UNITED STATES
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 December 31, 2008.
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    001-13643

ONEOK, Inc.
(Exact name of registrant as specified in its charter)

Oklahoma
73-1520922
(State or other jurisdiction of
incorporation or organization)
(I.R.S. Employer Identification No.)
 
   
100 West Fifth Street, Tulsa, OK
74103
(Address of principal executive offices)
(Zip Code)

Registrant’s telephone number, including area code    (918) 588-7000

Securities registered pursuant to Section 12(b) of the Act:
Common stock, par value of $0.01
New York Stock Exchange
(Title of Each Class)
(Name of Each Exchange on which Registered)

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. Yes X No__.

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes __  No X .

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.  Yes X   No __

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Registration S-K (§229.405) 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. X

Indicate by checkmark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer.  See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.  (Check one)
Large accelerated filer X                                                                 Accelerated filer __                                           Non-accelerated filer __

Indicate by checkmark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes__ No X .

Aggregate market value of registrant’s common stock held by non-affiliates based on the closing trade price on June 30, 2008, was $5.1 billion.

On February 18, 2009, the Company had 105,239, 496   shares of common stock outstanding.

DOCUMENTS INCORPORATED BY REFERENCE:
Portions of the definitive proxy statement to be delivered to shareholders in connection with the Annual Meeting of Shareholders to be held May 21, 2009, are incorporated by reference in Part III.

 
 

 

ONEOK, Inc.
2008 ANNUAL REPORT ON FORM 10-K
Part I.
 
Page No.
 
Item 1.
 
Item 1A.
 
Item 1B.
 
 
 
 
 
5-17
 
17-29
 
29
Item 2.
29-30
 
Item 3.
 
 
31-32
 
Item 4.
 
 
32
 
Part II.
 
   
Item 5.
 
32-34
 
Item 6.
35
 
Item 7.
 
35-62
 
Item 7A.
63-66
 
Item 8.
67-117
 
Item 9.
 
Item 9A.
 
Item 9B.
 
 
117
 
117-118
 
118
 
Part III.
 
   
Item 10.
118-119
 
Item 11.
119
 
Item 12.
 
119
 
Item 13.
120
 
Item 14.
120
 
Part IV.
 
   
Item 15.
120-125
 
 
126
 

As used in this Annual Report on Form 10-K, references to “we,” “our” or “us” refers to ONEOK, Inc., an Oklahoma corporation, and its predecessors and subsidiaries, unless the context indicates otherwise.

 
- 2 -


GLOSSARY

The abbreviations, acronyms and industry terminology used in this Annual Report on Form 10-K are defined as follows:

 
AFUDC
Allowance for funds used during construction
 
APB Opinion
Accounting Principles Board Opinion
 
ARB
Accounting Research Bulletin
 
Bbl
Barrels, 1 barrel is equivalent to 42 United States gallons
 
Bbl/d
Barrels per day
 
BBtu/d
Billion British thermal units per day
 
Bcf
Billion cubic feet
 
Bcf/d
Billion cubic feet per day
 
Black Mesa Pipeline
Black Mesa Pipeline, Inc.
 
Btu
British thermal units, a measure of the amount of heat required to raise
     the temperature of one pound of water one degree Fahrenheit
 
Bushton Plant
Bushton Gas Processing Plant
 
EBITDA
Earnings before interest, taxes, depreciation and amortization
 
EITF
Emerging Issues Task Force
 
EPA
United States Environmental Protection Agency
 
Exchange Act
Securities Exchange Act of 1934, as amended
 
FASB
Financial Accounting Standards Board
 
FERC
Federal Energy Regulatory Commission
 
FIN
FASB Interpretation
 
Fort Union Gas Gathering
Fort Union Gas Gathering, L.L.C.
 
GAAP
Generally Accepted Accounting Principles in the United States
 
Guardian Pipeline
Guardian Pipeline, L.L.C.
 
Heartland
Heartland Pipeline Company
 
IRS
Internal Revenue Service
 
KCC
Kansas Corporation Commission
 
KDHE
Kansas Department of Health and Environment
 
LDCs
Local Distribution Companies
 
LIBOR
London Interbank Offered Rate
 
MBbl
Thousand barrels
 
MBbl/d
Thousand barrels per day
 
Mcf
Thousand cubic feet
 
Midwestern Gas Transmission
Midwestern Gas Transmission Company
 
MMBbl
Million barrels
 
MMBtu
Million British thermal units
 
MMBtu/d
Million British thermal units per day
 
MMcf
Million cubic feet
 
MMcf/d
Million cubic feet per day
 
Moody’s
Moody’s Investors Service, Inc.
 
NGL(s)
Natural gas liquid(s)
 
Northern Border Pipeline
Northern Border Pipeline Company
 
NYMEX
New York Mercantile Exchange
 
NYSE
New York Stock Exchange
 
OBPI
ONEOK Bushton Processing Inc.
 
