off and application.  The rights of Lender under this Section 7.02 are in addition to any other rights and remedies (including, without limitation, other rights of set-off) which Lender may have.  Nothing contained in this Agreement or any other Transaction Document shall impair the right of Lender to exercise any right of set-off or counterclaim it may have against Borrower and to apply the amount subject to such exercise to the payment of indebtedness of Borrower unrelated to this Agreement or the other Transaction Documents.

7.03         Cost and Expenses .  Borrower agrees, whether or not any Loan is made under this Agreement, to pay or reimburse Lender upon demand for (a) all out-of-pocket costs and expenses incurred by Lender in connection with the preparation, documentation, negotiation and/or execution of this Agreement and/or any of the other Transaction Documents, (b) all recording, filing and search fees and expenses incurred by Lender in connection with this Agreement and/or any of the other Transaction Documents, (c) all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Lender in connection with the (i) the preparation, documentation, negotiation and execution of any amendment, modification, extension, renewal or restatement of this Agreement and/or any of the other Transaction Documents or (ii) the preparation of any waiver or consent under this Agreement or under any of the other Transaction Documents and (d) if an Event of Default occurs, all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Lender in connection with such Event of Default and collection and other enforcement proceedings resulting therefrom. Borrower further agrees to pay or reimburse Lender upon demand for any stamp or other similar taxes which may be payable with respect to the execution, delivery, recording and/or filing of this Agreement and/or any of the other Transaction Documents.  All of the obligations of Borrower under this Section 7.03 shall survive the satisfaction and payment of the Borrower’s Obligations and the termination of this Agreement.

7.04         General Indemnity .  In addition to the payment of expenses pursuant to Section 7.03, whether or not the transactions contemplated hereby shall be consummated, Borrower hereby agrees to defend, indemnify, pay and hold Lender and any holders of the Note, and the officers, directors, employees, agents and affiliates of Lender and such holders (collectively, the “ Indemnitees ”) harmless from and against any and all other liabilities, obligations, losses, damages, penalties, actions,
 
 
- 21 -
 
 
 
judgments, suits, claims, disbursements, costs and expenses of any kind or nature whatsoever (including, without limitation, the reasonable fees and disbursements of counsel for such Indemnitees in connection with any investigative, administrative or judicial proceeding commenced or threatened, whether or not such Indemnitees shall be designated a party thereto, provided that the Indemnitees shall share counsel to defend their interests to the extent legally practicable), that may be imposed on, incurred by or asserted against the Indemnitees, in any manner relating to or arising out of this Agreement, any of the other Transaction Documents or any other agreement, document or instrument executed and delivered by Borrower in connection herewith or therewith, the statements contained in any commitment letters delivered by Lender, the agreement of Lender to make the Loans under this Agreement or the use or intended use of the proceeds of any Loan under this Agreement (collectively, the “ Indemnified Liabilities ”); provided that (a) the Indemnitees shall promptly (and in any event within fifteen (15) Business Days after receiving notice of the existence of any potential Indemnified Liabilities) notify Borrower in writing of the existence of any potential Indemnified Liabilities; (b) Borrower shall have the right to assume and thereafter conduct the defense of any Indemnified Liabilities with counsel of its choice reasonably satisfactory to the Indemnitees, provided that Borrower will not consent to the entry of any judgment or enter into any settlement with respect to any Indemnified Liabilities without the prior written consent of the Indemnitees (not to be unreasonably withheld) unless the judgment or proposed settlement fully releases such Indemnitees and involves only the payment of money damages that are covered in full by this indemnity and does not impose an injunction or other equitable relief upon any Indemnitee and is subject to confidentiality provisions acceptable to the Indemnitees (which approval will not be unreasonably withheld by the Indemnitees); and (c) Borrower shall have no obligation to an Indemnitee hereunder with respect to Indemnified Liabilities directly resulting from the gross negligence or willful misconduct of that Indemnitee as determined by a court of competent jurisdiction in a final, nonappealable order.  To the extent that the undertaking to indemnify, pay and hold harmless set forth in the preceding sentence may be unenforceable because it is violative of any law or public policy, Borrower shall contribute the maximum portion that it is permitted to pay and satisfy under applicable law to the payment and satisfaction of all Indemnified Liabilities incurred by the Indemnitees or any of them.  The provisions of the undertakings and indemnification set out in this Section 7.04 shall survive satisfaction and payment of Borrower’s Obligations and the termination of this Agreement.

7.05         Notices .  Each notice, request, demand, consent, confirmation or other communication under this Agreement shall be in writing and delivered in person or sent by facsimile or registered or certified mail, return receipt requested and postage prepaid, to the applicable party at its address or facsimile number set forth on the signature pages hereof, or at such other address or facsimile number as any party hereto may designate as its address for communications hereunder by notice so given.  Such notices shall be deemed effective on the day on which delivered or sent if delivered in person or sent by facsimile (with answerback confirmation received), or on the fourth (4th) Business Day after the day on which mailed, if sent by registered or certified mail.

7.06         Consent to Jurisdiction; Waiver of Jury Trial .  BORROWER IRREVOCABLY SUBMITS TO THE NON-EXCLUSIVE JURISDICTION OF ANY MISSOURI STATE COURT SITTING IN THE COUNTY OF ST. LOUIS, MISSOURI OR ANY UNITED STATES OF AMERICA COURT SITTING IN THE EASTERN DISTRICT OF MISSOURI, EASTERN DISTRICT, AS LENDER MAY ELECT, IN ANY SUIT, ACTION OR PROCEEDING ARISING OUT OF OR RELATING TO THIS AGREEMENT OR ANY OTHER TRANSACTION DOCUMENT.  BORROWER HEREBY IRREVOCABLY AGREES THAT ALL CLAIMS IN RESPECT TO SUCH SUIT, ACTION OR PROCEEDING MAY BE HELD AND DETERMINED IN ANY OF SUCH COURTS.  BORROWER IRREVOCABLY WAIVES, TO THE FULLEST EXTENT PERMITTED BY LAW, ANY OBJECTION THAT BORROWER MAY NOW OR HEREAFTER HAVE TO THE LAYING OF VENUE OF ANY SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT, AND BORROWER FURTHER IRREVOCABLY WAIVES ANY CLAIM THAT SUCH SUIT, ACTION OR PROCEEDING BROUGHT IN ANY SUCH COURT HAS BEEN BROUGHT IN AN INCONVENIENT FORUM. BORROWER AUTHORIZES THE SERVICE OF
 
 
- 22 -
 
 
 
PROCESS UPON BORROWER BY REGISTERED MAIL SENT TO BORROWER AT ITS ADDRESS DETERMINED PURSUANT TO SECTION 7.05.   BORROWER AND LENDER HEREBY IRREVOCABLY WAIVE THE RIGHT TO TRIAL BY JURY WITH RESPECT TO ANY ACTION IN WHICH BORROWER AND LENDER ARE PARTIES RELATING TO OR ARISING OUT OF OR IN CONNECTION WITH THIS AGREEMENT OR ANY OF THE OTHER TRANSACTION DOCUMENTS.

7.07         Governing Law .  This Agreement shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).

7.08         Amendments and Waivers .  Any provision of this Agreement, the Note or any of the other Transaction Documents to which Borrower is a party may be amended or waived if, but only if, such amendment or waiver is in writing and is signed by Borrower and Lender.

7.09         References; Headings for Convenience .  Unless otherwise specified herein, all references herein to Section numbers refer to Section numbers of this Agreement, all references herein to Exhibits A and B refer to annexed Exhibits A and B that are hereby incorporated herein by reference and all references herein to Schedule 2.02 refers to annexed Schedule 2.02 that is hereby incorporated herein by reference.  The Section headings are furnished for the convenience of the parties and are not to be considered in the construction or interpretation of this Agreement.

7.10         Successors and Assigns .  The provisions of this Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns, except that Borrower may not assign or otherwise transfer any of its rights or delegate any of its obligations or duties under this Agreement.

7.11         Notice Required by Section 432.047 R.S.Mo.; Entire Agreement .  This notice is provided pursuant to Section 432.047 R.S.Mo.  As used herein, “creditor” means Lender and “this writing” means this Agreement and the other Transaction Documents.   ORAL AGREEMENTS OR COMMITMENTS TO LOAN MONEY, EXTEND CREDIT OR TO FORBEAR FROM ENFORCING REPAYMENT OF A DEBT INCLUDING PROMISES TO EXTEND OR RENEW SUCH DEBT ARE NOT ENFORCEABLE, REGARDLESS OF THE LEGAL THEORY UPON WHICH IT IS BASED THAT IS IN ANY WAY RELATED TO THE CREDIT AGREEMENT. TO PROTECT YOU (BORROWER(S)) AND US (CREDITOR) FROM MISUNDERSTANDING OR DISAPPOINTMENT, ANY AGREEMENTS WE REACH COVERING SUCH MATTERS ARE CONTAINED IN THIS WRITING, WHICH IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN US, EXCEPT AS WE MAY LATER AGREE IN WRITING TO MODIFY IT.   This Agreement embodies the entire agreement and understanding between the parties hereto and supersedes all prior agreements and understandings (oral or written) relating to the subject matter hereof.

7.12         Severability .  In the event any one or more of the provisions contained in this Agreement should be invalid, illegal or unenforceable in any respect, the validity, legality and enforceability of the remaining provisions contained herein shall not in any way be affected or impaired thereby.

7.13         Counterparts .  This Agreement may be executed in any number of counterparts (including facsimile counterparts), each of which shall be deemed an original, but all of which together shall constitute one and the same instrument.

7.14         Confidentiality .  Any information received by Lender from Borrower and clearly marked as confidential shall be treated as confidential by Lender in accordance with its customary practices and procedures.  Notwithstanding such agreement, nothing herein contained shall limit or impair the right or obligation of Lender to disclose such information: (a) to its auditors, attorneys, trustees, employees, directors, officers, advisors, affiliates or agents,  (b) when and as required by any law, ordinance, subpoena or governmental order, rule or regulation, (c) as may be required, requested or
 
 
- 23 -
 
 
 
otherwise appropriate in any report, statement or testimony submitted to any municipal, state, provincial or federal regulatory body or any self-regulatory body having or claiming to have jurisdiction over Lender, (d) which is publicly available or readily ascertainable from public sources, or which is received by Lender from a third Person which or which is not known by Lender to be bound to keep the same confidential, (e) in connection with any proceeding, case or matter pending (or on its face purported to be pending) before any court, tribunal or any governmental agency, commission, authority, board or similar entity, (f) in connection with protection of its interests under this Agreement, the Note or any of the other Transaction Documents, including, without limitation, the enforcement of the terms and conditions of this Agreement, the Note and the other Transaction Documents, or (g) to any entity utilizing such information to rate the creditworthiness of Lender or to rate or classify the debt or equity securities of Lender or report to the public concerning the industry of which such Lender is a part.  It is agreed and understood that Lender shall not be liable to Borrower or any other Person for failure to comply with the foregoing except in any case involving Lender’s gross negligence or willful misconduct as determined by a court of competent jurisdiction in a final, nonappealable order.

7.15         USA PATRIOT Act Lender hereby notifies Borrower that pursuant to the requirements of the USA Patriot Act, Title III of Pub. L. 107-56 (signed into law October 26, 2001) (the “ Act ”), it is required to obtain, verify and record information that identifies Borrower, which information includes the name and address of Borrower and other information that will allow Lender to identify Borrower in accordance with the Act.

IN WITNESS WHEREOF, Borrower and Lender have executed this Agreement as of the day and year first above written.




[SIGNATURES ON FOLLOWING PAGE]

 
- 24 -
 
 

SIGNATURE PAGE-
REVOLVING CREDIT AGREEMENT




Borrower:
 
THE LACLEDE GROUP, INC.
   
By:
/s/ Lynn D. Rawlings
 
 
Lynn D. Rawlings, Treasurer and Assistant Secretary
   
Address:
 
720 Olive Street, Suite 1525
St. Louis, Missouri 63101
Attention: Treasurer
 
Facsimile No.: (314) 421-1979
 
Lender:
   
PNC BANK, NATIONAL ASSOCIATION
   
By:
/s/ Joshua Kuhnash
 
 
Joshua Kuhnash, Assistant Vice President
   
Address:
   
120 South Central Avenue, 8 th Floor
St. Louis, Missouri 63105
Attention: PNC Financial Services Group
 
Facsimile No.: (314) 898-1401


 
 
 
 

SCHEDULE 2.02

Authorized Individuals


Douglas H. Yaeger

Mark D. Waltermire

Steven P. Rasche

Lynn D. Rawlings

Kent H. Sturhahn

Delfina Myers


 
 
 
 

EXHIBIT A

(Form of Note)

REVOLVING CREDIT NOTE


     
$20,000,000.00
 
St. Louis, Missouri
October 1, 2010

FOR VALUE RECEIVED, THE LACLEDE GROUP, INC. , a Missouri corporation (“ Borrower ”), hereby promises to pay to the order of PNC BANK, NATIONAL ASSOCIATION , a national banking association (“ Lender ”), on the last day of the Revolving Credit Period, the principal sum of Twenty Million Dollars ($20,000,000.00), or such lesser sum as may then constitute the aggregate unpaid principal amount of all Loans made by Lender to Borrower pursuant to the Agreement (defined below).  The aggregate principal amount of Revolving Credit Loans that Lender shall be committed to have outstanding under this Revolving Credit Note (this “ Note ”) at any one time shall not exceed Twenty Million Dollars ($20,000,000.00), which amount may be borrowed, paid, reborrowed and repaid, in whole or in part, subject to the terms and conditions of this Note and of the Agreement.

All payments received by Lender under this Note shall be allocated among the principal, interest, collection costs and expenses and other amounts due under this Note in such order and manner as Lender shall elect.  The amount of interest accruing under this Note shall be computed on an actual day, 360-day year basis.

All payments of principal and interest under this Note shall be made in lawful currency of the United States in Federal or other immediately available funds at the office of Lender located at 120 South Central Avenue, 8 th Floor, St. Louis, Missouri 63105 , or such other place as Lender may from time to time designate in writing.

This Note is the “Note” referred to in the Revolving Credit Agreement dated as of the date hereof by and between Borrower and Lender, as the same may from time to time be amended, modified, extended, renewed or restated (the “ Agreement ”; all capitalized terms used and not otherwise defined in this Note shall have the respective meanings ascribed to them in the Agreement.).  The Agreement, among other things, contains provisions for acceleration of the maturity of this Note upon the occurrence of certain stated events and also for prepayments on account of principal of this Note and interest on this Note prior to the maturity of this Note upon the terms and conditions specified therein.

If Borrower shall fail to make any payment of any principal or interest due under this Note as and when the same shall become due, then the entire outstanding principal balance of this Note and all accrued and unpaid interest thereon may be declared to be immediately due and payable in the manner and with the effect as provided in the Loan Agreement.

In the event that any payment of any principal or interest due under this Note is not paid when due, whether by reason of maturity, acceleration or otherwise, and this Note is placed in the hands of an attorney or attorneys for collection, or if this Note is placed in the hands of an attorney or attorneys for representation of Lender in connection with bankruptcy or insolvency proceedings relating to or affecting this Note, Borrower hereby promises to pay to the order of Lender, in addition to all other amounts otherwise due on, under or in respect of this Note, the costs and expenses of such collection and representation, including, without limitation, reasonable attorneys’ fees and expenses (whether or
 
 
 
 
 
 
not litigation shall be commenced in aid thereof).  Borrower hereby waives presentment for payment, demand for payment, protest, notice of protest and notice of dishonor.

This Note shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).


Borrower:
 
THE LACLEDE GROUP, INC .
   
By:
   
 
Lynn D. Rawlings, Treasurer and Assistant Secretary



  - 2 -
 
 
 

EXHIBIT B

(Form of Compliance Certificate)

[Date]


PNC Bank, National Association
120 South Central Avenue, 8 th Floor
St. Louis, Missouri 63105
Attention:  PNC Financial Services Group

Ladies and Gentlemen:

Reference is hereby made to the Revolving Credit Agreement dated as of October 1, 2010, by and between The Laclede Group, Inc. and PNC Bank, National Association, as the same may from time to time amended, modified, extended, renewed or restated (the “ Agreement ”).  All capitalized terms used and not otherwise defined herein shall have the respective meanings ascribed to them in the Agreement.

Borrower hereby certifies to Lender that as of the date hereof:

(a)           except as set forth below, all of the representations and warranties made by Borrower in the Agreement and/or in any of the other Transaction Documents are true and correct in all material respects on and as of the date of this Certificate as if made on and as of the date of this Certificate:

Exceptions:
 
   
;

(b)           except as set forth below, no Default or Event of Default under or within the meaning of the Agreement has occurred and is continuing:

Exceptions:
 
   
; and

(c)           the financial statements of Borrower and its Subsidiaries made available to you are true, correct and complete in all material respects and have been prepared in accordance with GAAP (subject, in the case of any interim financial statements, to normal year-end adjustments and absence of footnote disclosures).

(d)           Borrower had a Consolidated Capitalization Ratio of not more than Seventy Percent (70%) at all times during the period commencing _________, 201_, and ending _________, 201_.

                                     Very truly yours,

THE LACLEDE GROUP, INC.
   
By:
 
Name:
 
Title:
 


 
 
 
 



Exhibit 10.25

THE LACLEDE GROUP 2011
MANAGEMENT CONTINUITY PROTECTION PLAN
(as of January 1, 2011)

This Plan was adopted in the best interests of the Company and its stockholders for the purpose of reinforcing and encouraging the continued attention and dedication of the Plan Participants to their assigned duties without distraction in potentially disturbing circumstances arising from the possibility of any future change in control of the Company.

I.           Participants

Participants shall include all Officers of The Laclede Group, Inc. (the “Company”) and Laclede Gas Company first appointed to an officer position on or after January 1, 2011, as well as certain other key officers of other Company Affiliates as may be first determined on and after January 1, 2011.  It is contemplated that the features set forth below would be incorporated in agreements to be entered into between the Company and each of such officers.

II.           Change In Control
 
Change In Control occurs if and when any “person” (as such term is used in Sections 13(d) and 14(d)(2) of the Securities Exchange Act of 1934) is or becomes a beneficial owner, directly or indirectly, of securities of the Company representing more than fifty percent (50%) of the combined voting power of the Company’s then outstanding securities or when any such person becomes a beneficial owner, directly or indirectly, of at least thirty percent (30%) and no more than fifty percent (50%) of such securities and a majority of the outside members of the Company’s Board of Directors decides that a de facto Change in Control has occurred.

Notwithstanding the foregoing, to the extent that any Award granted under the Plan is subject to the provisions of Section 409A of the Code, the definition of Change of Control shall mean a change in the ownership or effective control of the Company, or in the ownership of a substantial portion of the assets of the Company within the meaning of Section 409A of the Code to the extent such Award constitutes nonqualified deferred compensation within the meaning of Section 409A of the Code.

III.          Cause

With respect to termination by the Company or a Company Affiliate of the Participant’s employment, Cause shall mean:

(i)     Willful and continued failure by the Participant to perform substantially the duties of employment assigned by the Company or any of 
 
 
1
 
 
 
its Affiliates (other than any such failure resulting from incapacity due to physical or mental illness) after a demand for substantial performance has been delivered by the Company, which specifically identifies the manner in which it is believed that the Participant has not substantially performed such duties;

(ii)    Willful engagement by the Participant in misconduct that is materially injurious to the Company or any of its Affiliates.

IV.         Good Reason

With respect to the termination by the Participant of his or her employment with the Company, Good Reason shall mean:

(i)     a material diminution in the Participant’s base salary compensation or Annual Incentive Plan Performance Award target level;

(ii)    a material diminution in the authority, duties or responsibilities of the Participant;

(iii)   a material change, of not less than 25 miles, in the geographic location at which the Participant’s office is located;

(iv)   the failure by the Company or its Affiliates, as applicable, to continue to provide the Participant with benefits substantially similar to those enjoyed by the Participant under any of the tax-qualified, nonqualified or welfare benefit plans of the Company or its Affiliates in which the Participant was participating immediately prior to the Change in Control.

V.         Employment and Employment Termination

Employment with the Company shall include employment with the Company, any Affiliate of the Company, any successor of the Company, or any Affiliate of such successor.
 
Employment Termination shall mean the effective date of:

(i)     the termination by the Company or any of its Affiliates of the Participant's employment with the Company other than for Cause; or

(ii)    the termination by the Participant of his or her employment with the Company for Good Reason;
 
 
2
 
 
 
provided that an event in (i) or (ii) must also be a “separation from service” as defined under Final Treasury Regulation Section 1.409A-1(h), including the default presumptions thereof.
 