OCC
Oklahoma Corporation Commission
 
ONEOK
ONEOK, Inc.
 
ONEOK Leasing Company
ONEOK Leasing Company, L.L.C.
 
ONEOK Partners
ONEOK Partners, L.P.
 
ONEOK Partners GP
ONEOK Partners GP, L.L.C., a wholly owned subsidiary of ONEOK
     and the sole general partner of ONEOK Partners
 
OPIS
Oil Price Information Service
 
Overland Pass Pipeline Company
Overland Pass Pipeline Company LLC
 
RRC
Texas Railroad Commission
 
S&P
Standard & Poor’s Rating Group
 
SEC
Securities and Exchange Commission
 
Statement
Statement of Financial Accounting Standards

 
- 3 -


 
TC PipeLines
TC PipeLines Intermediate Limited Partnership, a subsidiary of TC
     PipeLines, LP
 
TransCanada
TransCanada Corporation

The statements in this Annual Report on Form 10-K  that are not historical information, including statements concerning plans and objectives of management for future operations, economic performance or related assumptions, are forward-looking statements.  Forward-looking statements may include words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “could,” “may,” “continue,” “might,” “potential,” “scheduled”  and other words and terms of similar meaning.  Although we believe that our expectations regarding future events are based on reasonable assumptions, we can give no assurance that such expectations and assumptions will be achieved.  Important factors that could cause actual results to differ materially from those in the forward-looking statements are described under Part I, Item 1A, Risk Factors, and Part II, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation and “Forward-Looking Statements,”  in this Annual Report on Form 10-K for the year ended December 31, 2008.



 
- 4 -


PART I
ITEM 1.                      BUSINESS

GENERAL

We are a diversified energy company and successor to the company founded in 1906 known as Oklahoma Natural Gas Company.  Our common stock is listed on the NYSE under the trading symbol “OKE.”  We are the sole general partner and own 47.7 percent of ONEOK Partners, L.P. (NYSE: OKS), one of the largest publicly traded master limited partnerships.  ONEOK Partners is a leader in the gathering, processing, storage and transportation of natural gas in the United States.  In addition, ONEOK Partners owns one of the nation’s premier natural gas liquids systems, connecting NGL supply in the Mid-Continent and Rocky Mountain regions with key market centers.  We are the largest natural gas distributor in Oklahoma and Kansas and the third largest natural gas distributor in Texas, providing service as a regulated public utility to wholesale and retail customers.  Our largest distribution markets are Oklahoma City and Tulsa, Oklahoma; Kansas City, Wichita, and Topeka, Kansas; and Austin and El Paso, Texas.  Our energy services operation is engaged in providing premium natural gas marketing services to wholesale and retail customers across the United States and Canada.

DESCRIPTION OF BUSINESS SEGMENTS

We report operations in the following reportable business segments:
·  
ONEOK Partners
·  
Distribution
·  
Energy Services
·  
Other

For financial and statistical information regarding our business segments, see below in the “Segment Financial Information” section, Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation and Note M of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

Business Strategy

Our primary business strategy is to deliver consistent growth and sustainable earnings, while focusing on safe, reliable, environmentally sound and legally compliant operations for our customers, employees, contractors and the public through the following:
·  
developing and executing internally generated growth projects within our ONEOK Partners segment;
·  
increasing the level of sustainable earnings in our Distribution segment;
·  
continuing our focus on physical activities in our Energy Services segment;
·  
executing strategic acquisitions that utilize our core competencies; and
·  
managing our balance sheet over the long term to maintain our credit ratings at or above their current investment-grade levels.

ONEOK Partners - ONEOK Partners’ primary business objectives are to generate cash flow sufficient to pay quarterly cash distributions to its unitholders and to increase its quarterly cash distributions over time.  ONEOK Partners’ ability to maintain and grow its distributions to unitholders depends on, among other things, the growth of its existing businesses and strategic acquisitions.  We plan to continue pursuing internal growth opportunities and strategic acquisitions related to gathering, processing, fractionating, transporting, storing and marketing natural gas and NGLs that will utilize our core competencies, minimize commodity price risk and provide long-term, sustainable and stable cash flows.  Our strategy focuses on maintaining stable cash flows through predominantly fee-based income, equity earnings derived primarily from fee-based earnings, and by managing commodity and spread risk.

Distribution - Our integrated strategy for our LDCs incorporates a rates and regulatory plan that includes positive relationships with regulators, consistent strategies and synchronized rate case filings.  We focus on growth of our customer count and rate base through efficient investment in our system while emphasizing safety and cost control.  We provide customer choice programs designed to reduce volumetric sensitivity and create value for our customers.

Energy Services - Our Energy Services segment creates value by providing premium services to our customers by delivering physical and risk management products and services to our customers through our network of contracted gas supply and leased transportation and storage assets.  We optimize our storage and transportation capacity through the daily application of market knowledge and effective risk management.