VI.         Affiliates

For purposes of the Plan, “Affiliate shall mean (i) any person or entity that directly or indirectly controls, is controlled by or is under common control with the applicable entity and/or (ii) to the extent provided by the Company, any person or entity in which such entity has a significant interest.  The term “control” (including, with correlative meaning, the terms “controlled by” and “under common control with”), as applied to any person or entity, means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of such person or entity, whether through the ownership of voting or other securities, by contract or otherwise; provided , however , with respect to any deferrals subject to Section 409A of the Code, the term “Affiliate” shall mean any member of the applicable entity’s control group within the meaning of Final Treasury Regulation Section 1.409A-1(h)(3), as such may be modified or amended from time to time, by applying the “at least 50 percent” provisions thereof.
 
VII .        Benefits

If, within twenty-four (24) months following a Change in Control, the Company or a subsidiary terminates Participant, other than for Cause, or the Participant terminates his or her employment with the Company and its Affiliates for Good Reason, such Participant shall be entitled to receive at such time (or such other time as provided below) a non-discounted lump sum in an amount equal to the “average annual compensation” as such term is referred to in Treasury Regulation Section 1.280G-1 Question and Answer 34 and such other guidance promulgated under Section 280G of the Internal Revenue Code of 1986, as amended (the “Code”) paid to Participant for the five-year period (or if the Participant is employed by the Company for less than five years, such shorter period) immediately preceding such termination of employment or resignation (each a “separation from service” as shall be determined under Section 409A of the Internal Revenue Code of 1986, as amended (the “Code”), and Final Treasury Regulation 1.409A-1(h), including the default presumptions thereof), multiplied by: (1) in the case of the President or of the Executive Vice President, 2.99 times; or (2) in the case of all other Participants, 2.00 times.

However, notwithstanding the above, in no event shall the benefit be greater than an amount equal to the average monthly compensation paid to Participant for the five-year period (or if employed by the Company for less than five years, such shorter period) immediately preceding such separation from service multiplied by the number of months remaining from such date of separation from service until the date upon which the Participant would have been 65 years of age.
 
 
 
3
 
 
 
Notwithstanding any provision herein to the contrary, if the Company determines that Participant is a “specified employee” as defined in Section 409A(a)(2)(B)(i) of the Code and regulations and other guidance issued thereunder, then such benefit (or portion thereof) shall be paid no earlier than the first day of the seventh month following the month of Participant’s separation from service (with the first such payment being a lump sum equal to the aggregate benefit the Participant would have received during such period if no such payment delay had been imposed, together with interest on such delayed amount during the period of such restriction at a rate, per annum, equal to the applicable federal short-term rate (compounded monthly) in effect under Section 1274(d) of the Code at the time of such separation from service).

Moreover, notwithstanding the above, to the extent, if any, that any payment or distribution of any portion of the benefit described above (together with any other benefit under any other plan, policy or arrangement) would trigger any adverse tax consequences under Section 280G of the Code, or Section 4999 of said Code, such as loss of deductions to the Company, or the payment of an additional excise tax by the Participant, or both, then the benefit hereunder (and to the extent necessary, under any other plan, policy, or arrangement providing for “parachute payments” as defined under Code Section 280G) shall be reduced (on a pro rata basis for all such plans, policies, or arrangements) to $1 less than that extent, and to no greater extent.  Parachute payments and/or any cutback amount and any other determination with respect to Code Section 280G shall be determined by the Company in good faith.
 
VIII.      Amendment/Termination of the Plan

The Company may amend this Plan at any time, and from time to time; provided, however, that no amendment adopted after the effective date of a Change in Control shall have the effect of (i) removing a Participant from this Plan, (ii) adding conditions for participation or the entitlement to receive benefits under this Plan, (iii) reducing the amount of benefits payable to a Participant, or (iv) otherwise restricting a Participant’s right to receive benefits under the Plan, except as may otherwise be required to conform such payments to the requirements of Section 409A of the Code.  The Company’s Board of Directors may terminate the Plan at any time prior to a Change in Control.  The Plan may not be terminated after the effective date of a Change in Control, except that the Plan shall automatically terminate upon payment of all benefits due after such Change in Control.  Notwithstanding the above, the Plan may not be terminated and payments accelerated thereunder contrary to the provisions of Section 409A of the Code including, without limitation, Final Treasury Regulation Section 1.409A-3(j)(4)(ix) with reference to Final Treasury Regulation Section 1.409A-1(g).

 
4
 
 


IX.         Administration

The Plan shall be administered by a person or committee appointed by the Company’s Board of Directors (the “Plan Administrator”).  In the absence of such appointment, the Plan Administrator shall be the Board of Directors.
 
X.          Claim for Benefits

Any claim for benefits under this Plan shall be submitted to the Plan Administrator.  If the Plan Administrator denies the claim for benefits, in whole or in part, the Plan Administrator shall notify the claimant of the adverse benefit determination no later than ninety (90) days after receipt of the claim by the Plan, unless the Plan Administrator determines that special circumstances require an extension of time, which may not exceed a further ninety (90) days, for processing the claim and so notifies the claimant in writing prior to the termination of the initial 90 day period.  In the event that a claim for benefits under this Plan has been denied by the Plan Administrator, the decision shall be subject to review by the Company upon written request of the claimant made to the Plan Administrator within sixty (60) days of receipt by the claimant of notice of such denial.  Upon request and free of charge, the Company shall provide the claimant with reasonably access to all pertinent information, documents and records with respect to the claim.  The decision of the Company upon review shall be in writing and shall state the reasons for the decision and the provisions of this Plan on which the decision is based.  Such decision shall be made within sixty (60) days after the Company’s receipt of written request for such review unless a hearing is necessitated to determine the facts and circumstances, in which event a decision shall be rendered as soon as possible, but not later than one hundred and twenty (120) days after receipt of the claimant’s written request for review.  The decision of the Company upon review shall be final and binding on all persons.
 
XI.         Severability and Applicable Law
 
The illegality of any provision of this Plan shall not affect the enforceability of any other provision of this Plan.  The Plan shall be construed in accordance with and governed by the substantive laws of the State of Missouri without regard to conflict of law rules.
 
XII.        Withholding

All payments made under the Plan to a Participant or his or her beneficiary shall be subject to withholding of such amounts as the Company reasonably may determine are required to be withheld pursuant to any applicable Federal, state, local, or foreign law or regulation.
 
 
5
 
 
 
XIII.       Miscellaneous

The rights of Participants and their beneficiaries to benefits under the Plan shall be solely those of unsecured general creditors of the Company.  The Plan constitutes merely a promise by the Company to make benefit payments in the future.  The Plan is intended to be unfunded for purposes of the Code and Title I of the Employee Retirement Income Security Act of 1974, as amended.  Notwithstanding the foregoing, the Company may contribute to a trust fund under a “rabbi trust” agreement between the Company and a banking organization, if such a trust fund is hereafter established, and payments under the Plan may be made from any such trust fund.  Any asset acquired or held by the Company in connection with the Company’s liabilities under the Plan shall not be deemed to be security for the performance of the Company’s obligations under this Plan.

The rights and interests of Participants and their beneficiaries to benefit payments under the Plan shall not be subject in any manner to anticipation, alienation, sale, transfer, assignment, pledge, encumbrance, attachment or garnishment by creditors of the Participants or their beneficiaries, and any such rights and interests under the Plan shall not be liable for or subject to any obligation or liability of the Participant or beneficiary.

Notwithstanding any other provision of the Plan, the Plan is intended to comply with Section 409A of the Code and shall at all times be interpreted in accordance with such intent that amounts that may become payable to Participant shall not be taxable to such Participants until such amounts are paid in accordance with the terms of the Plan.  To the extent that any provision of the Plan violates Section 409A of the Code and the Final Treasury Regulations promulgated thereunder such that amounts would be taxable to a Participant prior to payment or otherwise subject to penalties under Section 409A of the Code, such provision shall be automatically reformed or stricken to preserve the intent hereof.  Notwithstanding the foregoing, in no event will the Company or any of its Affiliates have any liability for any failure of the Plan to satisfy Section 409A of the Code and such parties do not guarantee that the Plan complies with Section 409A of the Code.



 
6
 
 



Exhibit 10.25a

THE LACLEDE GROUP 2011
MANAGEMENT CONTINUITY PROTECTION AGREEMENT

This AGREEMENT is made as of the ___ day of _______________, 20__, between THE LACLEDE GROUP, INC., a Missouri corporation (the “Company”), and ___________________________________ (the “Executive”).
WHEREAS, upon recommendation of its Chairman, the Board of Directors of the Company has adopted The Laclede Group 2011 Management Continuity Protection Plan (the “Plan”).
WHEREAS, the Plan was adopted in the best interests of the Company and its stockholders for the purpose of reinforcing and encouraging the continued attention and dedication of the Plan Participants, including the Executive, to their assigned duties without distraction in potentially disturbing circumstances arising from the possibility of any future change in control of the Company; and
WHEREAS, as contemplated by the Plan, the Executive and the Company are executing this Management Continuity Protection Agreement; and
WHEREAS, subject only to the “Termination Benefits” (as hereinafter defined) payable hereunder following certain “Employment Terminations” (as hereinafter defined) subsequent to a “Change in Control” (as defined in the Plan), the execution of this Agreement by the Executive and the Company does not give rise to a claim by the Executive that the Executive is entitled to continued employment with the Company or any of its Affiliates.
NOW, THEREFORE, in consideration of the mutual agreements contained herein, the Company and the Executive agree as follows:
 
 
1
 
 
1.            Term of Agreement .  This Agreement shall terminate, except to the extent that any obligation of the Company hereunder remains unpaid as of such time, upon the earlier of: (a) the effective date of the termination by the Executive or by the Company or any of its Affiliates of the Executive’s employment with the Company, if such termination of employment occurs prior to a Change in Control; (b) the date the Executive ceases to serve as an officer of the Company or any of its Affiliates prior to a Change in Control; (c) twenty-four (24) months after a Change in Control, if the Executive’s Employment Termination has not yet occurred as of the end of such twenty-four (24) months; or (d) the date the Company’s Board of Directors terminates the Plan if and only if such termination is prior to a Change in Control.  No benefits shall be payable hereunder unless there shall have been a Change in Control as defined in the Plan, and Executive’s Employment Termination shall thereafter have occurred in accordance with Section 3 hereof.
2.            Termination Following Change in Control .  If a Change in Control shall have occurred, the Executive shall be entitled to the benefits provided in Section 3 hereof upon the subsequent Employment Termination of the Executive.
3.            Benefits upon Employment Termination .  (a) If, after a Change in Control shall have occurred, there is a subsequent Employment Termination of the Executive, prior to the expiration of the twenty-four (24) month period that begins on the effective date of the Change in Control, the Executive shall, subject to the provisions of Sections 3(b) and 4 hereof, be entitled to receive, upon the effective date of such Employment Termination (or such other time as provided below and/or in the Plan in the event of a separation of service of a “specified employee”), a non-discounted lump sum amount
 
 
2
 
 
(hereinafter called the “Termination Benefits”) equal to the average annual compensation (as referenced in the Plan) of the Executive for the five (5) year period (or if not employed for such five (5) year period, such shorter period) immediately preceding the Executive’s Employment Termination with the Company (as described in Section 280G(b)(3)(A) of the Internal Revenue Code of 1986, as amended (the “Code”)), multiplied by [2.99 for president and executive vice presidents/ 2.00 for all other officers].   Notwithstanding any provision herein to the contrary, if Termination Benefits are payable to the Executive and the Company determines that the Executive is a “specified employee” as defined in Section 409A(a)(2)(B)(i) of the Code and regulations and other guidance issued thereunder, then payment of such Termination Benefits (or portion thereof) shall commence no earlier than the first day of the seventh month following the month Executive’s “separation from service” (as referenced below) occurs (with the first such payment being a lump sum equal to the aggregate amount the Executive would have received during such period if no such payment delay had been imposed, together with interest on such delayed amount during the period of such restriction at a rate, per annum, equal to the applicable federal short-term rate (compounded monthly) in effect under Section 1274(d) of the Code at the time of such separation from service).
(b)           Notwithstanding the provisions of Section 3(a) above, in no event shall the Termination Benefits be greater than an amount equal to the average monthly compensation of the Executive for the five (5) year period (or such shorter period, as set forth above) immediately preceding the Executive’s Employment Termination, multiplied by the number of months remaining from such date of Employment
 
 
3
 
 
Termination until the date upon which the Executive would have been sixty-five (65) years of age.
4.            Limitation Upon Termination Benefits Caused by Tax Implications .
In the event that any payment or benefit received or to be received by the Executive in connection with a Change in Control, or the Executive’s Employment Termination, including all amounts payable pursuant to the terms of this Agreement or any other plan, arrangement or agreement with the Company (all of the Termination Benefits, together with all of such other payments or benefits being hereinafter called the “Total Payments”), would not be deductible as a result of Section 280G of the Code, or would trigger the payment of an additional excise tax by the Executive under Section 4999 of the Code, the Termination Benefits (or such other Total Payments to the extent necessary on a pro-rata basis) shall be reduced until no portion of the Total Payments is rendered non-deductible under Section 280G of the Code or is subject to the additional excise tax of Section 4999 of the Code, or the Termination Benefits are reduced to zero.  Parachute payments and/or any cutback amount, and any other determination with respect to Code Section 280G shall be determined by the Plan Administrator in good faith.
5.            Non-exclusivity of Rights .  Nothing in this Agreement shall prevent or limit the Executive’s continuing or future participation in any benefit, bonus, incentive, or other plan or program provided by the Company or its Affiliates and for which the Executive may qualify, nor shall anything herein limit or otherwise affect such rights as the Executive may have under any other agreements with the Company or its Affiliates.  Amounts that are vested benefits or that the Executive is otherwise entitled to receive
 
 
4
 
 
under any plan or program of the Company or its Affiliates shall be payable in accordance with the terms of such plan or program.
6.            Right to Terminate Employment .  The Company expressly confirms and agrees that it has entered into this Agreement and has assumed the obligations imposed on the Company hereby in order to induce the Executive to continue employment with the Company and acknowledges that the Executive is relying upon this Agreement in such capacity.  Notwithstanding the foregoing, the Company or the Executive may terminate the employment of the Executive at any time, subject to the Company’s providing the benefits specified under this Agreement (including, without limitation, those benefits referred to in Sections 3 and 5 hereof) in accordance with the terms hereof.
7.            Heirs, Successors and Assigns .  This Agreement shall: (a) inure to the benefit of and be enforceable by the Executive’s personal or legal representatives, executors, administrators, heirs, devisees and legatees; and (b) be binding on the successors and assigns of the Company.
8.            Severability .  If any provision or aspect of this Agreement shall be held to be invalid, illegal or unenforceable: (a) the validity, legality and enforceability of the remaining provisions or aspects of this Agreement shall not be in any way affected or impaired thereby; and (b) to the fullest extent possible, the provisions of this Agreement shall be construed so as to give effect to the intent manifested by the provision or aspect held invalid, illegal or unenforceable.
9.            Miscellaneous .
(a)  This Agreement shall be governed by and construed in accordance with the laws of the State of Missouri, without regard to choice of law principles.  The
 
 
5
 
 
captions of this Agreement are not part of the provisions hereof and shall have no force or effect.  This Agreement may not be amended or modified other than by a written agreement executed by the parties hereto or by their respective successors and legal representatives.
(b)  For the purposes of this Agreement, notices, demands or other communications necessitated by the provisions of this Agreement shall be in writing and shall be deemed to have been duly given when delivered or mailed by United States Post Office Registered Mail, return receipt requested, postage prepaid and addressed as follows:  to the Executive,  ___________________________________, 720 Olive Street, St. Louis, Missouri 63101; to the Company, The Laclede Group, Inc., Attention: President, 720 Olive Street, St. Louis, Missouri 63101; or to such other address as any party may have furnished to the other in writing in accordance therewith, except that notices of change of address shall be effective only upon receipt.
(c)  This Agreement has been authorized by the Board of Directors of the Company.  It has not been submitted to a shareholder vote of the Company or its parent company, nor is such a shareholder vote contemplated or required.  However, if, prior to a Change in Control, the shareholders of the Company or its parent company should adopt a shareholder proposal to reject part or all of the provisions of this Agreement, then the Company shall have the right unilaterally to modify this Agreement to the extent necessary to comply with such shareholder vote.
(d)  This Agreement (and the Plan, as hereby expressly incorporated herein) contains the entire understanding of the parties hereto with respect to the subject matter hereof.
 
 
6
 
 
(e)  The Company may withhold from any amounts payable under this Agreement such federal, state or local taxes as shall be required to be withheld pursuant to any applicable law or regulation.
(f)  Notwithstanding anything hereinabove, the Plan shall be incorporated by reference into this Agreement, and any inconsistency between the Plan and this Agreement shall be construed in favor of the Plan.
IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the day and year first above written.
           THE LACLEDE GROUP, INC.




By:
 
 
“Company”
   
   
   
   
   
   
   
   
 
“Executive”



                                                               
 
7
 
 


 
Exhibit 12
 
THE LACLEDE GROUP, INC. AND SUBSIDIARY COMPANIES
 
SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
       
       
   
Fiscal Year Ended September 30,
 
   
2010
 
2009
 
2008
 
2007
 
2006
 
(Thousands of Dollars)
                     
                                 
Income from continuing
    operations before interest
    charges and income taxes
 
$
107,986
 
$
126,517
 
$
113,228
 
$
101,867
 
$
100,080
 
Add: One third of applicable
    rentals charged to operating
    expense (which approximates
    the interest factor)
   
1,825
   
1,833
   
1,691
   
1,485
   
1,291
 
        Total Earnings
 
$
109,811
 
$
128,350
 
$
114,919
 
$
103,352
 
$
101,371
 
                                 
Interest on long-term debt –
    Laclede Gas
 
$
24,583
 
$
24,583
 
$
19,851
 
$
22,502
 
$
22,329
 
Other Interest
   
2,269
   
5,163
   
9,626
   
11,432
   
10,555
 
Add: One third of applicable
    rentals charged to operating
    expense (which approximates
    the interest factor)
   
1,825
   
1,833
   
1,691
   
1,485
   
1,291
 
        Total Fixed Charges
 
$
28,677
 
$
31,579
 
$
31,168
 
$
35,419
 
$
34,175
 
                                 
                                 
Ratio of Earnings to Fixed Charges
   
3.83
   
4.06
   
3.69
   
2.92
   
2.97
 
                                 
                                 
                                 

 
 




 
 
 
 


 
LACLEDE GAS COMPANY
 
SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
       
       
   
Fiscal Year Ended September 30,
 
   
2010
 
2009
 
2008
 
2007
 
2006
 
(Thousands of Dollars)
                     
                                 
Income before interest
    charges and income taxes
 
$
84,727
 
$
77,395
 
$
84,684
 
$
80,134
 
$
72,077
 
Add: One third of applicable
    rentals charged to operating
    expense (which approximates
    the interest factor)
   
1,820
   
1,833
   
1,691
   
1,485
   
1,291
 
        Total Earnings
 
$
86,547
 
$
79,228
 
$
86,375
 
$
81,619
 
$
73,368
 
                                 
Interest on long-term debt
 
$
24,583
 
$
24,583
 
$
19,851
 
$
22,502
 
$
22,329
 
Other Interest
   
2,269
   
5,770
   
10,363
   
11,101
   
10,236
 
Add: One third of applicable
    rentals charged to operating
    expense (which approximates
    the interest factor)
   
1,820
   
1,833
   
1,691
   
1,485
   
1,291
 
        Total Fixed Charges
 
$
28,672
 
$
32,186
 
$
31,905
 
$
35,088
 
$
33,856
 
                                 
                                 
Ratio of Earnings to Fixed Charges
   
3.02
   
2.46
   
2.71
   
2.33
   
2.17
 
                                 
                                 
                                 


 
 
 
 



Exhibit 21




 
THE LACLEDE GROUP, INC. AND SUBSIDIARIES
       
SUBSIDIARIES OF THE REGISTRANT
       
 
 
Subsidiaries of The Laclede Group, Inc. (Parent)
 
Percent of Voting Stock Owned
 
       
Laclede Gas Company
 
100%
 
Laclede Pipeline Company
 
100%
 
Laclede Investment LLC*
 
100%
 
Laclede Development Company**
 
100%
 
       
*Subsidiary Company of Laclede Investment LLC
     
Laclede Energy Resources, Inc.
 
100%
 
Subsidiary Company of Laclede Energy Resources, Inc.
     
Laclede Gas Family Services, Inc.
 
100%
 
**Subsidiary Company of Laclede Development Company
     
Laclede Venture Corp.
 
100%
 
       
All of the above corporations have been organized under the laws of the State of Missouri.
 