Outlook for 2009

We expect continued deteriorating economic conditions in 2009, with downward pressures, relative to 2008, on commodity prices for natural gas, NGLs and crude oil.  We anticipate that lower commodity prices will result in reduced drilling activity and economic conditions will result in reduced petrochemical demand.  We also expect continued volatility and disruption in the financial markets which could result in an increased cost of capital.  We expect depressed commodity prices and tighter capital markets to also result in the sale or consolidation of underperforming assets in the industry, which may present opportunities for us.

ONEOK Partners - ONEOK Partners intends to pursue continued growth in its natural gas businesses through well-connects, contract renegotiations and expansions and extensions of its existing systems and plants.  For its natural gas liquids businesses, ONEOK Partners will continue to focus on adding new supply connections and optimizing existing assets, as well as completing the growth projects currently under construction.  Capital expenditures in 2009 are expected to be significantly lower than in 2008 when ONEOK Partners spent approximately $1.3 billion.  ONEOK Partners plans to spend approximately $425 million on capital expenditures in 2009, of which approximately $355 million is for growth projects.  ONEOK Partners also plans to pursue strategic acquisitions related to gathering, processing, fractionating, storing, transporting and marketing natural gas and NGLs.

Distribution - In our Distribution segment, we plan to grow our asset base through efficient capital investment in infrastructure and technology and increase the level of sustainable earnings.

Energy Services - In our Energy Services segment, we expect higher natural gas basis differentials.  We plan to manage our current portfolio of supply and leased assets, reduce storage capacity utilization as compared with 2008, continue to offer premium products and services, and draw on the competitive position of our assets to extract incremental value through daily optimization of storage and transportation assets.  Additionally, we plan to grow our asset management agreements with LDCs, use hedging to establish base margins and capture incremental margins related to location and seasonal differences, and continue to achieve high customer satisfaction.

SIGNIFICANT DEVELOPMENTS IN 2008

Capital Projects - ONEOK Partners placed the following projects in-service during 2008:
·  
January - Midwestern Gas Transmission’s eastern extension pipeline;
·  
July - final phase of Fort Union Gas Gathering expansion project;
·  
September - Woodford Shale natural gas liquids pipeline extension;
·  
October - Bushton Fractionation expansion;
·  
November - Overland Pass Pipeline from Opal, Wyoming to Conway, Kansas; and
·  
December - partial operations of the Guardian Pipeline extension with interruptible service from Ixonia, Wisconsin, to Green Bay, Wisconsin.

Equity Issuance - In March 2008, we purchased from ONEOK Partners, in a private placement, an additional 5.4 million of ONEOK Partners’ common units for a total purchase price of approximately $303.2 million.  In addition, ONEOK Partners completed a public offering of 2.5 million common units at $58.10 per common unit and received net proceeds of $140.4 million after deducting underwriting discounts but before offering expenses.  In conjunction with ONEOK Partners’ private placement and public offering of common units, ONEOK Partners GP contributed $9.4 million to ONEOK Partners in order to maintain its 2 percent general partner interest.

In April 2008, ONEOK Partners sold an additional 128,873 common units at $58.10 per common unit to the underwriters of the public offering upon the partial exercise of their option to purchase additional common units to cover over-allotments.  ONEOK Partners received net proceeds of approximately $7.2 million from the sale of these common units after deducting underwriting discounts but before offering expenses.  In conjunction with the partial exercise by the underwriters, ONEOK Partners GP contributed $0.2 million to ONEOK Partners in order to maintain its 2 percent general partner interest.  Following these transactions, our ownership interest in ONEOK Partners is 47.7 percent.



SEGMENT FINANCIAL INFORMATION

Operating Income - The following table sets forth operating income by segment, as a percentage of our consolidated total, excluding any gain or (loss) on sale of assets, for the periods indicated.
 
 
Years Ended December 31,
Operating Income
2008
2007
2006
ONEOK Partners
70%
   
54%
   
53%
   
Distribution
21%
   
21%
   
16%
   
Energy Services
8%
   
25%
   
31%
   
Other and Eliminations
1%
   
*
   
*
   
Total
100%
   
100%
   
100%
   
                   
* Represents a value of less than 1 percent.
               

Customers and Total Assets - See Note M of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for discussion of revenues from external customers under “Customers” and disclosure of total assets by segment within the “Operating Segment Information” table.

Intersegment Revenues - The following table sets forth the percentage of intersegment revenues to total revenue, by segment, for the periods indicated.
 
 
Years Ended December 31,
Intersegment Revenues
2008
   
2007
   
2006
   
ONEOK Partners
10%
   
11%
   
13%
   
Distribution
*
   
*
   
*
   
Energy Services
8%
   
7%
   
8%
   
                   
* Represents a value of less than 1 percent.
               