Exhibit 23

 
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 
We consent to the incorporation by reference in Registration Statement Nos. 333-155714 and 333-155799 of The Laclede Group, Inc. on Form S-3 and in Registration Statement Nos. 333-157367, 333-90248, 333-90252, 333-90254, 333-102836, and 333-131830 of The Laclede Group, Inc. on Form S-8 of our reports dated November 19, 2010, relating to the consolidated financial statements and financial statement schedule of The Laclede Group, Inc. (which report expresses an unqualified opinion), and the effectiveness of The Laclede Group, Inc.’s internal control over financial reporting appearing in this Annual Report on Form 10-K of The Laclede Group, Inc. for the year ended September 30, 2010.


/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010


 
 
 
 

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM


We consent to the incorporation by reference in Registration Statement No. 333-165974 of Laclede Gas Company on Form S-3 of our reports dated November 19, 2010, relating to the financial statements and financial statement schedule of Laclede Gas Company (which report expresses an unqualified opinion), and the effectiveness of Laclede Gas Company’s internal control over financial reporting appearing in Exhibit 99.1 of this Annual Report on Form 10-K of The Laclede Group, Inc. and Laclede Gas Company for the year ended September 30, 2010.



/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010







Exhibit 31

CERTIFICATION

I, Douglas H. Yaeger, certify that:

1.
I have reviewed this annual report on Form 10-K of The Laclede Group, Inc.;
   
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
   
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
   
4.
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
   
   
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
       
   
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
       
   
c)
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
       
   
d)
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 Date:
 
November 19, 2010
Signature:
 
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board,
         
President and Chief
         
Executive Officer

 
 
 
 

CERTIFICATION

I, Mark D. Waltermire, certify that:

1.
I have reviewed this annual report on Form 10-K of The Laclede Group, Inc.;
   
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
   
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
   
4.
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
   
   
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
       
   
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
       
   
c)
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
       
   
d)
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 Date:
 
November 19, 2010
Signature:
 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
           
           

 
 
 
 

CERTIFICATION

I, Douglas H. Yaeger, certify that:

1.
I have reviewed this annual report on Form 10-K of Laclede Gas Company;
   
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
   
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
   
4.
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
   
   
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
       
   
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
       
   
c)
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
       
   
d)
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


 Date:
 
November 19, 2010
Signature:
 
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board,
         
President and Chief
         
Executive Officer

 
 
 
 

CERTIFICATION

I, Mark D. Waltermire, certify that:

1.
I have reviewed this annual report on Form 10-K of Laclede Gas Company;
   
2.
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
   
3.
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
   
4.
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
   
   
a)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
       
   
b)
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
       
   
c)
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
       
   
d)
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.


Date:
 
November 19, 2010
Signature:
 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Senior Vice President and
         
Chief Financial Officer


 
 
 
 



Exhibit 32

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Douglas H. Yaeger, Chairman of the Board, President and Chief Executive Officer of The Laclede Group, Inc., hereby certify that
       
 
(a)
To the best of my knowledge, the accompanying report on Form 10-K for the year ended September 30, 2010 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-K for the year ended September 30, 2010 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.



Date:
 
November 19, 2010
   
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board, President
         
and Chief Executive Officer
           


 
 
 
 

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Mark D. Waltermire, Chief Financial Officer of The Laclede Group, Inc., hereby certify that
       
 
(a)
To the best of my knowledge, the accompanying report on Form 10-K for the year ended September 30, 2010 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-K for the year ended September 30, 2010 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.


Date:
 
November 19, 2010
   
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
           
           



 
 
 
 



Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Douglas H. Yaeger, Chairman of the Board, President and Chief Executive Officer of Laclede Gas Company, hereby certify that
       
 
(a)
To the best of my knowledge, the accompanying report on Form 10-K for the year ended September 30, 2010 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-K for the year ended September 30, 2010 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.


Date:
 
November 19, 2010
   
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board, President
         
and Chief Executive Officer
           


 
 
 
 

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Mark D. Waltermire, Senior Vice President and Chief Financial Officer of Laclede Gas Company, hereby certify that
       
 
(a)
To the best of my knowledge, the accompanying report on Form 10-K for the year ended September 30, 2010 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-K for the year ended September 30, 2010 fairly presents, in all material respects, the financial condition and results of operations of Laclede Gas Company.


Date:
 
November 19, 2010
   
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Senior Vice President and
         
Chief Financial Officer
           
           


 
 
 
 



Exhibit 99.1
     
       
       
Selected Financial Data
     
       
Laclede Gas Company
     
       
       
   
Fiscal Years Ended September 30
 
(Thousands)
 
2010
 
2009
 
2008
 
2007
 
2006
 
Summary of Operations
                               
Operating Revenues:
                               
Utility
 
$
864,297
 
$
1,053,993
 
$
1,128,287
 
$
1,131,554
 
$
1,141,011
 
Other
   
10,327
   
2,246
   
2,693
   
3,415
   
2,305
 
Total Operating Revenues
   
874,624
   
1,056,239
   
1,130,980
   
1,134,969
   
1,143,316
 
                                 
Operating Expenses:
                               
Utility
                               
Natural and propane gas
   
519,905
   
699,984
   
770,097
   
797,924
   
821,721
 
Other operation expenses
   
141,995
   
146,542
   
144,611
   
131,798
   
128,180
 
Maintenance
   
27,244
   
27,818
   
25,827
   
24,306
   
21,198
 
Depreciation and amortization
   
37,572
   
36,751
   
35,303
   
34,080
   
30,904
 
Taxes, other than income taxes
   
61,407
   
68,639
   
69,023
   
68,361
   
71,038
 
Total Utility Operating Expenses
   
788,123
   
979,734
   
1,044,861
   
1,056,469
   
1,073,041
 
Other
   
4,343
   
2,238
   
2,641
   
2,914
   
2,316
 
Total Operating Expenses
   
792,466
   
981,972
   
1,047,502
   
1,059,383
   
1,075,357
 
Operating Income
   
82,158
   
74,267
   
83,478
   
75,586
   
67,959
 
Allowance for Funds Used During Construction
   
(112
 
(152
)
 
(72
 
(17
)
 
(45
)
Other Income and (Income Deductions) – Net
   
2,681
   
3,280
   
1,278
   
4,565
   
4,163
 
Interest Charges:
                               
Interest on long-term debt
   
24,583
   
24,583
   
19,851
   
22,502
   
22,329
 
Other interest charges
   
2,269
   
5,770
   
10,363
   
11,101
   
10,236
 
Total Interest Charges
   
26,852
   
30,353
   
30,214
   
33,603
   
32,565
 
Income Before Income Taxes
   
57,875
   
47,042
   
54,470
   
46,531
   
39,512
 
Income Tax Expense
   
18,150
   
13,859
   
15,264
   
14,047
   
10,632
 
Net Income
   
39,725
   
33,183
   
39,206
   
32,484
   
28,880
 
Dividends on Redeemable Preferred Stock
   
   
15
   
35
   
43
   
48
 
Earnings Applicable to Common Stock
 
$
39,725
 
$
33,168
 
$
39,171
 
$
32,441
 
$
28,832
 











 
1
 
 


Selected Financial Data (continued)
     
       
Laclede Gas Company
     
       
       
   
Fiscal Years Ended September 30
 
(Thousands)
 
2010
 
2009
 
2008
 
2007
 
2006
 
                                 
Dividends Declared –
                               
Common Stock
 
$
35,195
 
$
34,108
 
$
32,811
 
$
31,520
 
$
30,049
 
                                 
Utility Plant
                               
Gross Plant – End of Period
 
$
1,326,284
 
$
1,280,238
 
$
1,229,174
 
$
1,187,828
 
$
1,149,104
 
Net Plant – End of Period
   
884,084
   
855,929
   
823,197
   
793,794
   
763,827
 
Capital Expenditures
   
56,234
   
51,384
   
55,304
   
56,434
   
57,925
 
Property Retirements
   
10,946
   
9,732
   
15,629
   
16,331
   
22,588
 
Total Assets – End of Period
 
$
1,658,452
 
$
1,600,287
 
$
1,625,815
 
$
1,431,203
 
$
1,385,140
 
                                 
Capitalization – End of Period
                               
Common Stock and Paid-In Capital
 
$
208,154
 
$
203,754
 
$
157,883
 
$
151,510
 
$
145,527
 
Retained Earnings
   
205,980
   
201,450
   
202,535
   
195,728
   
194,807
 
Accumulated Other Comprehensive Loss
   
(2,875
)
 
(2,619
)
 
(1,790
 
(1,727
)
 
(834
)
    Common Stock Equity
   
411,259
   
402,585
   
358,628
   
345,511
   
339,500
 
Redeemable Preferred Stock
   
   
   
467
   
627
   
787
 
Long-Term Debt
   
364,298
   
389,240
   
389,181
   
309,122
   
349,041
 
Total Capitalization
 
$
775,557
 
$
791,825
 
$
748,276
 
$
655,260
 
$
689,328
 
                                 











 
2
 
 

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

LACLEDE GAS COMPANY

INTRODUCTION

This management’s discussion analyzes the financial condition and results of operations of Laclede Gas Company (Laclede Gas or the Utility). It includes management’s view of factors that affect its business, explanations of past financial results including changes in earnings and costs from the prior year periods, and their effects on the Utility’s overall financial condition and liquidity.

Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:

weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;
volatility in gas prices, particularly sudden and sustained changes in natural gas prices, including the related impact on margin deposits associated with the use of natural gas derivative instruments;
the impact of changes and volatility in natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;
changes in gas supply and pipeline availability, particularly those changes that impact supply for and access to our service area;
legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting
 
allowed rates of return
 
incentive regulation
 
industry structure
 
purchased gas adjustment provisions
 
rate design structure and implementation
 
regulatory assets
 
franchise renewals
 
environmental or safety matters, including the potential impact of legislative and regulatory actions related to climate change
 
taxes
 
pension and other postretirement benefit liabilities and funding obligations
 
accounting standards, including the effect of potential changes relative to adoption of or convergence with international accounting standards;
the results of litigation;
retention of, ability to attract, ability to collect from, and conservation efforts of, customers;
capital and energy commodity market conditions, including the ability to obtain funds with reasonable terms for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;
discovery of material weakness in internal controls; and
employee workforce issues.

Readers are urged to consider the risks, uncertainties, and other factors that could affect our business as described in this report. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. We do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement in light of future events.

The Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Utility’s financial statements and the notes thereto.



 
3
 
 

LACLEDE GAS COMPANY

RESULTS OF OPERATIONS

Overview

Laclede Gas is regulated by the Missouri Public Service Commission (MoPSC or Commission) and serves the City of St. Louis and parts of ten counties in eastern Missouri. Laclede Gas delivers natural gas to retail customers at rates and in accordance with tariffs authorized by the MoPSC. The Utility’s earnings are primarily generated by the sale of heating energy. The Utility’s weather mitigation rate design lessens the impact of weather volatility on Laclede Gas customers during cold winters and stabilizes the Utility’s earnings by recovering fixed costs more evenly during the heating season. Due to the seasonal nature of the business of Laclede Gas, earnings are typically concentrated in the November through April period, which generally corresponds with the heating season.

Based on the nature of the business of the Utility, as well as current economic conditions, management focuses on the following key variables in evaluating the financial condition and results of operations and managing the business:

the Utility’s ability to recover the costs of purchasing and distributing natural gas from its customers;
the impact of weather and other factors, such as customer conservation, on revenues and expenses;
changes in the regulatory environment at the federal, state, and local levels, as well as decisions by regulators, that impact the Utility’s ability to earn its authorized rate of return;
the Utility’s ability to access credit markets and maintain working capital sufficient to meet operating requirements; and,
the effect of natural gas price volatility on the business.
 
Further information regarding how management seeks to manage these key variables is discussed below.
 
The Utility’s strategy focuses on improving performance and mitigating the impact of weather fluctuations on Laclede Gas’ customers while improving the ability to recover its authorized distribution costs and return. The Utility’s distribution costs are the essential, primarily fixed expenditures it must incur to operate and maintain more than 16,000 miles of mains and services comprising its natural gas distribution system and related storage facilities. The Utility’s distribution costs include wages and employee benefit costs, depreciation and maintenance expenses, and other regulated utility operating expenses, excluding natural and propane gas expense. Distribution costs are considered in the ratemaking process, and recovery of these types of costs is included in revenues generated through the Utility’s tariff rates, as approved by the MoPSC. In addition, Laclede Gas is working to improve its ability to provide reliable natural gas service at a reasonable cost, while maintaining and building a secure and dependable infrastructure. The settlement of the Utility’s rate case in 2010 retained the Utility’s weather mitigation rate design that better ensures the recovery of its fixed costs and margins despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage.

The Utility’s income from off-system sales and capacity release remains subject to fluctuations in market conditions. The Utility is allowed to retain 15% to 25% of the first $6 million in annual income earned (depending on the level of income earned) and 30% of income exceeding $6 million annually. Some of the factors impacting the level of off-system sales include the availability and cost of the Utility’s natural gas supply, the weather in its service area, and the weather in other markets. When Laclede Gas’ service area experiences warmer-than-normal weather while other markets experience colder weather or supply constraints, some of the Utility’s natural gas supply is available for off-system sales and there may be a demand for such supply in other markets. See the Regulatory and Other Matters section on page 11 of this report for additional information on regulatory issues.

 
4
 
 

Laclede Gas works actively to reduce the impact of wholesale natural gas prices on its costs by strategically structuring its natural gas supply portfolio to increase its gas supply availability and pricing alternatives and through the use of derivative instruments to protect its customers from significant changes in the commodity price of natural gas. Nevertheless, the overall cost of purchased gas remains subject to fluctuations in market conditions. The Utility’s Purchased Gas Adjustment (PGA) Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of derivative instruments to hedge the purchase price of natural gas, as well as gas inventory carrying costs. The Utility believes it will continue to be able to obtain sufficient gas supply. The price of natural gas supplies and other economic conditions may affect sales volumes, due to the conservation efforts of customers, and cash flows associated with the timing of collection of gas costs and related accounts receivable from customers. Long-term increases in the wholesale cost of natural gas supplies may adversely impact the Utility’s competitive position compared with alternative energy sources.

The Utility relies on both short-term credit and long-term capital markets, as well as cash flows from operations, to satisfy its seasonal cash requirements and fund its cost of capital expenditures. Laclede Gas’ ability to issue commercial paper supported by lines of credit, to issue long-term bonds, or to obtain new lines of credit is dependent on current conditions in the credit and capital markets. Management focuses on maintaining a strong balance sheet and believes it currently has adequate access to credit and capital markets and will have sufficient capital resources to meet its foreseeable obligations. See the Liquidity and Capital Resources section on page 14 for additional information.

EARNINGS

2010 vs. 2009

Laclede Gas’ earnings applicable to common stock for fiscal year 2010 were $39.7 million, an increase of $6.5 million, compared with fiscal year 2009. The increase in net income was primarily due to the following factors (quantified on a pre-tax basis):

 
income from a non-regulated propane transaction in the wholesale market totaling $6.0 million;
 
decreases in operation and maintenance expenses totaling $5.1 million, including a lower provision for uncollectible accounts totaling $3.4 million;
 
higher Infrastructure System Replacement Surcharge (ISRS) revenues totaling $3.2 million; and,
 
the benefit of the general rate increase, effective September 1, 2010, totaling $2.5 million.

These factors were partially offset by:

 
lower income from off-system sales and capacity release totaling $4.3 million; and,
 
the effect of lower system gas sales volumes and other variations totaling $2.8 million.

2009 vs. 2008

Laclede Gas’ earnings applicable to common stock for fiscal year 2009 were $33.2 million, a decrease of $5.9 million, compared with fiscal year 2008. The decrease in net income was primarily due to the following factors (quantified on a pre-tax basis, except for the income tax item):

 
increases in operation and maintenance expenses, excluding the provision for uncollectible accounts, totaling $4.9 million;
 
the effect of lower system gas sales volumes and other variations totaling $2.0 million;
 
the effect of the recognition of previously unrecognized tax benefits and the reversal of related expenses recorded during fiscal year 2008, totaling $1.6 million; and,
 
an increase in depreciation and amortization expense totaling $1.4 million.

These factors were partially offset by higher ISRS revenues totaling $3.8 million.


 
5
 
 


Utility Operating Revenues

Laclede Gas passes on to Utility customers (subject to prudence review) increases and decreases in the wholesale cost of natural gas in accordance with its PGA Clause. The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income.

2010 vs. 2009

Utility Operating Revenues for fiscal year 2010 decreased $189.7 million compared to fiscal year 2009, primarily due to lower wholesale gas costs. Temperatures experienced in the Utility’s service area during 2010 were 1.6% warmer than the same period last year and 2.5% warmer than normal. Total system therms sold and transported were 894.5 million for fiscal year 2010 compared with 908.0 million for fiscal year 2009. Total off-system therms sold and transported were 71.0 million for fiscal year 2010 compared with 163.0 million for fiscal year 2009. The decrease in Utility Operating Revenues was primarily attributable to the following factors:

(Millions)
     
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
 
$
(141.1
)
Lower off-system sales volumes (reflecting less favorable market conditions as described in greater detail in the
  Results of Operations)
   
(42.8
)
Lower system sales volumes and other variations
   
(10.2
)
Higher ISRS revenues
   
3.2
 
General rate increase, effective September 1, 2010
   
2.5
 
Lower prices charged for off-system sales
   
(1.3
)
      Total Variation
 
$
(189.7
)

2009 vs. 2008

Utility Operating Revenues for fiscal year 2009 decreased $74.3 million compared to fiscal year 2008, primarily due to lower gas prices charged for off-system sales. Temperatures experienced in the Utility’s service area during 2009 were 1.8% warmer than fiscal year 2008 and 1.5% warmer than normal. Total system therms sold and transported were 908.0 million for fiscal year 2009 compared with 934.6 million for fiscal year 2008. Total off-system therms sold and transported were 163.0 million for fiscal year 2009 compared with 143.7 million for fiscal year 2008. The decrease in Utility Operating Revenues was primarily attributable to the following factors:

(Millions)
     
Lower prices charged for off-system sales
 
$
(64.2
)
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
   
(19.0
)
Higher off-system sales volumes (reflecting more favorable market conditions as described in greater
  detail in the Results of Operations)
   
16.6
 
Lower system sales volumes and other variations
   
(11.5
)
Higher ISRS revenues
   
3.8
 
      Total Variation
 
$
(74.3
)


 
6
 
 


Utility Operating Expenses

2010 vs. 2009

Utility Operating Expenses in fiscal year 2010 decreased $191.6 million, or 19.6%, from fiscal year 2009. Natural and propane gas expense decreased $180.1 million from last year’s level, primarily attributable to lower rates charged by our suppliers and lower off-system gas expense. Other operation and maintenance expenses decreased $5.1 million, or 2.9%, primarily due to a lower provision for uncollectible accounts, reduced distribution and maintenance expenses, a lower provision for injuries and damages, and decreased charges for outside services. These factors were partially offset by the effect of a gain on the disposal of assets recorded in fiscal year 2009 and an increase in pension expense. Depreciation and amortization expense increased $0.8 million, or 2.2%, primarily due to additional depreciable property. Taxes, other than income taxes, decreased $7.2 million, or 10.5%, primarily due to decreased gross receipts taxes (attributable to the decreased revenues).

2009 vs. 2008

Utility Operating Expenses in fiscal year 2009 decreased $65.1 million, or 6.2%, from fiscal year 2008. Natural and propane gas expense decreased $70.1 million from fiscal year 2008, primarily attributable to lower off-system gas expense, decreased rates charged by our suppliers, and lower volumes purchased for sendout. Other operation and maintenance expenses increased $3.9 million, or 2.3%, primarily due to increases in compensation expenses, higher maintenance charges, and increased injuries and damages expense, partially offset by a decrease in distribution charges, a lower provision for uncollectible accounts, and a gain on the disposal of assets in fiscal year 2009. Depreciation and amortization expense increased $1.4 million, or 4.1%, primarily due to additional depreciable property.

Other Operating Revenues and Operating Expenses

Other Operating Revenues increased $8.1 million in fiscal year 2010 (compared to fiscal year 2009) primarily due to a propane transaction in the wholesale market by Laclede Gas during the quarter ended December 31, 2009. This non-regulated transaction resulted from an inventory exchange that the counterparty settled in cash instead of through a return of inventory. The increase in Other Operating Expenses, totaling $2.1 million in fiscal year 2010 (compared to fiscal year 2009), was primarily due to expenses associated with this propane transaction.

Other Income and (Income Deductions) - Net

Other Income and (Income Deductions) - Net decreased $0.6 million in fiscal year 2010 (compared to fiscal year 2009), primarily due to lower income associated with carrying costs applied to under-recoveries of gas costs and other minor variations, partially offset by higher net investment gains. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s PGA Clause.

Other Income and (Income Deductions) - Net increased $1.9 million in fiscal year 2009 (compared to fiscal year 2008), primarily due to higher net investment gains and increased income associated with carrying costs applied to under-recoveries of gas costs, partially offset by additional proceeds received during fiscal year 2008 related to the Utility’s interest, as a policyholder, in the sale of a mutual insurance company.