See Note M of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional information about intersegment revenues.

NARRATIVE DESCRIPTION OF BUSINESS

ONEOK Partners

Ownership - We own approximately 42.4 million common and Class B limited partner units, and the entire 2 percent general partner interest, which, together, represents a 47.7 percent ownership interest in ONEOK Partners.  We receive distributions from ONEOK Partners on our common and Class B units and our 2 percent general partner interest.  See Note Q of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for discussion of our incentive distribution rights.

Business Strategy - ONEOK Partners’ primary business objectives are to generate cash flow sufficient to pay quarterly cash distributions to its unitholders and to increase its quarterly cash distributions over time.  ONEOK Partners plans to accomplish these objectives while focusing on safe, environmentally sound and legally compliant operations for its customers, employees, contractors and the public through the following:
·  
developing and executing internally generated growth projects;
·  
executing strategic acquisitions related to gathering, processing, fractionating, storing, transporting and marketing natural gas and NGLs that utilize its core competencies; and
·  
managing its balance sheet over the long-term to maintain its investment-grade credit ratings at or above their current levels.
    
Description of Business - Our ONEOK Partners segment is engaged in the gathering and processing of unprocessed natural gas and fractionation of NGLs, primarily in the Mid-Continent, and Rocky Mountain regions covering Oklahoma, Kansas, Montana, North Dakota and Wyoming.  These operations include the gathering of unprocessed natural gas produced from crude oil and natural gas wells.  Through gathering systems, unprocessed natural gas is aggregated and treated or processed for removal of water vapor, solids and other contaminants, and to extract NGLs in order to provide marketable natural gas, commonly referred to as residue gas.  When the NGLs are separated from the unprocessed natural gas at the processing plants, the NGLs are generally in the form of a mixed, unfractionated NGL stream.  This stream is then separated by a distillation process, referred to as fractionation, into marketable product components such as ethane, ethane/propane (EP),


propane, iso-butane, normal butane and natural gasoline (collectively, NGL products).  These NGL products can then be stored, transported and marketed to a diverse customer base of end-users.

Revenue from the gathering and processing business is primarily derived from the following three types of contracts:
·  
Percent of Proceeds - ONEOK Partners retains a percentage of the NGLs and/or a percentage of the residue gas as payment for gathering, compressing and processing the producer’s unprocessed natural gas.  For 2008, this type of contract represented approximately 34 percent of contracted volumes.
·  
Fee - ONEOK Partners is paid a fee for the services provided based on Btus gathered, compressed and/or processed.  For 2008, this type of contract represented approximately 58 percent of contracted volumes.
·  
Keep-Whole - ONEOK Partners extracts NGLs from unprocessed natural gas and returns to the producer volumes of residue gas containing the same amount of Btus as the unprocessed natural gas that was originally delivered.  For 2008, this type of contract represented approximately 8 percent of contracted volumes, with approximately 89 percent of that contracted volume containing language that effectively converts these contracts into fee contracts when the gross processing spread is negative.

ONEOK Partners also gathers, treats, fractionates, transports and stores NGLs.  ONEOK Partners’ natural gas liquids gathering pipelines deliver unfractionated NGLs gathered from natural gas processing plants located in Oklahoma, Kansas, the Texas panhandle and the Rocky Mountain region to fractionators it owns in Oklahoma, Kansas, and Texas.  The NGLs are then separated through the fractionation process into the individual NGL products that realize the greater economic value of the NGL components.  The individual NGL products are then stored or distributed to petrochemical manufacturers, heating fuel users, refineries and propane distributors through ONEOK Partners’ distribution pipelines that move NGL products from Oklahoma and Kansas to the market centers in Conway, Kansas, and Mont Belvieu, Texas, as well as the Midwest markets near Chicago, Illinois.

Revenue for the natural gas liquids businesses is primarily derived from the following types of services:
·  
Exchange services - ONEOK Partners gathers and transports unfractionated NGLs to its fractionators, separating them into marketable products and redelivering the NGL products to its customers for a fee;
·  
Optimization and marketing - ONEOK Partners uses its asset base, portfolio of contracts and market knowledge to capture location and seasonal price differentials through transactions that optimize the flow of its NGL products between the major market centers in Conway, Kansas, and Mont Belvieu, Texas, as well as markets near Chicago, Illinois;
·  
Isomerization - ONEOK Partners converts normal butane to the more valuable iso-butane used by the refining industry to increase the octane of motor gasoline;
·  
Storage services - ONEOK Partners stores NGLs for a fee; and
·  
Transportation - ONEOK Partners transports NGLs under its FERC-regulated tariffs.