Interest Charges

The $3.5 million decrease in interest charges in fiscal year 2010 (over fiscal year 2009) was primarily due to lower interest on short-term debt. The $0.1 million increase in interest charges in fiscal year 2009 (over fiscal year 2008) was primarily due to higher interest on long-term debt, primarily attributable to the issuance of $80.0 million principal amount of 6.35% first mortgage bonds on September 23, 2008. This increase was largely offset by lower interest on short-term debt. Average short-term interest rates were 0.3% this year compared with 1.6% in fiscal year 2009 and 4.0% in fiscal year 2008. Average short-term borrowings were $107.9 million, $232.7 million, and $203.9 million for fiscal years 2010, 2009, and 2008, respectively.


 
7
 
 

Income Taxes

Income tax expense increased $4.3 million in fiscal year 2010 (over fiscal year 2009) and decreased $1.4 million in fiscal year 2009 (from fiscal year 2008). These variations are primarily due to changes in pre-tax income. The variation in 2009 (compared to 2008) also reflects the effect of lower income tax expense associated with the recognition of previously unrecognized tax benefits recorded during fiscal year 2008.


CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. Generally accepted accounting principles (GAAP) require that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. We believe the following represent the more significant items requiring the use of judgment and estimates in preparing our financial statements:

 
Accounts Receivable and Allowance for Doubtful Accounts – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.

 
Employee Benefits and Postretirement Obligations – Pension and postretirement obligations are calculated by actuarial consultants that utilize several statistical factors and other assumptions provided by management related to future events, such as discount rates, returns on plan assets, compensation increases, and mortality rates. For the Utility, the amount of expense recognized and the amounts reflected in other comprehensive income are dependent upon the regulatory treatment provided for such costs, as discussed further below. Certain liabilities related to group medical benefits and workers’ compensation claims, portions of which are self-insured and/or contain “stop-loss” coverage with third-party insurers to limit exposure, are established based on historical trends.


 
8
 
 


The table below reflects the sensitivity of Laclede’s plans to potential changes in key assumptions:

Pension Plan Benefits:
                     
                       
           
Estimated
     
Estimated
 
           
Increase/
     
Increase/
 
           
(Decrease) to
     
(Decrease) to
 
           
Projected
     
Annual
 
           
Benefit
     
Net Pension
 
   
Increase/
     
Obligation
     
Cost*
 
Actuarial Assumptions
 
(Decrease)
     
(Thousands)
     
(Thousands)
 
                         
Discount Rate
 
0.25
%
   
$
(9,820
)
 
$
199
 
   
(0.25
)
     
10,120
     
(220
)
                         
Rate of Future Compensation Increase
 
0.25
%
     
6,400
     
380
 
   
(0.25
)
     
(6,300
)
   
(370
)
                         
Expected Return on Plan Assets
 
0.25
%
     
     
(610
)
   
(0.25
)
     
     
610
 
                         
Postretirement Benefits:
                       
                         
             
Estimated
     
Estimated
 
             
Increase/
     
Increase/
 
             
(Decrease) to
     
(Decrease) to
 
             
Projected
     
Annual Net
 
             
Postretirement
     
Postretirement
 
             
Benefit
     
Benefit
 
   
Increase/ 
       
Obligation
     
Cost*
 
Actuarial Assumptions
 
(Decrease)
       
(Thousands)
     
(Thousands)
 
                         
Discount Rate
 
0.25
%
   
$
(2,320
)
 
$
(116
)
   
(0.25
)
     
2,380
     
114
 
                         
Expected Return on Plan Assets
 
0.25
%
     
     
(100
)
   
(0.25
)
     
     
100
 
                         
Annual Medical Cost Trend
 
1.00
%
     
5,850
     
1,270
 
   
(1.00
)
     
(5,300
)
   
(1,130
)
                         
* Excludes the impact of regulatory deferral mechanism. See Note 2 , Pension Plans and Other Postretirement Benefits, of the Notes to Financial Statements for information regarding the regulatory treatment of these costs.


 
9
 
 


Regulated Operations Laclede Gas accounts for its regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. Management believes the following represent the more significant items recorded through the application of this accounting guidance:

 
The Utility’s PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including the costs, cost reductions, and related carrying costs associated with the Utility’s use of natural gas derivative instruments to hedge the purchase price of natural gas. The difference between actual costs incurred and costs recovered through the application of the PGA are recorded as regulatory assets and regulatory liabilities that are recovered or refunded in a subsequent period. The PGA Clause also authorizes the Utility to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The PGA Clause also permits the application of carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments. The PGA Clause also provides for a portion of income from off-system sales and capacity release revenues to be flowed through to customers.
   
 
Laclede Gas records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes, and the amounts used for income tax purposes. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or regulatory liability accounts for regulated activities. Pursuant to the direction of the MoPSC, Laclede Gas’ provision for income tax expense for financial reporting purposes reflects an open-ended method of tax depreciation. Laclede Gas’ provision for income tax expense also records the income tax effect associated with the difference between overheads capitalized to construction for financial reporting purposes and those recognized for tax purposes without recording an offsetting deferred income tax expense. These two methods are consistent with the regulatory treatment prescribed by the MoPSC.
   
 
Asset retirement obligations are recorded in accordance with GAAP using various assumptions related to the timing, method of settlement, inflation, and profit margins that third parties would demand to settle the future obligations. These assumptions require the use of judgment and estimates and may change in future periods as circumstances dictate. As authorized by the MoPSC, Laclede Gas accrues future removal costs associated with its property, plant and equipment through its depreciation rates, even if a legal obligation does not exist as defined by GAAP. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognizable pursuant to GAAP is a timing difference between the recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities.


 
10
 
 


 
The amount of net periodic pension and other postretirement benefit cost recognized in the financial statements related to the Utility’s qualified pension plans and other postretirement benefit plans is based upon allowances, as approved by the MoPSC, which have been established in the rate-making process for the recovery of these costs from customers. The differences between these amounts and actual pension and other postretirement benefit costs incurred for financial reporting purposes are deferred as regulatory assets or regulatory liabilities. GAAP also requires that changes that affect the funded status of pension and other postretirement benefit plans, but that are not yet required to be recognized as components of pension and other postretirement benefit cost, be reflected in other comprehensive income. For the Utility’s qualified pension plans and other postretirement benefit plans, amounts that would otherwise be reflected in other comprehensive income are deferred with entries to regulatory assets or regulatory liabilities.

For further discussion of significant accounting policies, see Note 1 of the Notes to Financial Statements included on page 28.


REGULATORY AND OTHER MATTERS

There have been several significant regulatory developments affecting Laclede Gas.

During fiscal year 2006, the MoPSC approved permanent modifications to the Cold Weather Rule affecting the disconnection and reconnection practices of utilities during the winter heating season. Those modifications included provisions to allow the Utility to obtain accounting authorizations and defer for future recovery certain costs incurred with the modifications. During fiscal year 2007, the Utility deferred for future recovery $2.7 million of costs associated with the fiscal year 2007 heating season. In 2008, the Utility and the MoPSC Staff filed a Non-Unanimous Stipulation & Agreement in which these parties agreed to a recovery of $2.5 million of costs, which Public Counsel opposed. The Commission approved the $2.5 million cost recovery recommended by the Utility and the MoPSC Staff, which Public Counsel appealed to the Cole County, Missouri Circuit Court. In 2009, the Court affirmed the Commission’s Order and Public Counsel appealed to the Court of Appeals for the Western District of Missouri. On December 22, 2009, the Court of Appeals also issued a judgment affirming the Commission’s Order. On January 5, 2010, Public Counsel sought rehearing of the decision or transfer to the Missouri Supreme Court. The Court subsequently denied this request.

On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, Laclede Energy Resources, Inc. (LER). The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. On December 31, 2009, the MoPSC Staff proposed a number of non-monetary recommendations only, based on its review of gas costs for fiscal year 2008. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.

In its December 31, 2007 recommendation relating to fiscal year 2006 gas costs, the MoPSC Staff also raised questions regarding whether certain sales and capacity release transactions subject to the Federal Energy Regulatory Commission (FERC)’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. Laclede Group, Inc. (Laclede Group) commenced an internal review of the questions raised by the MoPSC Staff and notified the FERC Staff that it took this action. In June 2008, as a result of the internal review, Laclede Group provided the FERC Staff with a self report regarding compliance of sales and capacity release activities with the FERC’s regulations and policies. On February 9, 2010, the FERC Staff informed Laclede Group that it has closed its investigation of the Laclede Group’s self report without taking further action.

 
11
 
 


In connection with the affiliate transaction matters mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order approving a 2001 Stipulation and Agreement that permitted the Company’s corporate reorganization into a holding company structure. Also, on October 6, 2010, the MoPSC Staff filed a related complaint against Laclede Gas alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. Laclede Gas believes that neither of the complaints have merit and intends to vigorously oppose both of them. In addition, the Company had filed a counterclaim against the MoPSC Staff in the July 7 complaint case alleging that the Staff has failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and the provisions under which the Company allocates costs among affiliated companies. However, on November 3, 2010, the MoPSC issued an order dismissing the Utility’s counterclaim for failure to state a claim upon which relief may be granted.

On July 9, 2008, Laclede Gas made a tariff filing with the MoPSC that would make the payment provisions for the restoration of gas service under the Utility’s Cold Weather Rule available to customers in the summer of 2008 and enable the Utility to increase or decrease its PGA rates to correct for any shortfall or surplus created by the difference between the gas cost portion of the Utility’s actual net bad debt write-offs and the amount of such cost that is embedded in its existing rates. As a result of the ensuing procedural schedule, the Cold Weather Rule portion of the filing became moot. On April 15, 2009, the Commission rejected the Utility’s tariffs on the grounds that it did not have the legal authority to approve them, of which Laclede Gas sought judicial review. On January 11, 2010, the Court found that the Commission did have the legal authority to approve such tariffs, which decision the Commission appealed to the Missouri Court of Appeals, Western District. On October 19, 2010, the Western District overruled the Cole County Circuit Court’s decision, and affirmed the Commission’s April 15, 2009 Order. Laclede Gas has filed with the Western District a motion for rehearing and an application to transfer the case to the Missouri Supreme Court.

On December 4, 2009, Laclede Gas filed tariff sheets in a new general rate case proceeding designed to increase revenues by approximately $52.6 million annually, or 6.9%. On July 23, 2010 and August 3, 2010, the Utility and the other parties to the proceeding filed Stipulation and Agreements that comprised a settlement of all matters and provided for a net $20.5 million increase in annual revenues, reflecting an annual increase of $31.4 million in base rates minus $10.9 million that was being billed to customers through the ISRS. The settlement also retained the Utility’s weather mitigation rate design and provided for the funding of various low-income, weatherization, and conservation and energy efficiency programs. On August 18, 2010, the MoPSC approved the settlement, which became effective September 1, 2010.

On January 15, 2010, the Utility made an ISRS filing with the Commission designed to increase revenues by $3.2 million annually, $2.8 million of which the MoPSC approved effective March 31, 2010. These surcharges were reset to zero effective September 1, 2010, as the ISRS-related costs are being recovered through new base rates effective on that same date. On October 29, 2010, the Utility made an ISRS filing with the Commission designed to increase revenues $2.6 million annually, pending approval by the Commission.

On June 29, 2010, the Office of Federal Contract Compliance Programs issued a Notice of Violations to Laclede Gas alleging lapses in certain employment selection procedures during a two-year period ending in February 2006. The Utility believes that the allegations lack merit and is vigorously defending its position. While the results of the claims cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the financial position and results of operations of the Utility.


ACCOUNTING PRONOUNCEMENTS

Laclede Gas has evaluated or is in the process of evaluating the impact that recently issued accounting standards will have on the Utility’s financial position or results of operations upon adoption. For disclosures related to the adoption of new accounting standards, see the New Accounting Standards section of Note 1 of the Notes to Financial Statements.



 
12
 
 

INFLATION

The accompanying financial statements reflect the historical costs of events and transactions, regardless of the purchasing power of the dollar at the time. Due to the capital-intensive nature of the business of Laclede Gas, the most significant impact of inflation is on the depreciation of utility plant. Rate regulation, to which Laclede Gas is subject, allows recovery through its rates of only the historical cost of utility plant as depreciation. While no plans exist to undertake replacements of plant in service other than normal replacements and those under existing replacement programs, Laclede Gas believes that any higher costs experienced upon replacement of existing facilities would be recovered through the normal regulatory process.


FINANCIAL CONDITION


CASH FLOWS

Laclede Gas’ short-term borrowing requirements typically peak during colder months when Laclede Gas borrows money to cover the lag between when it purchases its natural gas and when its customers pay for that gas. Changes in the wholesale cost of natural gas (including cash payments for margin deposits associated with the Utility’s use of natural gas derivative instruments), variations in the timing of collections of gas cost under the Utility’s PGA Clause, the seasonality of accounts receivable balances, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year and from year to year, and can cause significant variations in the Utility’s cash provided by or used in operating activities.

Net cash provided by operating activities for fiscal years 2010 and 2009 was $92.6 million and $216.4 million, respectively. Net cash used in operating activities for fiscal year 2008 was $45.6 million. The decrease in net cash provided by operating activities in fiscal year 2010 (compared to fiscal year 2009) is primarily attributable to increased cash payments for natural gas storage inventories this year. The improvement in cash flows provided by operating activities in fiscal year 2009 (over fiscal year 2008) was primarily attributable to reduced payments for natural gas storage inventories, other variations in the timing of the collection of gas costs under the PGA Clause, and reduced cash payments to Laclede Group for the Utility’s allocation of income taxes.

Net cash used in investing activities for fiscal years 2010, 2009, and 2008 was $59.8 million, $51.6 million, and $56.4 million, respectively. Net cash used in investing activities primarily reflected capital expenditures in all periods.

Net cash used in financing activities for fiscal years 2010 and 2009 was $33.2 million and $166.6 million, respectively. Net cash provided by financing activities for fiscal year 2008 was $102.7 million. The decrease in net cash used in financing activities in fiscal year 2010 (over fiscal year 2009) primarily reflects a reduction in repayments of short-term debt, partially offset by reduced sales of shares of common stock to Laclede Group. The variation in net cash used in financing activities in fiscal year 2009 (over fiscal year 2008) primarily reflects an increase in the repayments of short-term debt in fiscal year 2009 and the net effect of changes in long-term debt during fiscal year 2008, partially offset by the sale of additional shares of common stock to Laclede Group in fiscal year 2009.



 
13
 
 

LIQUIDITY AND CAPITAL RESOURCES

Short-term Debt

As indicated above, the Utility’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. Laclede Gas has a syndicated line of credit in place of $320 million from 10 banks, with the largest portion provided by a single bank being 17.5%. This line expires in December 2011. During fiscal year 2010, Laclede Gas utilized only commercial paper for external short-term funding. Commercial paper borrowings ranged between $48.2 million and $178.0 million during the fiscal year, and stood at $129.7 million on September 30, 2010. The weighted average interest rate on the short-term borrowings was 0.3% per annum at September 30, 2010. For the entire fiscal year, short-term borrowings averaged $107.9 million at an average interest rate of 0.3%. Based on average short-term borrowings for the year, an increase in the average interest rate of 100 basis points would decrease pre-tax earnings and cash flows by approximately $1.1 million on an annual basis. Portions of such increases or decreases may be offset through the application of PGA carrying costs. Laclede Gas borrowed a maximum of $1.2 million from Laclede Group during the fiscal year, and there were no such borrowings outstanding at the end of the fiscal year.

Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation and amortization (EBITDA) to be at least 2.25 times interest expense. On September 30, 2010, total debt was 56% of total capitalization . For the fiscal year ended September 30, 2010, EBITDA was 4.55 times interest expense.

Long-term Debt, Equity, and Shelf Registration

Laclede Gas has on file with the Securities and Exchange Commission an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, which expires May 28, 2013. The entire amount of this shelf registration remains available to Laclede Gas at this time.

The Utility has MoPSC authority to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in capital, and enter into capital lease agreements, all for a total of up to $518 million, effective from June 30, 2010 through June 30, 2013. During fiscal year 2010, pursuant to this and previous authorities, the Utility sold 40 shares of its common stock to Laclede Group for $1.4 million. As of November 19, 2010, $517.6 million remains available under this authorization. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions, as well as future MoPSC authorizations.

At September 30, 2010, Laclede Gas had fixed-rate long-term debt totaling $390 million (including current maturities). On November 15, 2010, Laclede Gas paid at maturity $25 million principal amount of 6 1/2% first mortgage bonds. This maturity was funded through short-term borrowings. While the remaining long-term debt issues are fixed-rate, they are subject to changes in their fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period. Of the Utility’s $390 million in long-term debt, $75 million have no call option, $235 million have make-whole call options, and $80 million are callable at par in 2013. None of the debt has any put options.

Guarantees

Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends into 2015. At September 30, 2010, the maximum guarantees under these leases were $1.3 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At September 30, 2010, the carrying value of the liability recognized for these guarantees was $0.3 million.


 
14
 
 

Other

The Utility’s access to capital markets, including the commercial paper market, and its financing costs, may depend on its credit rating. These ratings, which are indicated below, were unchanged over the past fiscal year, but remain subject to review and change by the rating agencies.

Type of Facility
S&P
Moody’s
Fitch
Laclede Gas Issuer Rating
A
 
A-
Laclede Gas First Mortgage Bonds
A
A2
A+
Laclede Gas Commercial Paper
A-1
P-2
F1

Utility capital expenditures were $56.2 million in fiscal year 2010, compared with $51.4 million and $55.3 million for fiscal years 2009 and 2008, respectively. Utility capital expenditures are expected to be approximately $64 million in fiscal year 2011. The increase in capital expenditures expected for fiscal year 2011, compared with prior periods, is primarily attributable to anticipated additional expenditures for distribution plant, as well as other planned improvements to the Utility’s natural gas storage facilities and general plant purchases.

Capitalization at September 30, 2010, consisted of 53.0% common stock equity and 47.0% long-term debt.

Laclede Gas’ ratio of earnings to fixed charges was 3.0 for fiscal year 2010, 2.5 for fiscal year 2009, and 2.7 for fiscal year 2008.

It is management’s view that Laclede Gas has adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements, which primarily include capital expenditures, scheduled maturities of long-term debt, short-term seasonal needs, and dividends.



 
15
 
 

CONTRACTUAL OBLIGATIONS

As of September 30, 2010, Laclede Gas had contractual obligations with payments due as summarized below (in millions):

   
Payments due by period
 
       
Less than
 
1-3
 
3-5
 
More than
 
Contractual Obligations
 
Total
 
1 Year
 
Years
 
Years
 
5 Years
 
Principal Payments on Long-Term Debt
 
$
390.0
 
$
25.0
 
$
25.0
 
$
 
$
340.0
 
Interest Payments on Long-Term Debt
   
484.9
   
23.8
   
45.1
   
42.7
   
373.3
 
Operating Leases (a)
   
15.0
   
5.1
   
6.9
   
3.0
   
 
Purchase Obligations – Natural Gas (b)
   
410.1
   
259.2
   
116.8
   
19.7
   
14.4
 
Purchase Obligations – Other (c)
   
89.1
   
17.4
   
18.2
   
16.6
   
36.9
 
Total (d)
 
$
1,389.1
 
$
330.5
 
$
212.0
 
$
82.0
 
$
764.6
 

(a)
Operating lease obligations are primarily for office space, vehicles, and power operated equipment. Additional payments will be incurred if renewal options are exercised under the provisions of certain agreements.
(b)
These purchase obligations represent the minimum payments required under existing natural gas transportation and storage contracts and natural gas supply agreements. These amounts reflect fixed obligations as well as obligations to purchase natural gas at future market prices, calculated using September 30, 2010 New York Mercantile Exchange futures prices. Laclede Gas recovers the costs related to its purchases, transportation, and storage of natural gas through the operation of its PGA Clause, subject to prudence review by the MoPSC; however, variations in the timing of collections of gas costs from customers affect short-term cash requirements. Additional contractual commitments are generally entered into prior to or during the heating season.
(c)
These purchase obligations reflect miscellaneous agreements for the purchase of materials and the procurement of services necessary for normal operations.
(d)
The categories of Capital Leases and Other Long-Term Liabilities have been excluded from the table above because there are no material amounts of contractual obligations under these categories. Long-term liabilities associated with unrecognized tax benefits, totaling $6.4 million, have been excluded from the table above because the timing of future cash outflows, if any, cannot be reasonably estimated. Also, commitments related to pension and postretirement benefit plans have been excluded from the table above. Laclede Gas expects to make contributions to its qualified, trusteed pension plans totaling $10.6 million in fiscal year 2011. Laclede Gas anticipates a $2.4 million contribution relative to its non-qualified pension plans during fiscal year 2011. With regard to the postretirement benefits, the Utility anticipates it will contribute $13.3 million to the qualified trusts and $0.3 million directly to participants from Laclede Gas’ funds during fiscal year 2011. For further discussion of the Utility’s pension and postretirement benefit plans, refer to Note 2 , Pension Plans and Other Postretirement Benefits, of the Notes to Financial Statements.



 
16
 
 

MARKET RISK

Laclede Gas’ commodity price risk, which arises from market fluctuations in the price of natural gas, is primarily managed through the operation of its PGA Clause. The PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies. The Utility is allowed the flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months. The Utility is able to mitigate, to some extent, changes in commodity prices through the use of physical storage supplies and regional supply diversity. Laclede Gas also has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing its price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. However, the timing of recovery for cash payments related to margin requirements may cause short-term cash requirements to vary. Nevertheless, carrying costs associated with such requirements, as well as other variations in the timing of collections of gas costs, are recovered through the PGA Clause. For more information about the Utility’s natural gas derivative instruments, see Note 8 , Derivative Instruments and Hedging Activities, of the Notes to Financial Statements.

The Utility is subject to interest rate risk associated with its long-term and short-term debt issuances. In fiscal year 2010, an increase of 100 basis points in the underlying average interest rate for short-term debt would have caused an increase in interest expense of approximately $1.1 million. Portions of such increases may be offset through the application of PGA carrying costs. At September 30, 2010, Laclede Gas had fixed-rate long-term debt, including current obligations, totaling $390 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period.


ENVIRONMENTAL MATTERS

Laclede Gas owns and operates natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. For information relative to environmental matters, see Note 12 , Commitments and Contingencies, of the Notes to Financial Statements.


OFF-BALANCE SHEET ARRANGEMENTS

Laclede Gas has no off-balance sheet arrangements.

 
17
 
 

Management Report on Internal Control Over Financial Reporting

Management is responsible for establishing and maintaining adequate internal controls over financial reporting. Laclede Gas’ internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements and can provide only reasonable assurance with respect to financial statement preparation and presentation. Also, projections of any evaluation of effectiveness to future periods are subject to the risks that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Laclede Gas’ management, including our Chief Executive Officer and Chief Financial Officer, conducted an assessment of the effectiveness of Laclede Gas’ internal control over financial reporting as of September 30, 2010. In making this assessment, management used the criteria in Internal Control – Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on that assessment, management concluded that Laclede Gas’ internal control over financial reporting was effective as of September 30, 2010. Deloitte & Touche LLP, an independent registered public accounting firm, has issued an attestation report on the Laclede Gas’ internal control over financial reporting, which is included herein.


 
18
 
 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of
Laclede Gas Company
St. Louis, Missouri

We have audited the internal control over financial reporting of Laclede Gas Company (a wholly-owned subsidiary of The Laclede Group, Inc.) (the “Company”) as of September 30, 2010, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed by, or under the supervision of, the company’s principal executive and principal financial officers, or persons performing similar functions, and effected by the company’s board of directors, management, and other personnel to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of the inherent limitations of internal control over financial reporting, including the possibility of collusion or improper management override of controls, material misstatements due to error or fraud may not be prevented or detected on a timely basis. Also, projections of any evaluation of the effectiveness of the internal control over financial reporting to future periods are subject to the risk that the controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of September 30, 2010, based on the criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the financial statements and financial statement schedule as of and for the year ended September 30, 2010 of the Company and our report dated November 19, 2010 expressed an unqualified opinion on those financial statements and financial statement schedule.

/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010

 
19
 
 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
 
To the Board of Directors and Shareholder of
Laclede Gas Company
St. Louis, Missouri
 
We have audited the accompanying balance sheets and statements of capitalization of Laclede Gas Company (a wholly-owned subsidiary of The Laclede Group, Inc.) (the “Company”) as of September 30, 2010 and 2009, and the related statements of income, common shareholder’s equity, comprehensive income, and cash flows for each of the three years in the period ended September 30, 2010. Our audits also included the financial statement schedule listed in the Index at Item 15. These financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on the financial statements and financial statement schedule based on our audits.
 
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). 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 financial position of Laclede Gas Company as of September 30, 2010 and 2009, and the results of its operations and cash flows for each of the three years in the period ended September 30, 2010, 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 financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.
 
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the Company’s internal control over financial reporting as of September 30, 2010, based on the criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated November 19, 2010 expressed an unqualified opinion on the Company's internal control over financial reporting.
 

 
/s/ DELOITTE & TOUCHE LLP
St. Louis, Missouri
November 19, 2010



 
20
 
 


LACLEDE GAS COMPANY
                         
STATEMENTS OF INCOME
                         
                           
(Thousands)
                         
Years Ended September 30
     
2010
     
2009
   
  
2008
 
                                 
Operating Revenues:
                               
  Utility
     
$
864,297
     
$
1,053,993
     
$
1,128,287
 
  Other
       
10,327
       
2,246
       
2,693
 
          Total Operating Revenues
       
874,624
       
1,056,239
       
1,130,980
 
                                 
Operating Expenses:
                               
  Utility
                               
    Natural and propane gas
       
519,905
       
699,984
       
770,097
 
    Other operation expenses
       
141,995
       
146,542
       
144,611
 
    Maintenance
       
27,244
       
27,818
       
25,827
 
    Depreciation and amortization
       
37,572
       
36,751
       
35,303
 
    Taxes, other than income taxes
       
61,407
       
68,639
       
69,023
 
          Total Utility Operating Expenses
       
788,123
       
979,734
       
1,044,861
 
    Other
       
4,343
       
2,238
       
2,641
 
          Total Operating Expenses
       
792,466
       
981,972
       
1,047,502
 
Operating Income
       
82,158
       
74,267
       
83,478
 
Other Income and (Income Deductions) - Net
       
2,569
       
3,128
       
1,206
 
Interest Charges:
                               
  Interest on long-term debt
       
24,583
       
24,583
       
19,851
 
  Other interest charges
       
2,269
       
5,770
       
10,363
 
          Total Interest Charges
       
26,852
       
30,353
       
30,214
 
Income Before Income Taxes
       
57,875
       
47,042
       
54,470
 
Income Tax Expense
       
18,150
       
13,859
       
15,264
 
Net Income
       
39,725
       
33,183
       
39,206
 
Dividends on Redeemable Preferred Stock
       
       
15
       
35
 
Earnings Applicable to Common Stock
     
$
39,725
     
$
33,168
     
$
39,171
 
                                 
                                 
                                 
See the accompanying Notes to Financial Statements .
                               






 
21
 
 


LACLEDE GAS COMPANY
                         
STATEMENTS OF COMPREHENSIVE INCOME
                         
                           
(Thousands)
     
 
                 
Years Ended September 30
     
2010
     
2009
     
2008
 
                                 
Net Income
     
$
39,725
     
$
33,183
     
$
39,206
 
                                 
Other Comprehensive Income (Loss) Before Tax:
                               
  Net gains (losses) on cash flow hedging derivative instruments:
                               
    Net hedging gains arising during the period
       
160
       
248
       
 
    Reclassification adjustment for gains included in net income
       
(264
)
     
(119
)
     
 
        Net unrealized (losses) gains on cash flow hedging derivative                                
          instruments
       
(104
)
     
129
       
 
  Defined benefit pension and other postretirement benefit plans:
                               
    Net actuarial loss arising during the period
       
(1,783
)
     
(1,728
)
     
(271
)
    Amortization of actuarial loss included in net periodic pension
      and other postretirement benefit cost
       
1,471
       
199
       
171
 
        Net defined benefit pension and other postretirement benefit plans
       
(312
)
     
(1,529
)
     
(100
)
  Other Comprehensive Loss, Before Tax
       
(416
)
     
(1,400
)
     
(100
)
  Income Tax Benefit Related to Items of Other Comprehensive Loss
       
(160
)
     
(540
)
     
(37
)
Other Comprehensive Loss, Net of Tax
       
(256
)
     
(860
)
     
(63
)
Comprehensive Income
     
$
39,469
     
$
32,323
     
$
39,143
 
                                 
                                 
                                 
See the accompanying Notes to Financial Statements .
                               






 
22
 
 


LACLEDE GAS COMPANY
                 
BALANCE SHEETS
                 
                   
(Thousands)
                 
September 30
     
2010
     
2009
 
                       
ASSETS
                     
Utility Plant
     
$
1,326,284
     
$
1,280,238
 
  Less – Accumulated depreciation and amortization
       
442,200
       
424,309
 
          Net Utility Plant
       
884,084
       
855,929
 
Other Property and Investments
       
45,864
       
40,549
 
                       
Current Assets:
                     
  Cash and cash equivalents
       
1,009
       
1,402
 
  Accounts receivable:
                     
    Utility
       
70,053
       
81,262
 
    Non-utility
       
848
       
1,634
 
    Associated companies
       
310
       
375
 
    Other
       
7,277
       
4,731
 
    Allowance for doubtful accounts
       
(10,176
)
     
(10,791
)
  Inventories:
                     
    Natural gas stored underground at LIFO cost
       
113,576
       
93,313
 
    Propane gas at FIFO cost
       
15,625
       
19,847
 
    Materials, supplies and merchandise at average cost
       
3,741
       
4,032
 
  Derivative instrument assets
       
9,288
       
12,369
 
  Unamortized purchased gas adjustments
       
23,718
       
 
  Prepayments and other
       
7,101
       
7,547
 
          Total Current Assets
       
242,370
       
215,721
 
                       
Deferred Charges:
                     
  Regulatory assets
       
479,462
       
482,999
 
  Other
       
6,672
       
5,089
 
          Total Deferred Charges
       
486,134
       
488,088
 
                       
Total Assets
     
$
1,658,452
     
$
1,600,287
 






 
23
 
 


LACLEDE GAS COMPANY
                 
BALANCE SHEETS (continued)
                 
                   
(Thousands)
                 
September 30
     
2010
     
2009
 
                       
CAPITALIZATION AND LIABILITIES
                     
Capitalization:
                     
  Common stock equity
     
$
411,259
     
$
402,585
 
   Long-term debt
       
364,298
       
389,240
 
          Total Capitalization
       
775,557
       
791,825
 
                       
Current Liabilities:
                     
  Notes payable
       
129,650
       
129,800
 
  Accounts payable
       
36,706
       
30,220
 
  Accounts payable – associated companies
       
652
       
 
  Advance customer billings
       
16,809
       
21,140
 
  Current portion of long-term debt
       
25,000
       
 
  Wages and compensation accrued
       
13,410
       
12,682
 
  Dividends payable
       
8,806
       
8,535
 
  Customer deposits
       
11,244
       
12,400
 
  Interest accrued
       
9,639
       
9,943
 
  Taxes accrued
       
8,677
       
12,414
 
  Unamortized purchased gas adjustments
       
       
3,130
 
  Deferred income taxes
       
4,248
       
912
 
  Other
       
11,385
       
10,737
 
          Total Current Liabilities
       
276,226
       
251,913
 
                       
Deferred Credits and Other Liabilities:
                     
  Deferred income taxes
       
292,766
       
256,381
 
  Unamortized investment tax credits
       
3,538
       
3,754
 
  Pension and postretirement benefit costs
       
207,607
       
202,681
 
  Asset retirement obligations
       
25,829
       
25,495
 
  Regulatory liabilities
       
47,365
       
44,225
 
  Other
       
29,564
       
24,013
 
          Total Deferred Credits and Other Liabilities
       
606,669
       
556,549
 
Commitments and Contingencies ( Note 12 )
                     
Total Capitalization and Liabilities
     
$
1,658,452
     
$
1,600,287
 
                       
                       
                       
See the accompanying Notes to Financial Statements .
                     






 
24
 
 


LACLEDE GAS COMPANY
                 
STATEMENTS OF CAPITALIZATION
                 
                   
(Thousands, Except for Shares and Per Share Amounts)
                 
September 30
     
2010
     
2009
 
                   
Common Stock Equity:
                 
  Common stock, par value $1 per share and Paid-in Capital:
                 
    Authorized – 2010 and 2009, 50,000,000 shares
                 
    Issued – 2010, 11,674 shares; and 2009, 11,634 shares
   
$
208,154
   
$
203,754
 
  Retained earnings
     
205,980
     
201,450
 
  Accumulated other comprehensive loss
     
(2,875
)
   
(2,619
)
          Total Common Stock Equity
     
411,259
     
402,585
 
                   
Long-Term Debt:
                 
  First Mortgage Bonds:
                 
    6-1/2% Series, due November 15, 2010
     
     
25,000
 
    6-1/2% Series, due October 15, 2012
     
25,000
     
25,000
 
    5-1/2% Series, due May 1, 2019
     
50,000
     
50,000
 
    7% Series, due June 1, 2029
     
25,000
     
25,000
 
    7.90% Series, due September 15, 2030
     
30,000
     
30,000
 
    6% Series, due May 1, 2034
     
100,000
     
100,000
 
    6.15% Series, due June 1, 2036
     
55,000
     
55,000
 
    6.35% Series, due October 15, 2038
     
80,000
     
80,000
 
          Total
     
365,000
     
390,000
 
  Unamortized discount, net of premium, on long-term debt
     
(702
)
   
(760
)
          Total Long-Term Debt
     
364,298
     
389,240
 
          Total Capitalization
   
$
775,557
   
$
791,825
 
                   
                   
                   
Long-term debt dollar amounts are exclusive of current portion.
         
                   
See the accompanying Notes to Financial Statements .
                 






 
25
 
 



LACLEDE GAS COMPANY
                     
STATEMENTS OF COMMON SHAREHOLDER’S EQUITY
             
                       
   
Common Stock Issued
 
Paid-in
 
Retained
 
Accum.
Other
Comp.
     
(Thousands, Except for Shares)
 
Shares
 
Amount
 
Capital
 
Earnings
 
Income
 
Total
 
                                     
BALANCE OCTOBER 1, 2007
 
10,307
 
$
10
 
$
151,500
 
$
195,728
 
$
(1,727
)
$
345,511
 
  Adoption of FIN 48, as codified in
    ASC Topic 740, as of October 1, 2007
 
   
   
   
447
   
   
447
 
  Net income
 
   
   
   
39,206
   
   
39,206
 
  Dividends declared:
                                   
    Common stock
 
   
   
   
(32,811
)
 
   
(32,811
)
    Preferred stock
 
   
   
   
(35
)
 
   
(35
)
  Stock-based compensation costs
 
   
   
2,036
   
   
   
2,036
 
  Tax benefit – stock compensation
 
   
   
534
   
   
   
534
 
  Other comprehensive loss, net of tax
 
   
   
   
   
(63
)
 
(63
)
  Issuance of common stock to Laclede Group
 
109
   
   
3,803
   
   
   
3,803
 
BALANCE SEPTEMBER 30, 2008
 
10,416
   
10
   
157,873
   
202,535
   
 (1,790
)
 
358,628
 
  Net income
 
   
   
   
33,183
   
   
33,183
 
  Dividends declared:
                                   
    Common stock
 
   
   
   
(34,108
)
 
   
(34,108
)
    Preferred stock
 
   
   
   
(15
)
 
   
(15
)
  Stock-based compensation costs
 
   
   
3,228
   
   
   
3,228
 
  Tax benefit – stock compensation
 
   
   
663
   
   
   
663
 
  Other comprehensive loss, net of tax
 
   
   
   
   
(860
)
 
(860
)
  Issuance of common stock to Laclede Group
 
1,218
   
2
   
41,978
   
   
   
41,980
 
  Adoption of SFAS No. 158, as codified in
    ASC Topic 715, net of tax
 
   
   
   
(145
)
 
31
   
(114
)
BALANCE SEPTEMBER 30, 2009
 
11,634
 
 
12
   
203,742
   
201,450
   
(2,619
)
 
402,585
 
  Net income
 
   
   
   
39,725
   
   
39,725
 
  Dividends declared:
                                   
    Common stock
 
   
   
   
(35,195
)
 
   
(35,195
)
  Stock-based compensation costs
 
   
   
2,956
   
   
   
2,956
 
  Tax benefit – stock compensation
 
   
   
6
   
   
   
6
 
  Other comprehensive loss, net of tax
 
   
   
   
   
(256
)
 
(256
)
  Issuance of common stock to Laclede Group
 
40
   
   
1,438
   
   
   
1,438
 
BALANCE SEPTEMBER 30, 2010
 
11,674
 
$
12
 
$
208,142
 
$
205,980
 
$
(2,875
)
$
411,259
 
                                     
                                     
                                     
See the accompanying Notes to Financial Statements .
                         






 
26
 
 


LACLEDE GAS COMPANY
             
STATEMENTS OF CASH FLOWS
             
               
(Thousands)
             
Years Ended September 30
 
2010
 
2009
 
2008
 
                     
Operating Activities:
                   
  Net Income
 
$
39,725
 
$
33,183
 
$
39,206
 
  Adjustments to reconcile net income to net cash provided by
      (used in) operating activities:
                   
    Depreciation and amortization
   
37,572
   
36,751
   
35,303
 
    Deferred income taxes and investment tax credits
   
31,454
   
21,404
   
6,635
 
    Other – net
   
1,812
   
1,557
   
3,553
 
    Changes in assets and liabilities:
                   
      Accounts receivable – net
   
8,899
   
18,502
   
4,776
 
      Unamortized purchased gas adjustments
   
(26,848
)
 
36,541
   
(20,598
)
      Deferred purchased gas costs
   
20,265
   
(45,234
)
 
(19,614
)
      Accounts payable
   
6,764
   
(27,631
)
 
8,024
 
      Advance customer billings – net
   
(4,331
)
 
(4,408
)
 
108
 
      Taxes accrued
   
(3,860
)
 
1,938
   
(6,126
)
      Natural gas stored underground
   
(20,263
)
 
102,795
   
(67,996
)
      Other assets and liabilities
   
1,391
   
41,044
   
(28,860
)
          Net cash provided by (used in) operating activities
   
92,580
   
216,442
   
(45,589
)
                     
Investing Activities:
                   
  Capital expenditures
   
(56,234
)
 
(51,384
)
 
(55,304
)
  Other investments
   
(3,535
)
 
(261
)
 
(1,119
)
          Net cash used in investing activities
   
(59,769
)
 
(51,645
)
 
(56,423
)
                     
Financing Activities:
                   
  Issuance of first mortgage bonds
   
   
   
80,000
 
  Maturity of first mortgage bonds
   
   
   
(40,000
)
  (Repayment) issuance of short-term debt - net
   
(150
)
 
(175,316
)
 
93,716
 
  Changes in book overdrafts
   
358
   
652
   
 
  Dividends paid
   
(34,925
)
 
(33,837
)
 
(32,497
)
  Issuance of common stock to Laclede Group
   
1,438
   
41,980
   
3,803
 
  Excess tax benefits from stock-based compensation
   
131
   
706
   
387
 
  Preferred stock redeemed/reacquired
   
   
(627
)
 
(160
)
  Other
   
(56
)
 
(116
)
 
(2,528
)
          Net cash (used in) provided by financing activities
   
(33,204
)
 
(166,558
)
 
102,721
 
                     
Net (Decrease) Increase in Cash and Cash Equivalents
   
(393
)
 
(1,761
)
 
709
 
Cash and Cash Equivalents at Beginning of Year
   
1,402
   
3,163
   
2,454
 
Cash and Cash Equivalents at End of Year
 
$
1,009
 
$
1,402
 
$
3,163
 
                     
                     
Supplemental Disclosure of Cash Paid (Refunded) During the Year for:
                   
  Interest
 
$
26,393
 
$
29,873
 
$
30,992
 
  Income taxes
   
(15,163
)
 
(13,088
)
 
21,178
 
                     
                     
                     
See the accompanying Notes to Financial Statements .
                   