ONEOK Partners operates interstate and intrastate natural gas transmission pipelines, natural gas storage facilities and non-processable natural gas gathering facilities.  ONEOK Partners also provides natural gas transportation and storage services in accordance with Section 311(a) of the Natural Gas Policy Act.  ONEOK Partners’ interstate assets transport natural gas through FERC-regulated interstate natural gas pipelines that access supply from Canada and from the Mid-Continent, Rocky Mountain and Gulf Coast regions.  ONEOK Partners’ pipelines include Midwestern Gas Transmission, Guardian Pipeline, Viking Gas Transmission Company, OkTex Pipeline Company L.L.C. and a 50 percent ownership interest in Northern Border Pipeline.

ONEOK Partners’ intrastate natural gas pipeline assets in Oklahoma have access to the major natural gas producing areas and transport natural gas throughout the state.  ONEOK Partners also has access to the major natural gas producing area in south central Kansas.  In Texas, its intrastate natural gas pipelines are connected to the major natural gas producing areas in the Texas panhandle and the Permian Basin, and transport natural gas to the Waha Hub, where other pipelines may be accessed for transportation east to the Houston Ship Channel market, north into the Mid-Continent market and west to the California market.  ONEOK Partners owns or leases storage capacity in underground natural gas storage facilities in Oklahoma, Kansas and Texas.  ONEOK Partners’ natural gas pipeline assets primarily serve LDCs, large industrial companies, municipalities, irrigation customers, power generation facilities and marketing companies.

ONEOK Partners’ revenues from its natural gas pipelines are typically derived from fee services under the following types of contracts:
·  
Firm service - Customers can reserve a fixed quantity of pipeline or storage capacity for the terms of their contracts.  Under this type of contract, the customer pays a fixed fee for a specified quantity regardless of their actual usage, and is generally guaranteed access to the capacity they reserve; and


·  
Interruptible service - Customers with interruptible service transportation and storage agreements may utilize available capacity after firm service requests are satisfied or on an as available basis.  Under the interruptible service contract, the customer is not guaranteed use of our pipelines and storage facilities unless excess capacity is available.

The main factors that affect ONEOK Partners’ margins are:
·  
NGL transportation and fractionation volumes and associated fees;
·  
natural gas transportation and storage volumes;
·  
weather impacts on demand and operations;
·  
fees charged for processing services and storage services;
·  
the Mid-Continent, Gulf Coast and Rocky Mountain natural gas price, crude oil price and the daily average OPIS price for its products sold, as well as the relative value on a Btu basis of each of the components to each other;
·  
the relative value of ethane to natural gas; and
·  
regional and seasonal natural gas and NGL product price differentials.

Market Conditions and Seasonality - Supply - ONEOK Partners’ business is affected by the economy, commodity price volatility, and weather.  The strength of the economy has a direct relationship on manufacturing and industrial companies’ demand for natural gas and NGL products.  Volatility in the commodity markets impacts the decisions of ONEOK Partners’ customers relating to the output of the gas processing plants, storage activity for natural gas and natural gas liquids, and demand for the various NGL products.  In addition, its natural gas liquids pipelines and fractionation facilities are affected by operational or market-driven changes in the output of the gas processing plants to which they are connected.  Natural gas and NGL output from gas processing plants may increase or decrease affecting the quality of natural gas and volume of NGLs transported through the systems as a result of the gross processing spread, which is the difference between the relative value of the composite price of NGLs to the price of natural gas, primarily ethane to natural gas.  In addition, volume delivered through the system may increase or decrease as a result of the relative NGL price between the Mid-Continent and Gulf Coast regions.  Natural gas transportation throughput fluctuates due to rainfall that impacts irrigation demand, hot temperatures that affect power generation demand and cold temperatures that affect heating demand.

Natural gas and NGL supply is affected by rig availability, operating capability and producer drilling activity, which is sensitive to commodity prices, exploration success, available capital and regulatory control.  Relatively high natural gas and crude oil prices, resulted in increased drilling for most of 2008 in the Mid-Continent and Rocky Mountain regions, which are our primary supply regions.  Significant price declines and reduced drilling activity starting in the fourth quarter of 2008 are now creating less favorable near-term supply projections.

Demand   -   Demand for gathering and processing services is typically aligned with the supply of natural gas, which generally flows from a producing area at a relatively steady but gradually declining pace over time unless new reserves are added.  ONEOK Partners’ plant operations can be adjusted to respond to market conditions, such as demand for ethane.  By changing operating parameters at certain plants, ONEOK Partners can produce more of the specific commodity that has the most favorable price or price spread.

Demand for natural gas pipeline transportation service and natural gas storage is directly related to demand for natural gas in the markets that the natural gas pipelines and storage facilities serve, and is affected by weather, the economy, and natural gas price volatility.  The effect of weather on ONEOK Partners’ natural gas pipelines operations is discussed below under “Seasonality.”  The strength of the economy directly impacts manufacturing and industrial companies that rely on natural gas.  Commodity price volatility can influence customers’ decisions related to the usage of natural gas versus alternative fuels and natural gas storage injection and withdrawal activity.