 
27
 
 

LACLEDE GAS COMPANY
NOTES TO FINANCIAL STATEMENTS
 
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

BASIS OF PRESENTATION - The financial statements include the accounts of Laclede Gas Company (Laclede Gas or the Utility).
In compliance with generally accepted accounting principles in the United States of America (GAAP), transactions between Laclede Gas and its affiliates as well as intercompany balances on Laclede Gas’ Balance Sheets have not been eliminated from the Laclede Gas financial statements.
Laclede Gas is a wholly-owned subsidiary of The Laclede Group, Inc. (Laclede Group or the Company). Laclede Gas provides administrative and general support to affiliates. All such costs, which are not material, are billed to the appropriate affiliates. Also, Laclede Group may charge or reimburse Laclede Gas for certain tax-related amounts. Unpaid balances relating to these activities are reflected in the Laclede Gas Balance Sheets as Accounts receivable-Associated companies or as Accounts payable-associated companies. Additionally, Laclede Gas may, on occasion, borrow funds from affiliated companies. Unpaid balances relating to these arrangements, if any, are reflected in Notes payable-associated companies.
NATURE OF OPERATIONS - Laclede Gas is a public utility engaged in the retail distribution of natural gas. Laclede Gas serves an area in eastern Missouri, with a population of approximately 2.1 million, including the City of St. Louis and parts of ten counties in eastern Missouri. As an adjunct to its gas distribution business, Laclede Gas operates an underground natural gas storage field.
USE OF ESTIMATES - The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates.
SYSTEM OF ACCOUNTS - The accounts of Laclede Gas are maintained in accordance with the Uniform System of Accounts prescribed by the Missouri Public Service Commission (MoPSC or Commission), which system substantially conforms to that prescribed by the Federal Energy Regulatory Commission (FERC).
UTILITY PLANT, DEPRECIATION AND AMORTIZATION - Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses.
Utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal years 2010, 2009, and 2008, annual depreciation and amortization expense averaged 3.1% of the original cost of depreciable and amortizable property.
The Utility’s capital expenditures were $56.2 million, $51.4 million, and $55.3 million for fiscal years 2010, 2009, and 2008, respectively. Additionally, the Utility had recorded accruals for capital expenditures totaling $2.2 million at September 30, 2010, $1.7 million at September 30, 2009, and $2.3 million at September 30, 2008. Accrued capital expenditures are excluded from the Statements of Cash Flows.
ASSET RETIREMENT OBLIGATIONS - Laclede Gas records legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Utility has recorded asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of Laclede Gas’ distribution system and general plant. As authorized by the MoPSC, Laclede Gas accrues future asset removal costs associated with its property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities. When Laclede Gas retires depreciable utility plant and equipment, it charges the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities. In the rate setting process, the regulatory liability is deducted from the rate base upon which the Utility has the opportunity to earn its allowed rate of return.

 
28
 
 

The following table presents a reconciliation of the beginning and ending balances of Asset retirement obligations at September 30 as reported in the Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Asset retirement obligations, beginning of year
 
$
25,495
 
$
26,817
 
 
Liabilities incurred during the period
   
208
   
415
 
 
Liabilities settled during the period
   
(904
)
 
(2,767
)
 
Accretion
   
1,526
   
1,566
 
 
Revisions in estimated cash flows
   
(496
)
 
(536
)
 
Asset retirement obligations, end of year
 
$
25,829
 
$
25,495
 

REGULATED OPERATIONS - Laclede Gas accounts for its regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities).
The following regulatory assets and regulatory liabilities were reflected in the Balance Sheets as of September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Regulatory Assets:
             
 
  Future income taxes due from customers
 
$
100,624
 
$
91,782
 
 
  Pension and postretirement benefit costs
   
288,077
   
280,939
 
 
  Unamortized purchased gas adjustments
   
23,718
   
 
 
  Purchased gas costs
   
74,040
   
94,305
 
 
  Compensated absences
   
7,885
   
7,425
 
 
  Cold weather rule
   
4,275
   
5,264
 
 
  Other
   
4,561
   
3,284
 
 
     Total Regulatory Assets
 
$
503,180
 
$
482,999
 
 
Regulatory Liabilities:
             
 
  Unamortized purchased gas adjustments
 
$
 
$
3,130
 
 
  Unamortized investment tax credits
   
3,538
   
3,754
 
 
  Accrued cost of removal
   
45,441
   
41,590
 
 
  Other
   
1,924
   
2,635
 
 
     Total Regulatory Liabilities
 
$
50,903
 
$
51,109
 

As authorized by the MoPSC, Laclede Gas discontinued deferring certain costs for future recovery, as expenses associated with those specific areas were included in approved rates effective December 27, 1999. Previously deferred costs of $10.5 million are being recovered and amortized on a straight-line basis over a fifteen-year period, without return on investment. Amortization of these costs totaled $7.6 million from December 27, 1999 through September 30, 2010.
Certain previously deferred costs, totaling $2.6 million, are being recovered and amortized on a straight-line basis over a period of approximately two years, without return on investment. Amortization of these costs totaled $0.1 million from September 1, 2010 through September 30, 2010.
NATURAL GAS STORED UNDERGROUND - Inventory of Utility natural gas in storage is priced on a last-in, first-out (LIFO) basis. The replacement cost of natural gas stored underground for current use at September 30, 2010 and September 30, 2009 was less than the LIFO cost by $26.5 million and $33.1 million, respectively. The inventory carrying value is not adjusted to the lower of cost or market prices because, pursuant to the Laclede Gas Purchased Gas Adjustment (PGA) Clause, actual gas costs are recovered in customer rates.

 
29
 
 

REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its utility operating revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at September 30, 2010 and 2009, for the Utility, were $11.3 million and $12.7 million, respectively.
PURCHASED GAS ADJUSTMENTS AND DEFERRED ACCOUNT   As authorized by the MoPSC, the PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, the Utility is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism. Certain other provisions of the PGA Clause are included below:
 
The tariffs allow the Utility flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months.
 
The Utility is authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The Utility is also authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits.
 
The MoPSC approved a plan applicable to the Utility’s gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level of gas cost. This gas supply cost management program allows the Utility to retain 10% of cost savings, up to a maximum of $3.0 million annually. The Utility recorded $0.6 million in pre-tax income under the plan in fiscal year 2008. Laclede Gas did not record any income under the plan during fiscal years 2009 and 2010. Income recorded under the plan is included in Utility Operating Revenues on the Statements of Income.
Pursuant to the provisions of the PGA Clause, the difference between actual costs incurred and costs recovered through the application of the PGA (including costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs), amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Utility’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries are reflected as a deferred charge or credit until fiscal year end. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA Clause also provides for the treatment of income from off-system sales and capacity release revenues, as described below.
OFF-SYSTEM SALES - Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The customer share of such income is determined in accordance with the table below. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November.

 
Pre-tax Income
Customer Share
 
Company Share
 
First $2 million
85%
 
15%
 
Next $2 million
80%
 
20%
 
Next $2 million
75%
 
25%
 
Amounts exceeding $6 million
70%
 
30%


 
30
 
 

INCOME TAXES - Laclede Gas has elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. GAAP permits the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. Laclede Gas records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities in the financial statements, and the related tax basis. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or regulatory liability accounts.
Laclede Gas’ investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
Laclede Group files a consolidated federal income tax return and allocates income taxes to Laclede Gas and its other subsidiaries as if each entity were a separate taxpayer.
CASH AND CASH EQUIVALENTS - All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Utility’s controlled disbursement bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the Balance Sheets. Changes in book overdrafts between periods are reflected as Financing Activities in the Statements of Cash Flows.
GROSS RECEIPTS AND SALES TAXES - Gross receipts taxes associated with Laclede Gas’ natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Income. Amounts recorded in Utility Operating Revenues were $44.1 million, $51.6 million, and $52.5 million for fiscal years 2010, 2009, and 2008, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
Sales taxes imposed on applicable Utility sales are billed to customers. These amounts are not recorded in the Statements of Income, but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the Balance Sheets.
ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. The Utility’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses, as approved by the MoPSC.
GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES - Laclede Gas self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting.
FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below:
Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities.
Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data.
Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability.
Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Additional information about fair value measurements is provided in Note 2 , Pension Plans and Other Postretirement Benefits, Note 6 , Fair Value of Financial Instruments, and Note 7 , Fair Value Measurements.

 
31
 
 

STOCK-BASED COMPENSATION - Officers and employees of Laclede Gas, as determined by the Compensation Committee of Laclede Group’s Board of Directors, are eligible to be selected for awards under the Laclede Group 2006 Equity Incentive Plan. Grants of awards may be earned by achieving performance objectives and/or other criteria as determined by the Compensation Committee. Awards may include restricted stock, restricted stock units, qualified and non-qualified stock options, stock appreciation rights, and performance shares payable in stock, cash, or a combination of both. The 2006 Plan generally provides a minimum vesting period of at least three years for each type of award. For Laclede Group’s non-employee directors, shares are awarded under the Restricted Stock Plan for Non-Employee Directors. These awards vest depending upon the participant’s age upon entering the plan and years of service as a director. Shares of Laclede Gas common stock, which are 100% owned by Laclede Group, are not transacted under the plans. Laclede Group accounts for awards under these plans in accordance with GAAP, and allocates applicable compensation costs to its subsidiaries. For awards made to its employees, the Utility records its allocation of compensation cost from Laclede Group with a corresponding increase to additional paid-in capital.
The amounts of compensation cost allocated to the Utility for share-based compensation arrangements are presented below:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Total equity compensation cost
 
$
3,270
 
$
3,483
 
$
2,263
 
 
Compensation cost capitalized
   
(798
)
 
(815
)
 
(578
)
 
Compensation cost recognized in net income
   
2,472
   
2,668
   
1,685
 
 
Income tax benefit recognized in net income
   
(953
)
 
(1,029
)
 
(650
)
 
Compensation cost recognized in net income, net of income tax
 
$
1,519
 
$
1,639
 
$
1,035
 

As of September 30, 2010, there was $2.9 million in unrecognized compensation cost related to nonvested share-based compensation arrangements that is expected to be allocated to the Utility over a weighted average period of 2.3 years.
NEW ACCOUNTING STANDARDS – In September 2006, the FASB issued Statement of Financial Accounting Standards (SFAS) No. 157, “Fair Value Measurements,” as codified in ASC Topic 820, “Fair Value Measurements and Disclosures.” This Statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. The Statement applies to fair value measurements required under other accounting guidance that require or permit fair value measurements. Accordingly, this Statement does not require any new fair value measurements. The guidance in this Statement does not apply to Laclede Group’s stock-based compensation plans accounted for in accordance with ASC Topic 718, “Compensation-Stock Compensation.” The Utility partially adopted SFAS No. 157 on October 1, 2008 and elected the one-year deferral allowed by FASB Staff Position (FSP) No. FAS 157-2, which permits delayed application of this Statement for nonfinancial assets and nonfinancial liabilities, except for those recognized or disclosed at fair value on a recurring basis. The partial adoption of this Statement had no impact on the Utility’s financial position or results of operations. For disclosures required pursuant to ASC Topic 820, see Note 7 , Fair Value Measurements. The Utility adopted SFAS No. 157 for certain nonfinancial assets and nonfinancial liabilities as of October 1, 2009. Such adoption had no impact on the Utility’s financial position or results of operations.
In December 2008, the FASB issued FSP No. FAS 132(R)-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets,” as codified in ASC Topic 715, “Compensation–Retirement Benefits.” This FSP provides guidance on an employer’s disclosures about plan assets of a defined benefit pension or other postretirement plan. The FSP requires disclosure of additional information regarding investment policies and strategies, the classes of plan assets, fair value measurements of plan assets, and significant concentrations of risk. The enhanced disclosures, which the Utility adopted this fiscal year, are presented in Note 2 , Pension Plans and Other Postretirement Benefits. The FSP does not require disclosures for comparative periods prior to adoption.
In August 2009, the FASB issued Accounting Standards Update (ASU) No. 2009-05, “Measuring Liabilities at Fair Value,” to update ASC Topic 820. The guidance provides clarification on measuring liabilities at fair value when a quoted price in an active market is not available. In such circumstances, the ASU specifies that a valuation technique should be applied that uses either the quote of the identical liability when traded as an asset, the quoted prices for similar liabilities or similar liabilities when traded as assets, or another valuation technique consistent with existing fair value measurement guidance. Laclede Gas’ adoption of this ASU in the first quarter of fiscal year 2010 had no impact on the Utility’s financial position or results of operations.

 
32
 
 

In January 2010, the FASB issued ASU No. 2010-06, “Improving Disclosures about Fair Value Measurements,” which amends ASC Topic 820. The ASU requires separate disclosure of significant transfers in and out of level 1 and level 2 fair value measurements. It also requires disclosure of the policy for when transfers are recognized. Additionally, the ASU clarifies certain areas of the guidance, including the level of disaggregation required in fair value measurement disclosures. While the adoption of these updates during the quarter ended March 31, 2010 had no effect on the financial statements, the Utility modified its disclosures in Note 7 , Fair Value Measurements, accordingly. The ASU also requires that certain activity in the level 3 fair value measurements reconciliation be presented on a gross basis (instead of net). This change is effective for the Utility’s disclosures in the first quarter of fiscal year 2012.
In February 2010, the FASB issued ASU No. 2010-09, “Amendments to Certain Recognition and Disclosure Requirements.” The ASU amends ASC Topic 855, “Subsequent Events.” Subsequent events or transactions occur after the balance sheet date, but prior to the financial statements being issued, and are required to be assessed by management for possible financial statement recognition and/or disclosure. For entities that are Securities and Exchange Commission (SEC) filers, this ASU removes the requirement to disclose the date through which subsequent events have been evaluated to alleviate potential conflicts with SEC guidance. Laclede Gas adopted this ASU during the quarter ended March 31, 2010. While the adoption of the ASU did not impact the financial statements or management’s process for assessing subsequent events, the Utility did modify its disclosures accordingly.


PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

In September 2009, the Utility adopted the measurement date provisions in ASC Topic 715. ASC Topic 715 requires that plan assets and benefit obligations be measured as of the date of the employer’s fiscal year-end statement of financial position. The Utility previously used a June 30 valuation date for its benefit plans. To change to a September 30 measurement date, the Utility elected to use the 15-month alternative transition approach, wherein benefit costs for the period between June 30, 2008 and September 30, 2009 are allocated proportionately between a retained earnings adjustment and periodic benefit cost for the period. As a result of changing the measurement date, excluding the effect of income taxes, the Utility recorded a one-time cumulative effect adjustment to reduce retained earnings by $0.2 million, increase accumulated other comprehensive income by $50,000, and, pursuant to ASC Topic 980, increase net regulatory assets by $5.1 million. In conjunction with the adoption, the Utility recorded increases to benefit liabilities totaling $5.3 million.

Pension Plans

Laclede Gas has non-contributory, defined benefit, trusteed forms of pension plans covering substantially all employees. Effective January 1, 2009, the Utility modified the calculation of future benefits under Laclede Gas’ primary plan from a years of service and final average compensation formula to a cash balance formula, which accrues benefits based on a percentage of compensation and provides interest credits on the balance. Benefits attributable to plan participation prior to January 1, 2009 will be based on final average compensation at the date of termination of employment and years of service earned at January 1, 2009. Effective January 1, 2010, the Utility modified the calculation of future benefits under its Missouri Natural Gas division plan from a career average formula to a cash balance formula, which accrues benefits based on a percentage of compensation, provides interest credits on the balance, and provides certain transition credits. Benefits attributable to plan participation prior to January 1, 2010 will be based on career average compensation earned as a participant prior to January 1, 2010. Plan assets consist primarily of corporate and U.S. government obligations and equity market exposure achieved through derivative instruments.

 
33
 
 

Pension costs in 2010, 2009, and 2008 amounted to $7.4, $6.2, and $6.1 million, respectively, including amounts charged to construction.
The net periodic pension costs include the following components:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Service cost – benefits earned during the period
 
$
8,841
 
$
8,936
 
$
12,970
 
 
Interest cost on projected benefit obligation
   
19,729
   
20,957
   
18,680
 
 
Expected return on plan assets
   
(20,256
)
 
(20,938
)
 
(20,650
)
 
Amortization of prior service cost
   
756
   
1,035
   
1,088
 
 
Amortization of actuarial loss
   
8,107
   
3,096
   
3,165
 
 
Sub-total
   
17,177
   
13,086
   
15,253
 
 
Loss on lump-sum settlement
   
1,078
   
   
 
 
Regulatory adjustment
   
(10,862
)
 
(6,890
)
 
(9,120
)
 
Net pension cost
 
$
7,393
 
$
6,196
 
$
6,133
 

Other changes in plan assets and pension benefit obligations recognized in other comprehensive income include the following:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Current year actuarial loss
 
$
3,822
 
$
84,187
 
$
18,050
 
 
Amortization of actuarial loss
   
(9,185
)
 
(3,096
)
 
(3,165
)
 
Current year prior service credit
   
(2,949
)
 
   
 
 
Amortization of prior service cost
   
(756
)
 
(1,035
)
 
(1,088
)
 
Sub-total
   
(9,068
)
 
80,056
   
13,797
 
 
Regulatory adjustment
   
9,380
   
(78,527
)
 
(13,697
)
 
Total recognized in other comprehensive income
 
$
312
 
$
1,529
 
$
100
 

Pursuant to the provisions of the Laclede Gas pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a MoPSC Order, lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs. Lump-sum payments recognized as settlements during fiscal 2010 were $2.3 million. No lump-sum payments were recognized as settlements during fiscal years 2009 and 2008.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s qualified pension plans is based on an allowance of $4.8 million annually. The difference between this amount and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Income and Statements of Comprehensive Income is deferred as a regulatory asset or regulatory liability.

 
34
 
 

The following table sets forth the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Benefit obligation at beginning of year
 
$
378,032
 
$
308,736
 
 
Service cost
   
8,841
   
12,371
 
 
Interest cost
   
19,729
   
26,150
 
 
Plan amendments
   
(2,949
)
 
 
 
Actuarial loss
   
28,437
   
54,769
 
 
Settlement loss
   
778
   
 
 
Gross benefits paid **
   
(34,508
)
 
(23,994
)
                 
 
Benefit obligation at end of year
 
$
398,360
 
$
378,032
 
                 
 
Accumulated benefit obligation at end of year
 
$
338,042
 
$
305,255
 
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.
     
 
**
Includes $(2,293) lump-sum payments recognized as settlements in fiscal year 2010. No lump-sum payments were recognized as settlements in fiscal year 2009.

The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Fair value of plan assets at beginning of year
 
$
223,688
 
$
248,346
 
 
Actual return on plan assets
   
45,648
   
(3,245
)
 
Employer contributions
   
6,094
   
2,581
 
 
Gross benefits paid **
   
(34,508
)
 
(23,994
)
 
Fair value of plan assets at end of year
 
$
240,922
 
$
223,688
 
                 
 
Funded status of plans, end of year
 
$
(157,438
)
$
(154,344
)
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.
     
 
**
Includes $(2,293) lump-sum payments recognized as settlements in fiscal year 2010. No lump-sum payments were recognized as settlements in fiscal year 2009.


 
35
 
 

The following table sets forth the amounts recognized in the Balance Sheets at September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Current liabilities
 
$
(2,420
)
$
(1,920
)
 
Noncurrent liabilities
   
(155,018
)
 
(152,424
)
 
  Total
 
$
(157,438
)
$
(154,344
)
                 
 
Pre-tax amounts recognized in accumulated other comprehensive income
             
 
  not yet recognized as components of net periodic pension cost consist of:
             
 
Net actuarial loss
 
$
157,327
 
$
162,689
 
 
Prior service costs
   
6,245
   
9,950
 
 
  Sub-total
   
163,572
   
172,639
 
 
Adjustments for amounts included in Regulatory Assets
   
(158,867
)
 
(168,246
)
 
  Total
 
$
4,705
 
$
4,393
 

At September 30, 2010, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic pension cost during fiscal year 2011:

 
(Thousands)
     
           
 
Amortization of net actuarial loss
 
$
10,228
 
 
Amortization of prior service cost
   
642
 
 
  Sub-total
   
10,870
 
 
Regulatory adjustment
   
(10,444
)
 
  Total
 
$
426
 

The assumptions used to calculate net periodic pension costs are as follows:

   
2010
 
2009
 
2008
             
 
Weighted average discount rate
5.25%
 
6.60%
 
6.25%
 
Weighted average rate of future compensation increase
3.25%
 
3.75%
 
3.50%
 
Expected long-term rate of return on plan assets
8.25%
 
8.25%
 
8.25%

The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually.
The assumptions used to calculate the benefit obligations are as follows:

   
2010
 
2009
         
 
Weighted average discount rate
4.75%
 
5.25%
 
Weighted average rate of future compensation increase
3.00%
 
3.25%


 
36
 
 

Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Projected benefit obligation
 
$
398,360
 
$
378,032
 
 
Fair value of plan assets
   
240,922
   
223,688
 
                 
 
Accumulated benefit obligation
   
338,042
   
305,255
 
 
Fair value of plan assets
   
240,922
   
223,688
 

Following are the targeted and actual plan assets by category:

   
2011
 
2010
 
2009
   
Target
 
Actual
 
Actual
             
 
Equity Strategy
50%
 
49%
 
50%
 
Debt Securities
50%
 
51%
 
50%
 
  Total
100%
 
100%
 
100%

Laclede Gas’ investment policy is designed to maximize, to the extent possible, the funded status of the plan over time, and minimize volatility of funding and costs. The policy seeks to maximize investment returns consistent with these objectives and Laclede Gas’ tolerance for risk. The duration of plan liabilities and the impact of potential changes in asset values on the funded status are fundamental considerations in the selection of plan assets. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with the policy. The policy seeks to avoid significant concentrations of risk by investing in a diversified portfolio of assets. Investments in corporate, U. S. government and agencies, and, to a lesser extent, international debt securities seek to provide duration matching with plan liabilities, and typically have investment grade ratings and reflect allocations across various entities and industries. The investment policy permits the use of derivative instruments, which may be used to achieve the desired market exposure of an index, adjust portfolio duration, or rebalance the total portfolio to the target asset allocation. The Equity Strategy utilizes a combination of derivative instruments and debt securities to achieve both diversified equity market exposure while generating returns from the fixed-income investments and providing further duration matching with the liabilities. Performance and compliance with the guidelines is regularly monitored. The policy calls for increased allocations to debt securities as the funded status improves.
Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:

 
 
(Millions)
 
 
Pensions from
Qualified Trust
 
Pensions from
Laclede Gas
Funds
 
                         
 
2011
   
$
22.0
     
$
2.4
   
 
2012
     
20.8
       
1.5
   
 
2013
     
23.8
       
1.0
   
 
2014
     
25.9
       
0.8
   
 
2015
     
30.1
       
0.7
   
 
2016 – 2020
     
188.2
       
3.7
   

The funding policy of Laclede Gas is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Contributions to the pension plans in fiscal year 2011 are anticipated to be $10.6 million into the qualified trusts, and $2.4 million into the non-qualified plans.