Demand for NGLs and the ability of natural gas processors to successfully and economically sustain their operations impacts the volume of unfractionated NGLs produced by natural gas processing plants, thereby affecting the demand for natural gas liquids gathering, fractionation and distribution services.  Natural gas and propane are subject to weather-related seasonal demand.
 
Other products are affected by economic conditions and the demand associated with the various industries that utilize the commodity, such as butanes and natural gasoline, which are used by the refining industry as blending stocks for motor fuel.  Ethane and EP are used by the petrochemical industry to produce chemical products, such as plastic, rubber and synthetic fiber.

Commodity Prices - During 2008, both crude oil and natural gas prices were volatile, with NYMEX crude oil settlement prices ranging from $49.62 to $134.62 per Bbl and NYMEX natural gas settlement prices ranging from $6.47 to $13.11 per MMBtu.


Seasonality - Some of ONEOK Partners’ products, such as natural gas and propane used for heating, are subject to seasonality, resulting in more demand during the months of November through March.  As a result, prices of these products are typically higher during that time period.  Demand has also increased for natural gas in the summer periods as more electric generation is now dependent upon natural gas for fuel.  Other products, such as ethane and EP, are tied to the petrochemical industry, while normal butane, iso-butane and natural gasoline are used by the refining industry as blending stocks.  As a result, the prices of these products are affected by the economic conditions and demand associated with these various industries.

Competition - ONEOK Partners’ natural gas and natural gas liquids pipelines compete directly with other intrastate and interstate pipeline companies and other storage facilities for natural gas and NGLs.  Competition for natural gas transportation services continues to increase as the FERC and state regulatory bodies continue to encourage more competition in the natural gas markets.  Competition among pipelines and storage facilities is based primarily on fees for services, quality of services provided, current and forward natural gas prices and proximity to supply areas and markets.  ONEOK Partners believes that its pipelines and storage assets enable it to effectively compete.

ONEOK Partners’ natural gas gathering and processing business competes for natural gas supplies with major integrated exploration and production companies, pipeline companies and their affiliated marketing companies, national and local natural gas gatherers and processors, and marketers in the Mid-Continent and Rocky Mountain regions.  ONEOK Partners’ gathering and fractionation business competes with other fractionators, storage providers and gatherers for NGL supplies in the Rocky Mountain, Mid-Continent and Gulf Coast regions.  The factors that typically affect ONEOK Partners’ ability to compete for natural gas and NGL supplies are:
·  
producer drilling activity;
·  
the petrochemical industry’s level of capacity utilization and feedstock requirements;
·  
fees charged under our contracts;
·  
pressures maintained on our gathering systems;
·  
location of our gathering systems relative to our competitors;
·  
location of our gathering systems relative to drilling activity;
·  
efficiency and reliability of our operations; and
·  
delivery capabilities that exist in each system, plant and storage location.

ONEOK Partners is responding to these industry conditions by making capital investments to access new supplies, increase gathering and fractionation capacity, increase storage capabilities, improve plant processing flexibility and reduce operating costs, evaluating consolidation opportunities to maximize earnings, selling assets in non-core operating areas and renegotiating unprofitable contracts.  The principal goal of the contract renegotiation effort is to eliminate unprofitable contracts and improve margins, primarily during periods when the gross processing spread is negative.

Government Regulation - The FERC has traditionally maintained that a processing plant is not a facility for the transportation or sale for resale of natural gas in interstate commerce and, therefore, is not subject to jurisdiction under the Natural Gas Act.  Although the FERC has made no specific declaration as to the jurisdictional status of ONEOK Partners’ natural gas processing operations or facilities, ONEOK Partners’ natural gas processing plants are primarily involved in removing NGLs and, therefore, ONEOK Partners believes, its natural gas processing plants are exempt from FERC jurisdiction.  The Natural Gas Act also exempts natural gas gathering facilities from the jurisdiction of the FERC.  Interstate transmission facilities remain subject to FERC jurisdiction.  The FERC has historically distinguished between these two types of facilities, either interstate or intrastate, on a fact-specific basis.  ONEOK Partners believes its gathering facilities and operations meet the criteria used by the FERC for non-jurisdictional gathering facility status.  ONEOK Partners can transport residue gas from its plants to interstate pipelines in accordance with Section 311(a) of the Natural Gas Policy Act.

Oklahoma and Kansas also have statutes regulating, in various degrees, the gathering of natural gas in those states.  In each state, regulation is applied on a case-by-case basis if a complaint is filed against the gatherer with the appropriate state regulatory agency.

ONEOK Partners’ interstate natural gas pipelines are regulated under the Natural Gas Act and Natural Gas Policy Act, which give the FERC jurisdiction to regulate virtually all aspects of the pipeline activities.  ONEOK Partners’ intrastate natural gas transportation assets in Oklahoma, Kansas and Texas are regulated by the OCC, KCC and RRC, respectively.  ONEOK Partners has flexibility in establishing natural gas transportation rates with customers.  However, there are maximum rates that ONEOK Partners can charge its customers in Oklahoma and Kansas.