 
37
 
 

Postretirement Benefits

Laclede Gas provides certain life insurance benefits at retirement. Medical insurance is available after early retirement until age 65. The transition obligation not yet includible in postretirement benefit cost is being amortized over 20 years. Postretirement benefit costs in 2010, 2009, and 2008 amounted to $7.6 million per year, including amounts charged to construction.
Net periodic postretirement benefit costs consisted of the following components:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Service cost – benefits earned during the period
 
$
6,442
 
$
5,132
 
$
4,560
 
 
Interest cost on accumulated postretirement
                   
 
  benefit obligation
   
4,515
   
4,679
   
3,909
 
 
Expected return on plan assets
   
(3,032
)
 
(2,376
)
 
(2,039
)
 
Amortization of transition obligation
   
136
   
136
   
136
 
 
Amortization of prior service credit
   
(2,328
)
 
(2,328
)
 
(2,328
)
 
Amortization of actuarial loss
   
3,980
   
3,509
   
2,985
 
 
Sub-total
   
9,713
   
8,752
   
7,223
 
 
Regulatory adjustment
   
(2,071
)
 
(1,110
)
 
419
 
 
Net postretirement benefit cost
 
$
7,642
 
$
7,642
 
$
7,642
 

Other changes in plan assets and postretirement benefit obligations recognized in other comprehensive income include the following:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Current year actuarial loss
 
$
6,713
 
$
11,137
 
$
9,772
 
 
Amortization of actuarial loss
   
(3,980
)
 
(3,509
)
 
(2,985
)
 
Amortization of prior service credit
   
2,328
   
2,328
   
2,328
 
 
Amortization of transition obligation
   
(136
)
 
(136
)
 
(136
)
 
Sub-total
   
4,925
   
9,820
   
8,979
 
 
Regulatory adjustment
   
(4,925
)
 
(9,820
)
 
(8,979
)
 
Total recognized in other comprehensive income
 
$
 
$
 
$
 

Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s postretirement benefit plans is based on an allowance of $7.6 million annually. The difference between this amount and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Income and Statements of Comprehensive Income is deferred as a regulatory asset or regulatory liability.

 
38
 
 

The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Benefit obligation at beginning of year
 
$
83,631
 
$
69,714
 
 
Service cost
   
6,442
   
6,415
 
 
Interest cost
   
4,515
   
5,848
 
 
Actuarial loss
   
7,564
   
7,298
 
 
Gross benefits paid
   
(4,173
)
 
(5,644
)
 
Benefit obligation at end of year
 
$
97,979
 
$
83,631
 
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.

The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30:

 
(Thousands)
 
2010
 
2009 *
 
                 
 
Fair value of plan assets at beginning of year
 
$
33,561
 
$
26,082
 
 
Actual return on plan assets
   
3,883
   
(869
)
 
Employer contributions
   
11,819
   
13,992
 
 
Gross benefits paid
   
(4,173
)
 
(5,644
)
 
Fair value of plan assets at end of year
 
$
45,090
 
$
33,561
 
                 
 
Funded status of plans, end of year
 
$
(52,889
)
$
(50,070
)
 
 
*
Due to the change in measurement date, fiscal year 2009 amounts reflect 15 months of activity from July 1, 2008 to September 30, 2009.

The following table sets forth the amounts recognized in the Balance Sheets at September 30:

 
(Thousands)
 
2010
 
2009
 
                 
 
Current liabilities
 
$
(300
)
$
(280
)
 
Noncurrent liabilities
   
(52,589
)
 
(49,790
)
 
  Total
 
$
(52,889
)
$
(50,070
)
                 
 
Pre-tax amounts recognized in accumulated other comprehensive income
             
 
  not yet recognized as components of net periodic postretirement cost
             
 
    consist of:
             
 
Net actuarial loss
 
$
49,442
 
$
46,709
 
 
Prior service credit
   
(4,423
)
 
(6,751
)
 
Transition obligation
   
365
   
501
 
 
  Sub-total
   
45,384
   
40,459
 
 
Adjustments for amounts included in Regulatory Assets
   
(45,384
)
 
(40,459
)
 
  Total
 
$
 
$
 


 
39
 
 

At September 30, 2010, the following pre-tax amounts are expected to be amortized from accumulated other comprehensive income into net periodic postretirement benefit cost during fiscal year 2011:

 
  (Thousands)
       
 
  Amortization of net actuarial loss
 
$
4,443
 
 
  Amortization of prior service credit
   
(2,328
)
 
  Amortization of transition obligation
   
136
 
 
    Sub-total
   
2,251
 
 
  Regulatory adjustment
   
(2,251
)
 
    Total
 
$
 

The assumptions used to calculate net periodic postretirement benefit costs are as follows:

   
2010
 
2009
 
2008
             
 
Weighted average discount rate
5.15%
 
6.35%
 
6.25%
 
Weighted average rate of future compensation increase
3.25%
 
3.75%
 
3.50%
 
Expected long-term rate of return on plan assets
8.25%
 
8.25%
 
8.25%

The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The expected return is a long-term assumption that generally does not change annually.
The assumptions used to calculate the accumulated postretirement benefit obligations are as follows:

   
2010
 
2009
         
 
Weighted average discount rate
4.70%
 
5.15%
 
Weighted average rate of future compensation increase
3.00%
 
3.25%

The assumed medical cost trend rates at September 30 are as follows:

   
2010
 
2009
 
Medical cost trend assumed for next year
8.00%
 
8.00%
 
Rate to which the medical cost trend rate is assumed to decline
     
 
    (the ultimate medical cost trend rate)
5.00%
 
5.00%
 
Year that the rate reaches the ultimate trend
2017
 
2016

The following table presents the effect of an assumed 1% change in the assumed medical cost trend rate:

 
(Thousands)
 
1% Increase
 
1% Decrease
 
                     
 
Effect on net periodic postretirement benefit cost
   
$
1,270
   
$
(1,130
)
 
Effect on accumulated postretirement benefit obligation
     
5,850
     
(5,300
)

Following are the targeted and actual plan assets by category:

   
2011
 
2010
 
2009
   
Target
 
Actual
 
Actual
             
 
Equity Securities
60%
 
59%
 
58%
 
Debt Securities
40%
 
41%
 
42%
 
  Total
100%
 
100%
 
100%


 
40
 
 

Missouri state law provides for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. Laclede Gas established Voluntary Employees’ Beneficiary Association and Rabbi trusts as its external funding mechanisms. Laclede Gas’ investment policy seeks to maximize investment returns consistent with Laclede Gas’ tolerance for risk. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with policy. Performance and compliance with the guidelines is regularly monitored. Laclede Gas’ current investment policy targets an asset allocation of 60% to equity securities and 40% to debt securities, excluding cash held in short-term debt securities for the purpose of making benefit payments. Laclede Gas currently invests in a mutual fund which is rebalanced on an ongoing basis to the target allocation. The mutual fund is diversified across U.S. stock and bond markets.
Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter:

 
 
(Millions)
 
Benefits Paid
from
Qualified Trust
  
Benefits Paid
from Laclede Gas
Funds
 
                         
 
2011
   
$
5.0
     
$
0.3
   
 
2012
     
5.3
       
0.3
   
 
2013
     
5.5
       
0.3
   
 
2014
     
5.9
       
0.3
   
 
2015
     
6.4
       
0.3
   
 
2016 – 2020
     
45.7
       
1.9
   

Laclede Gas’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Contributions to the postretirement plans in fiscal year 2011 are anticipated to be $13.3 million to the qualified trusts, and $0.3 million paid directly to participants from Laclede Gas funds.

Other Plans

Laclede Gas sponsors 401(k) plans that cover substantially all employees. The plans allow employees to contribute a portion of their base pay in accordance with specific guidelines. Laclede Gas provides a match of such contributions within specific limits. The cost of the defined contribution plans of Laclede Gas amounted to $3.6 million, $3.5 million, and $3.1 million for fiscal years 2010, 2009, and 2008, respectively.

Fair Value Measurements of Pension and Other Postretirement Plan Assets

The table below categorizes the fair value measurements of Laclede Gas’ pension plan assets:

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Total
 
 
As of September 30, 2010
                         
 
Cash and cash equivalents
 
$
1,406
 
$
 
$
 
$
1,406
 
 
Debt Securities
                         
 
  U.S. bond mutual funds
   
33,082
   
   
   
33,082
 
 
  U.S. government
   
   
90,993
   
   
90,993
 
 
  U.S. corporate
   
   
90,476
   
   
90,476
 
 
  U.S. municipal
   
   
6,241
   
   
6,241
 
 
  International
   
   
18,676
   
   
18,676
 
 
Derivative instruments (a)
   
   
9
   
   
9
 
 
Other
   
   
39
   
   
39
 
 
          Total
 
$
34,488
 
$
206,434
 
$
 
$
240,922
 
 
 
(a)
Derivative assets of $10,399 net of cash margin payable of $10,390.


 
41
 
 


The table below categorizes the fair value measurements of Laclede Gas’ postretirement plan assets:

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Total
 
 
As of September 30, 2010
                         
 
Cash and cash equivalents
 
$
1,021
 
$
 
$
 
$
1,021
 
 
U.S. stock/bond mutual fund
   
44,069
   
   
   
44,069
 
 
          Total
 
$
45,090
 
$
 
$
 
$
45,090
 

Cash and cash equivalents include money market mutual funds valued based on quoted market prices. Fair values of derivative instruments are calculated by investment managers who use valuation models that incorporate observable market inputs. Debt securities are valued based on broker/dealer quotations or by using observable market inputs. The stock and bond mutual funds are valued at the quoted market price of the identical securities.


STOCKHOLDER’S EQUITY

Total shares of common stock outstanding were 11,674 and 11,634 at September 30, 2010 and 2009, respectively.
Common stock and paid-in capital increased $4.4 million and $45.9 million in 2010 and 2009, respectively. These increases were primarily due to the issuance of common stock to Laclede Group and stock-based compensation costs allocated to Laclede Gas from Laclede Group in both periods.
Laclede Gas periodically sold shares of its stock to Laclede Group at prices per share equal to book value on the last day of the quarter preceding each sale. Laclede Gas sold 40 shares to Laclede Group for $1.4 million during fiscal 2010 and 1,218 shares to Laclede Group for $42.0 million during fiscal 2009, which also represents the total number of shares issued in each year. The proceeds from all the sales were used to reduce short-term borrowings. Exemption from registration for all of the sales was claimed under Section 4(2) of the Securities Act of 1933.
Substantially all of the utility plant of Laclede Gas is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock. These provisions are applicable regardless of whether the stock is publicly held or, as has been the case since the formation of Laclede Group, held solely by the Utility’s parent company. Under the most restrictive of these provisions, no cash dividend may be declared or paid if, after the dividend, the aggregate net amount spent for all dividends after September 30, 1953, would exceed a maximum amount determined by a formula set out in the mortgage. Under that formula, the maximum amount is the sum of $8 million plus earnings applicable to common stock (adjusted for stock repurchases and issuances) for the period from September 30, 1953, to the last day of the quarter before the declaration or payment date for the dividends. As of September 30, 2010 and 2009, the amount under the mortgage’s formula that was available to pay dividends was $280 million and $274 million, respectively. Thus, all of the Utility’s retained earnings were free from such restrictions as of those dates.
Laclede Gas has on file with the SEC an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, all of which remains available to Laclede Gas at this time. The Utility has authority from the MoPSC until June 30, 2013 to issue up to $518 million in debt securities and preferred stock, including on a private placement basis, as well as to enter into capital leases, issue common stock and receive paid-in capital, of which $517.6 million remained under this authorization as of September 30, 2010. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions.

 
42
 
 

The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the Balance Sheets at September 30 were as follows:

 
(Thousands)
 
 
Net Unrealized Gains (Losses) on Cash Flow Hedges
Defined Benefit Pension and Other
Postretirement
Benefit Plans
Total
 
 
Balance, September 30, 2008
   
$
   
$
(1,790
)
 
$
(1,790
)
 
Current-period change
     
79
     
(939
)
   
(860
)
 
Adoption of SFAS No. 158, as codified in
  ASC Topic 715
     
     
31
     
31
 
 
Balance, September 30, 2009
     
79
     
(2,698
)
   
(2,619
)
 
Current-period change
     
(64
)
   
(192
)
   
(256
)
 
Balance, September 30, 2010
   
$
15
   
$
(2,890
)
 
$
(2,875
)

Income tax expense (benefit) recorded for items of other comprehensive income reported in the Statements of Comprehensive Income is calculated by applying statutory federal, state, and local income tax rates applicable to ordinary income. The tax rates applied to individual items of other comprehensive income are similar within each reporting period.


4.
LONG-TERM DEBT

Maturities on long-term debt for the five fiscal years subsequent to September 30, 2010 are as follows:

 
2011
$25 million
    (Paid at maturity on November 15, 2010)
 
2012
 
 
2013
$25 million
 
 
2014
 
 
2015
 

At September 30, 2010, Laclede Gas had fixed-rate long-term debt totaling $390 million (including current maturities). While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. Of the Utility’s $390 million in long-term debt, $75 million have no call options, $235 million have make-whole call options, and $80 million are callable at par in 2013. None of the debt has any put options.
Laclede Gas has on file with the SEC an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, all of which remains available to Laclede Gas at this time. The Utility has authority from the MoPSC until June 30, 2013 to issue up to $518 million in debt securities and preferred stock, including on a private placement basis, as well as to enter into capital leases, issue common stock and receive paid-in capital, of which $517.6 million remained under this authorization as of September 30, 2010. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions.
Substantially all of the utility plant of Laclede Gas is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock, which are described more fully in Note 3 , Stockholder’s Equity.
At September 30, 2010 and 2009, Laclede Gas had preferred stock shares authorized totaling 1,480,000, but none were issued and outstanding.


5.
NOTES PAYABLE AND CREDIT AGREEMENTS

The Utility’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. Laclede Gas has a syndicated line of credit in place of $320 million from 10 banks, with the largest portion provided by a single bank being 17.5%. This line expires in December 2011. During fiscal year 2010, Laclede Gas utilized only commercial paper for external short-term funding. Commercial paper borrowings ranged between $48.2 million and $178.0 million during the fiscal year, and stood at $129.7 million on September 30, 2010. The weighted average interest rate on the short-term borrowings was 0.3% per annum at September 30, 2010. For the entire fiscal year, short-term borrowings averaged $107.9 million at an average interest rate of 0.3%. Laclede Gas borrowed a maximum of $1.2 million from Laclede Group during the fiscal year, and there were no such borrowings outstanding at the end of the fiscal year.

 
43
 
 

During fiscal year 2009, the Utility’s short-term borrowing requirements, which ranged between $116.9 million and $386.4 million, were generally met by the sale of commercial paper. However, due to unfavorable terms in the commercial paper markets generally in the first half of fiscal year 2009, Laclede Gas utilized its line of credit and borrowing from Laclede Group as more economical sources of short-term financing. External borrowings (which exclude borrowings from Laclede Group) ranged between $116.9 million and $309.9 million. The Utility had $129.8 million in commercial paper outstanding as of September 30, 2009, at a weighted average interest rate of 0.2% per annum, and no borrowings under its bank line or from Laclede Group.
Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation, and amortization (EBITDA) to be at least 2.25 times interest expense. On September 30, 2010, total debt was 56% of total capitalization . For the fiscal year ended September 30, 2010, EBITDA was 4.55 times interest expense.


FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts and estimated fair values of financial instruments at September 30, 2010 and 2009 are as follows:

 
 
(Thousands)
 
Carrying
Amount
 
Fair
Value
 
                 
 
2010:
             
 
Cash and cash equivalents
 
$
1,009
 
$
1,009
 
 
Marketable securities
   
12,856
   
12,856
 
 
Derivative instrument assets
   
10,974
   
10,974
 
 
Short-term debt
   
129,650
   
129,650
 
 
Long-term debt, including current portion
   
389,298
   
443,959
 
                 
 
2009:
             
 
Cash and cash equivalents
 
$
1,402
 
$
1,402
 
 
Marketable securities
   
11,110
   
11,110
 
 
Derivative instrument assets
   
12,369
   
12,369
 
 
Short-term debt
   
129,800
   
129,800
 
 
Long-term debt
   
389,240
   
423,375
 

The carrying amounts for cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. The fair value of marketable securities and derivative instrument assets are valued as described in Note 7 , Fair Value Measurements.


 
44
 
 


FAIR VALUE MEASUREMENTS

The following table categorizes the assets and liabilities in the Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Effects of Netting and Cash Margin Receivables
/Payables
   
Total
 
 
As of September 30, 2010
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
12,856
 
$
 
$
 
$
 
$
12,856
 
 
  NYMEX natural gas contracts
   
1,909
   
   
   
8,786
   
10,695
 
 
  NYMEX gasoline and heating
    oil contracts
   
59
   
   
   
220
   
279
 
 
        Total
 
$
14,824
 
$
 
$
 
$
9,006
 
$
23,830
 
                                   
 
Liabilities
                               
 
  NYMEX natural gas contracts
 
$
40,537
 
$
 
$
 
$
(40,537
)
$
 
 
  NYMEX gasoline & heating
    oil contracts
   
37
   
   
   
(37
)
 
 
 
        Total
 
$
40,574
 
$
 
$
 
$
(40,574
)
$
 
                                   
 
As of September 30, 2009
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
11,110
 
$
 
$
 
$
 
$
11,110
 
 
  NYMEX natural gas contracts
   
6,971
   
   
   
5,121
   
12,092
 
 
  NYMEX gasoline and heating
    oil contracts
   
278
   
   
   
(1
)
 
277
 
 
        Total
 
$
18,359
 
$
 
$
 
$
5,120
 
$
23,479
 
                                   
 
Liabilities
                               
 
  NYMEX natural gas contracts
 
$
53,144
 
$
 
$
 
$
(53,144
)
$
 

The mutual funds included in Level 1 are valued based on quoted market prices of identical securities that are provided by the trustees of these securities. Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX). During fiscal years 2010 and 2009, there were no transfers between the levels of the fair value hierarchy. The Utility’s policy is to recognize such transfers, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer. The mutual funds are included in the Other investments line of the Balance Sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the Balance Sheets when a legally enforceable netting agreement exists between Laclede Gas and the counterparty to a derivative contract. For additional information on derivative instruments, see Note 8 , Derivative Instruments and Hedging Activities.


 
45
 
 


DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation and permits the Utility to hedge up to 70% of its normal volumes purchased for up to a 36-month period. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause, through which the MoPSC allows the Utility to recover gas supply costs, subject to prudence review. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. The Utility does not designate these instruments as hedging instruments for financial reporting purposes because gains or losses associated with the use of these derivative instruments are deferred and recorded as regulatory assets or regulatory liabilities pursuant to ASC Topic 980 and, as a result, have no direct impact on the Statements of Income. The timing of the operation of the PGA Clause may cause interim variations in short-term cash flows because the Utility is subject to cash margin requirements associated with changes in the values of these instruments. Nevertheless, carrying costs associated with such requirements are recovered through the PGA Clause.
From time to time, Laclede Gas purchases NYMEX futures contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At September 30, 2010, Laclede Gas held 0.6 million gallons of gasoline futures contracts at an average price of $2.10 per gallon and 0.1 million gallons of heating oil futures contracts (to hedge diesel fuel purchases) at an average price of $2.33 per gallon. Most of these futures contracts, the longest of which extends to September 2011, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815, “Derivatives and Hedging.” The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.
Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the Balance Sheets at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income (OCI). Accumulated other comprehensive income (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at September 30, 2010, it is expected that essentially no net amounts will be reclassified into the Statements of Income during fiscal year 2011. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the Statements of Cash Flows.
The Utility’s derivative instruments consist primarily of NYMEX positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. NYMEX-traded contracts are supported by the financial and credit quality of the clearing members of the NYMEX and have nominal credit risk. Open NYMEX natural gas futures positions at September 30, 2010 were as follows:

     
MMBtu
(millions)
 
Avg. Price
Per
MMBtu
 
Open long futures positions
           
 
    Fiscal 2011
 
13.16
 
$
6.19
 
 
    Fiscal 2012
 
4.94
   
5.47
 



 
46
 
 

At September 30, 2010, Laclede Gas also had 23.9 million MMBtu of other price risk mitigation in place through the use of NYMEX natural gas option-based strategies.

The Effect of Derivative Instruments on the Statements of Income and Statements of Comprehensive Income
 
                           
   
Location of Gain (Loss)
                     
(Thousands)
 
Recorded in Income
     
2010
       
2009 (a)
   
Derivatives in Cash Flow Hedging Relationships
                         
                           
NYMEX gasoline and heating oil contracts:
                         
  Effective portion of gain (loss) recognized in
    OCI on derivative
       
$
160
     
$
248
   
                           
  Effective portion of gain (loss) reclassified from
    AOCI to income
 
Utility – Other Operation Expenses
     
264
       
119
   
                           
  Ineffective portion of gain (loss) on derivatives
    recognized in income
 
Utility – Other Operation Expenses
     
(57
)
     
198
   
                       
Derivatives Not Designated as Hedging Instruments (b)
                     
                           
NYMEX gasoline and heating oil contracts:
                         
                           
  Gain (loss) recognized in income on derivative
 
Other Income and (Income Deductions) - Net
   
$
(1
)
   
$
17
   

(a)
The Utility prospectively adopted SFAS No. 161, as codified in ASC Topic 815, in the second quarter of fiscal year 2009. Accordingly, amounts disclosed in this column exclude activity prior to January 1, 2009.
(b)  Gains and losses on Laclede Gas' NYMEX natural gas derivative instruments, which are not designeated as hedging instruments for financial reporting purposes, are deferred pursuant to the Utility's PGA Clause and recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Income. 


 
47
 
 


Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2010
 
           
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair Value
*
Balance Sheet Location
 
Fair Value
*
Derivatives designated as hedging instruments
             
                   
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
$
56
 
Derivative Instrument Assets
$
34
 
                   
Derivatives not designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
 
1,401
 
Derivative Instrument Assets
 
37,457
 
   
Other Deferred Charges
 
508
 
Other Deferred Charges
 
3,080
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
3
 
Derivative Instrument Assets
 
3
 
        Sub-total
     
1,912
     
40,540
 
  Total derivatives
   
$
1,968
   
$
40,574
 
                   
Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2009
 
                   
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair Value
*
Balance Sheet Location
 
Fair Value
*
Derivatives designated as hedging instruments
             
                   
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
$
278
 
Derivative Instrument Assets
$
 
                   
Derivatives not designated as hedging instruments
             
                   
  NYMEX natural gas contracts
 
Derivative Instrument Assets
 
6,971
 
Derivative Instrument Assets
 
53,144
 
  Total derivatives
   
$
7,249
   
$
53,144
 

*
The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Utility’s net economic exposure. Refer to Note 7 , Fair Value Measurements, for information on the valuation of derivative instruments.

Following is a reconciliation of the amounts in the tables above to the amounts presented in the Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Fair value of asset derivatives presented above
 
$
1,968
 
$
7,249
 
 
Fair value of cash margin receivables
   
49,580
   
58,264
 
 
Netting of assets and liabilities with the same counterparty
   
(40,574
)
 
(53,144
)
 
  Total
 
$
10,974
 
$
12,369
 
                 
 
Derivative Instrument Assets, per Balance Sheets:
             
 
  Derivative instrument assets
 
$
9,288
 
$
12,369
 
 
  Other deferred charges
   
1,686
   
 
 
    Total
 
$
10,974
 
$
12,369
 
                 
 
Fair value of liability derivatives presented above
 
$
40,574
 
$
53,144
 
 
Netting of assets and liabilities with the same counterparty
   
(40,574
)
 
(53,144
)
 
  Derivative instrument liabilities, per Balance Sheets*
 
$
 
$
 
                 
*
Included in the Other line of the Current Liabilities section
             


 
48
 
 


9.
INCOME TAXES

The net provisions for income taxes charged during the fiscal years ended September 30, 2010, 2009, and 2008 are as follows:

 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Included in Statements of Income:
                   
 
  Federal
                   
 
    Current
 
$
(11,412
)
$
(6,437
)
$
7,476
 
 
    Deferred
   
27,222
   
18,423
   
5,762
 
 
    Investment tax credits
   
(216
)
 
(219
)
 
(227
)
 
  State and local
                   
 
    Current
   
(1,892
)
 
(1,108
)
 
1,153
 
 
    Deferred
   
4,448
   
3,200
   
1,100
 
 
Total Income Tax Expense
 
$
18,150
 
$
13,859
 
$
15,264
 

The effective income tax rate varied from the federal statutory income tax rate for each year due to the following:

     
2010
 
2009
 
2008
 
                       
 
Federal income tax statutory rate
   
35.0
%
 
35.0
 %
 
35.0
 %
 
State and local income taxes, net of federal
                   
 
  income tax benefits
   
2.9
   
2.9
   
2.7
 
 
Certain expenses capitalized on books and
                   
 
  deducted on tax return
   
(5.6
)
 
(5.9
)
 
(5.4
)
 
Taxes related to prior years
   
(0.4
)
 
(0.5
)
 
(1.4
)
 
Other items – net
   
(0.5
)
 
(2.0
)
 
(2.9
)
 
Effective income tax rate
   
31.4
%
 
29.5
 %
 
28.0
 %

The significant items comprising the net deferred tax liability recognized in the Balance Sheets as of September 30 are as follows:

 
(Thousands)
 
2010
 
2009
 
                 
 
Deferred tax assets:
             
 
  Reserves not currently deductible
 
$
18,808
 
$
19,419
 
 
  Pension and other postretirement benefits
   
78,790
   
80,508
 
 
  Unamortized investment tax credits
   
2,222
   
2,358
 
 
  Other
   
7,108
   
10,015
 
 
      Total deferred tax assets
   
106,928
   
112,300
 
                 
 
Deferred tax liabilities:
             
 
  Relating to property
   
255,901
   
221,392
 
 
  Regulatory pension and other postretirement benefits
   
110,396
   
109,041
 
 
  Deferred gas costs
   
22,126
   
16,609
 
 
  Other
   
15,519
   
22,551
 
 
      Total deferred tax liabilities
   
403,942
   
369,593
 
                 
 
Net deferred tax liability
   
297,014
   
257,293
 
 
Net deferred tax liability – current
   
(4,248
)
 
(912
)
 
Net deferred tax liability – non-current
 
$
292,766
 
$
256,381
 


 
49
 
 


Laclede Group files a consolidated federal and state income tax return and allocates income taxes to Laclede Gas and its other subsidiaries as if each entity were a separate taxpayer. Pursuant to GAAP, the Utility may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Utility records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are included in the Other line of the Deferred Credits and Other Liabilities section of the Balance Sheets.
The following table presents a reconciliation of the beginning and ending amount balances of unrecognized tax benefits at September 30 as reported in the Balance Sheets:

 
(Thousands)
 
2010
 
2009
 
                 
 
Unrecognized tax benefits, beginning of year
 
$
1,366
 
$
1,033
 
 
Increases related to tax positions taken in current year
   
5,017
   
333
 
 
Unrecognized tax benefits, end of year
 
$
6,383
 
$
1,366
 

The amount of unrecognized tax benefits, which, if recognized, would affect the Utility’s effective tax rate were $1.7 million and $1.4 million as of September 30, 2010 and 2009, respectively. It is reasonably possible that events will occur in the next 12 months that could increase or decrease the amount of the Utility’s unrecognized tax benefits. The Utility does not expect any such change will be significant.
Interest accrued associated with the Utility’s uncertain tax positions as of September 30, 2010 and 2009 were $0.3 million and $0.1 million, respectively, and no penalties were accrued as of those dates. Interest expense accrued during fiscal year 2010 was $0.2 million and immaterial for fiscal year 2009 and 2008. During fiscal year 2008, the Utility reversed $0.2 million of accrued interest expense and $0.1 million of accrued penalties in the Statements of Income.
Laclede Group and/or Laclede Gas are subject to U.S. federal income tax as well as income tax of state and local jurisdictions. These companies are no longer subject to examination for fiscal years prior to 2007.


10.
OTHER INCOME AND (INCOME DEDUCTIONS) – NET
 
 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Interest income
 
$
1,493
 
$
2,505
 
$
2,133
 
 
Net investment gain (loss)
   
890
   
229
   
(1,403
)
 
Other income
   
161
   
316
   
69
 
 
Other income deductions
   
25
   
78
   
407
 
 
Other Income and (Income Deductions) – Net
 
$
2,569
 
$
3,128
 
$
1,206
 

The decrease in Other Income and (Income Deductions) – Net in fiscal year 2010 (compared to fiscal year 2009), was primarily due to lower income associated with carrying costs applied to under-recoveries of gas costs and other minor variations, partially offset by higher net investment gains. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s PGA Clause.
The increase in Other Income and (Income Deductions) – Net in fiscal year 2009 (compared to fiscal year 2008), was primarily due to higher net investment gains and increased income associated with carrying costs applied to under-recoveries of gas costs, partially offset by additional proceeds received during fiscal year 2008 related to the Utility’s interest, as a policyholder, in the sale of a mutual insurance company.


 
50
 
 


11.
INFORMATION BY OPERATING SEGMENT

The Regulated Gas Distribution segment consists of the regulated operations of Laclede Gas. Laclede Gas is a public utility engaged in the retail distribution and sale of natural gas serving an area of eastern Missouri, with a population of approximately 2.1 million, including the City of St. Louis and ten counties in eastern Missouri. The Non-Regulated Other segment includes the retail sale of gas appliances, which ceased operation September 30, 2009 and was not material, and the non-regulated propane transaction. Accounting policies are described in Note 1 . There are no material intersegment revenues.
Beginning in fiscal 2010, Laclede Gas’ parent company, Laclede Group, evaluates the performance of its operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impact of net unrealized gains and losses on energy-related derivative contracts. For comparative purposes, the measurement of segment performance has been presented to conform to the current-period presentation.

   
Regulated Gas
 
Non-Regulated
 
Adjustments &
     
(Thousands)
 
Distribution
 
Other
 
Eliminations
 
Total
 
                           
FISCAL 2010
                         
Operating revenues
 
$
864,297
 
$
10,327
 
$
 
$
874,624
 
Depreciation & amortization
   
37,572
   
   
   
37,572
 
Interest income
   
1,493
   
   
   
1,493
 
Interest charges
   
26,852
   
   
   
26,852
 
Income tax expense
   
15,842
   
2,308
   
   
18,150
 
Net economic earnings
   
36,141
   
3,675
   
   
39,816
 
Total assets
   
1,657,530
   
922
   
   
1,658,452
 
Capital expenditures
   
56,234
   
   
   
56,234
 
                           
FISCAL 2009
                         
Operating revenues
 
$
1,053,993
 
$
2,246
 
$
 
$
1,056,239
 
Depreciation & amortization
   
36,751
   
   
   
36,751
 
Interest income
   
2,505
   
   
   
2,505
 
Interest charges
   
30,353
   
   
   
30,353
 
Income tax expense
   
13,856
   
3
   
   
13,859
 
Net economic earnings
   
33,072
   
6
         
33,078
 
Total assets
   
1,598,600
   
1,687
   
   
1,600,287
 
Capital expenditures
   
51,384
   
   
   
51,384
 
                           
FISCAL 2008
                         
Operating revenues
 
$
1,128,287
 
$
2,693
 
$
 
$
1,130,980
 
Depreciation & amortization
   
35,303
   
   
   
35,303
 
Interest income
   
2,133
   
   
   
2,133
 
Interest charges
   
30,214
   
   
   
30,214
 
Income tax expense
   
15,244
   
20
   
   
15,264
 
Net economic earnings
   
39,174
   
32
         
39,206
 
Total assets
   
1,624,041
   
1,774
   
   
1,625,815
 
Capital expenditures
   
55,304
   
   
   
55,304
 

 
Reconciliation of Net Economic Earnings to Net Income
 
                 
 
(Thousands)
 
2010
 
2009
 
2008
 
                       
 
Total Net Economic Earnings above
 
$
39,816
 
$
33,078
 
$
39,206
 
 
  Add: Unrealized gain (loss) on energy-related
    derivative contracts, net of tax
   
(91
)
 
105
   
 
 
Net Income
 
$
39,725
 
$
33,183
 
$
39,206
 


 
51
 
 


COMMITMENTS AND CONTINGENCIES

Commitments

Laclede Gas estimates fiscal year 2011 utility capital expenditures at approximately $64 million. There are no material contractual commitments at September 30, 2010 related to these estimated capital expenditures.
Laclede Gas has entered into various contracts, expiring on dates through 2017, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at September 30, 2010 are estimated at approximately $410 million. Additional contracts are generally entered into prior to or during the heating season. Laclede Gas estimates that it will pay approximately $86 million annually, at present rate levels, for fixed charges related to these or other contracts that are expected to be in place for the upcoming year for the reservation of gas supplies and pipeline transmission and storage capacity. The Utility recovers its costs from customers in accordance with the PGA Clause.
Laclede Pipeline Company (Pipeline), a wholly-owned subsidiary of Laclede Group, is providing liquid propane transportation service to Laclede Gas pursuant to an approved FERC tariff and a contractual arrangement between Pipeline and Laclede Gas. In accordance with the terms of that agreement, Laclede Gas is obligated to pay Pipeline approximately $1.0 million annually, at current rates. The agreement renews at the end of each contract year, unless terminated by either party upon provision of at least six months’ notice.

Leases and Guarantees

The lease agreement covering the headquarters office space of Laclede Gas extends through February 2015 with the option to renew for up to five additional years. The aggregate rental expense for fiscal years 2010, 2009, and 2008 was $909,000, $900,000, and $891,000, respectively. The annual minimum rental payment for fiscal year 2011 is anticipated to be approximately $917,000 with a maximum annual rental payment escalation of $8,800 per year for each year through fiscal year 2015. Laclede Gas has entered into various operating lease agreements for the rental of vehicles and power operated equipment. The rental costs will be approximately $3.6 million in fiscal year 2011, $2.5 million in fiscal year 2012, $1.5 million in fiscal year 2013, $0.9 million in fiscal year 2014, and $0.2 million in fiscal year 2015. Laclede Gas has other relatively minor rental arrangements that provide for minimum rental payments.
Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2015. At September 30, 2010, the maximum guarantees under these leases are $1.3 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At September 30, 2010, the carrying value of the liability recognized for these guarantees was $0.3 million.

Contingencies

Laclede Gas owns and operates natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs.
As with other companies, Laclede Gas faces the risk of environmental liabilities. In the natural gas industry, these are typically associated with sites formerly owned or operated by gas distribution companies like Laclede Gas and/or its predecessor companies at which manufactured gas operations took place. At this time, Laclede Gas has identified three former manufactured gas plant (MGP) sites located in Missouri: one in Shrewsbury and two in the City of St. Louis.

 
52
 
 

With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, EPA Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs.
The site in the City of St. Louis, which is currently owned by the City, has been enrolled in the Missouri Voluntary Cleanup Program (VCP). The VCP provides potential opportunities to minimize the cost of site cleanup while maximizing possibilities for site development. The City has selected a developer with whom it is negotiating a final site development contract which contemplates remediation and redevelopment of the property. In conjunction with the redevelopment, Laclede Gas and another former site owner have entered into an agreement with the owner and development agencies as well as their parent agency, the private developer of the property, and an environmental consultant (Remediation Agreement). Under the Remediation Agreement, the development agency and the private developer agreed to remediate the site, and Laclede Gas and the other former owner are to be released by the involved City agencies, the private developer, and the environmental consultant from certain liabilities for the past and current environmental condition of the property. Also under that agreement Laclede Gas and the former site owner agreed to pay, at the closing of the transaction, a small percentage of the cost of remediation (subject to a maximum amount). The transactions contemplated by the Remediation Agreement are expected to close during fiscal year 2011. The amount Laclede Gas expects to pay under the Remediation Agreement is not material and will not have a material impact on the future financial condition, results of operations, or cash flows of Laclede Gas.
The third former MGP site, also located in the City of St. Louis, is not currently and has not been owned by Laclede Gas for many years. At this time, it is not known whether Laclede Gas will incur any costs in connection with environmental investigations of or remediation at the site, and if it does incur any such costs, what the amount of those costs would be.
Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the three MGP sites identified above. In response, the majority of insurers have reserved their rights. While some of the insurers have denied coverage, Laclede Gas continues to discuss potential reimbursements with them, with one insurer making a settlement payment in exchange for a release of claims in June 2007. The Utility’s outside consultant completed an analysis of the MGP sites to determine cost estimates for a one-time contractual transfer of risk from each insurer to the Utility of environmental coverage for the MGP sites. That analysis demonstrated a range of possible future expenditures to investigate, monitor, and remediate these MGP sites from $5.8 million to $36.3 million based upon then currently available facts, technology, and laws and regulations. The actual costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remedial actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and governmental regulations, the ultimate ability of other potentially responsible parties to pay, and any insurance recoveries. Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable.
The amount of costs relative to future remedial actions at these and other sites is unknown and may be material. Laclede Gas anticipates that any costs it may incur in the future to remediate these sites, less any amounts received as insurance proceeds or as contributions from other potentially responsible parties, would be deferred and recovered in rates through periodic adjustments approved by the MoPSC. Accordingly, potential liabilities associated with remediating these sites are not expected to have a material impact on the future financial position and results of operations of Laclede Gas.
On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, Laclede Energy Resources, Inc. (LER). The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. On December 31, 2009, the MoPSC Staff proposed a number of non-monetary recommendations only, based on its review of gas costs for fiscal year 2008. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.
In its December 31, 2007 recommendation relating to fiscal year 2006 gas costs, the MoPSC Staff also raised questions regarding whether certain sales and capacity release transactions subject to the FERC’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. Laclede Group commenced an internal review of the questions raised by the MoPSC Staff and notified the FERC Staff that it took this action. In June 2008, as a result of the internal review, Laclede Group provided the FERC Staff with a self report regarding compliance of sales and capacity release activities with the FERC’s regulations and policies. On February 9, 2010, the FERC Staff informed Laclede Group that it has closed its investigation of Laclede Group’s self report without taking further action.

 
53
 
 

In connection with the affiliate transaction matters mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order approving a 2001 Stipulation and Agreement that permitted the Laclede Group’s corporate reorganization into a holding company structure. Also, on October 6, 2010, the MoPSC Staff filed a related complaint against Laclede Gas alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. Laclede Gas believes that neither of the complaints have merit and intends to vigorously oppose both of them. In addition, the Company had filed a counterclaim against the MoPSC Staff in the July 7 complaint case alleging that the Staff has failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and the provisions under which the Company allocates costs among affiliated companies. However, on November 3, 2010, the MoPSC issued an order dismissing the Utility’s counterclaim for failure to state a claim upon which relief may be granted.
Laclede Gas is involved in other litigation, claims, and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the financial position, results of operations, or cash flows of the Utility.


13.
INTERIM FINANCIAL INFORMATION (UNAUDITED)

In the opinion of Laclede Gas, the quarterly information presented below for fiscal years 2010 and 2009 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in operations reported on a quarterly basis primarily reflect the seasonal nature of the business of Laclede Gas.

 (Thousands)
               
 
               
 
 
 
 
Three Months Ended
   
  
 
Dec. 31
       
March 31
       
June 30
       
Sept. 30
 
                                           
Fiscal Year 2010
                                         
Total Operating Revenues
     
$
293,254
     
$
373,521
     
$
124,746
     
$
83,103
 
Operating Income (Loss)
       
37,702
       
42,852
       
5,589
       
(3,985
)
Net Income (Loss)
       
21,066
       
23,416
       
24
       
(4,781
)
                                           
                                           
Three Months Ended
       
Dec. 31
       
March 31
       
June 30
       
Sept. 30
 
                                           
Fiscal Year 2009
                                         
Total Operating Revenues
     
$
358,698
     
$
441,067
     
$
160,917
     
$
95,557
 
Operating Income (Loss)
       
32,959
       
42,068
       
8,951
       
(9,711
)
Net Income (Loss)
       
16,197
       
22,186
       
2,347
       
(7,547
)


 
54