ONEOK Partners’ proprietary natural gas liquids gathering pipelines in both Oklahoma and Kansas are not regulated by the FERC or the states’ respective corporation commissions.  ONEOK Partners’ remaining natural gas liquids gathering and


distribution pipelines are interstate pipelines regulated by the FERC.  ONEOK Partners transports unfractionated NGLs and NGL products pursuant to filed tariffs.

Additionally, the operations of our assets are regulated by various state and federal government agencies.  See further discussion in the “Environmental and Safety Matters” section.

Unconsolidated Affiliates - Our ONEOK Partners segment has the following unconsolidated affiliates:
·  
50 percent interest in Northern Border Pipeline, which transports natural gas from the Montana-Saskatchewan border near Port Morgan, Montana, to a terminus near North Hayden, Indiana;
·  
49 percent ownership interest in Bighorn Gas Gathering, L.L.C., which operates a major coalbed methane gathering system serving a broad production area in northeast Wyoming;
·  
37 percent ownership interest in Fort Union Gas Gathering, which gathers coalbed methane gas produced in the Powder River Basin and delivers natural gas into the interstate pipeline grid;
·  
35 percent ownership interest in Lost Creek Gathering Company, L.L.C., which gathers natural gas produced from conventional wells in the Wind River Basin of central Wyoming and delivers natural gas into the interstate pipeline grid;
·  
10 percent ownership interest in Venice Energy Services Co., LLC, a gas processing complex near Venice, Louisiana;
·  
50 percent ownership interest in Chisholm Pipeline Company which operates an interstate natural gas liquids pipeline system extending approximately 184 miles from origin points in Oklahoma and Kansas;
·  
48 percent ownership interest in Sycamore Gas System, which is a gathering system with compression located in south central Oklahoma; and
·  
50 percent ownership interest in the Heartland joint venture, which operates a terminal and pipeline systems that transport refined petroleum products in Kansas, Nebraska and Iowa.

See Note O of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional discussion of unconsolidated affiliates.

Distribution

Business Strategy -   Our Distribution segment focuses on increasing the level of sustainable earnings through safe, reliable, environmentally sound and legally compliant distribution operations.

The integrated strategy for our LDCs incorporates:
·  
a rates and regulatory strategy that includes fostering positive relationships with regulators, consistent strategies and synchronized rate case filings;
·  
a focus on the growth of our customer count and rate base through efficient investment in our system while emphasizing safety and cost control; and
·  
providing customer choice programs designed to reduce volumetric sensitivity and create value for our customers.

Our regulatory strategy incorporates rate features that provide strategies for earnings lag, margin protection and risk mitigation.  These strategies include capital recovery mechanisms in Oklahoma, Kansas and portions of Texas.  In Texas, we also have cost of service adjustments that address investments in rate base and changes in expense.  Margin protection strategies include increased customer fixed charges in all three states.  Risk mitigation strategies include fuel related bad-debt recovery mechanisms in Oklahoma, Kansas and portions of Texas.

Description of Business - Our Distribution segment provides natural gas distribution services to more than two million customers in Oklahoma, Kansas and Texas through Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively, each a division of ONEOK.  We serve residential, commercial, industrial and transportation customers in all three states.  In addition, our distribution companies in Oklahoma and Kansas serve wholesale customers, and in Texas we serve public authority customers, such as cities, governmental agencies and schools.

Our operating results are primarily affected by the number of customers, usage and the ability to collect delivery rates that provide a reasonable rate of return on our investment and recovery of our cost of service.  Natural gas costs are passed through to our customers based on the actual cost of gas purchased by the respective distribution companies.  Substantial fluctuations in natural gas sales can occur from year to year without materially or adversely impacting our net margin, since the fluctuations in natural gas costs affect natural gas sales and cost of gas by an equivalent amount.  Higher natural gas costs may cause customers to conserve or, in the case of industrial customers, to use alternative energy sources.  Higher natural gas costs may also adversely impact our accounts receivable collections, resulting in higher bad-debt expense.


The rate structure for Oklahoma Natural Gas includes two service rate options for residential gas sales customers.  Certain high usage customers pay a higher monthly service charge and a lower per dekatherm delivery charge, while lower usage customers pay a lower monthly service charge coupled with a higher per dekatherm delivery charge.  Customers can elect to change service rate options to ensure that they are billed under the alternative that best fits their individual usage, but they must remain on the selected option for a full year after the change is made.

Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service distribute natural gas as public utilities to approximately 87 percent, 70 percent and 14 percent of the distribution markets for Oklahoma, Kansas and Texas, respectively.  Natural gas sold to residential and commercial customers accounts for approximately 79 and 20 percent of natural gas sales, respectively, in Oklahoma; 74 and 19 percent of natural gas sales, respectively, in Kansas; and 66 and 26 percent of natural gas sales, respectively, in Texas.

A franchise, although nonexclusive, is a utility’s right to use the municipal streets, alleys and other public ways for a defined period of time in exchange for a fee.  In management’s opinion, our franchises contain no unduly burdensome restrictions and are sufficient for the transaction of business in the manner in which it is now conducted.

Market Conditions and Seasonality - Supply - In 2008, our Distribution segment purchased 182 Bcf of natural gas supply.  Our gas supply portfolio consists of long-term, seasonal and short-term contracts from a diverse group of suppliers.  These contracts are awarded through competitive bid processes to ensure reliable and competitively priced gas supply.  Our Distribution segment’s natural gas supply is purchased from a combination of direct wellhead production, natural gas processing plants, natural gas marketers and production companies.

We are responsible for acquiring sufficient natural gas supplies, interstate and intrastate pipeline capacity and storage capacity to meet customer requirements.  As such, we must contract for both reliable and adequate supplies and delivery capacity to our distribution system, while considering: (i)   the dynamics of the interstate and intrastate pipeline and storage capacity market; (ii) our peaking facilities and storage and contractual commitments; and (iii)   the demand characteristics of our customer base.

An objective of our supply sourcing strategy is to diversify our supply among multiple production areas and suppliers.  This strategy is designed to protect receipt of supply from being curtailed by physical interruption, possible financial difficulties of a single supplier, natural disasters and other unforeseen force majeure events.

There is an adequate supply of natural gas available to our utility systems, and we do not anticipate problems with securing additional natural gas supply as needed for our customers.  However, if supply shortages occur, each of our LDCs has curtailment tariff provisions in place that provide for: (i) reducing or discontinuing gas service to large industrial users; and (ii) requesting that residential and commercial customers reduce their gas requirements to an amount essential for public health and safety.  In addition, during times of critical supply problems, curtailments of deliveries to customers with firm contracts may be made in accordance with guidelines established by appropriate federal, state and local regulatory agencies.

Natural gas supply requirements are affected by changes in the natural gas consumption pattern of our customers that are driven by factors other than weather.  Natural gas usage per customer may decline as customers change their consumption patterns in response to: (i) more volatile and higher natural gas prices, as discussed above; (ii)   customers’ replacement of older, less efficient gas appliances with more efficient appliances; (iii) more energy-efficient construction; and (iv) fuel switching.  In each jurisdiction in which we operate, changes in customer usage profiles have been reflected in recent rate case proceedings where rates have been adjusted to reflect current customer usage.

In December 2007, Oklahoma Natural Gas was authorized by the OCC to implement a natural gas hedging program as a three-year pilot program, with up to $10 million per year in hedge costs to be recovered from customers.  Kansas Gas Service has a natural gas hedging program in place, subject to annual KCC approval, which is designed to reduce volatility in the natural gas price paid by consumers.  The costs of this program are borne by the Kansas Gas Service customers.  Texas Gas Service also has a natural gas hedging program for certain of its jurisdictions.

In managing our gas supply portfolios, we partially mitigate gas price volatility using a combination of financial derivatives, the triggering of forward prices on certain gas supply contracts, and injecting gas into leased storage capacity.  Our Distribution segment does not utilize financial derivatives for speculative purposes, nor does it have trading operations.  To further mitigate gas price volatility, we utilize 38.3 Bcf of leased storage capacity, which allows gas to be purchased during the off-peak season and stored for use in the winter periods.

Demand - See discussion below under “Seasonality” and “Competition” for factors affecting demand.


Seasonality - Natural gas sales to residential and commercial customers are seasonal, as a substantial portion of their natural gas is used for space heating.  Accordingly, the volume of natural gas sales is normally higher during the heating season (November through March) than in other months of the year.  The sales effect resulting from weather that is above or below normal is substantially offset through weather normalization adjustments (WNA), which are now approved by the regulatory authorities for all of our Oklahoma and Kansas service territories.  WNA allows us to increase customer billing to offset lower gas usage when weather is warmer than normal and decrease customer billing to offset higher gas usage when weather is colder than normal.

Approximately 94 percent of Texas Gas Service’s revenues, including Austin and Galveston, are protected from abnormal weather due to a higher customer charge or WNA clauses.  A higher customer charge is included in the authorized rate design for the jurisdictions of El Paso, north Texas, Rio Grande Valley and Port Arthur to protect customers from abnormal rate fluctuation due to weather.

Competition   -   We can face competition based on customers’ preference for natural gas compared with other energy products, and the comparative prices of those products.  The most significant product competition occurs between natural gas and electricity in the residential and small commercial markets.  We compete for space heating, water heating, cooking and other general energy needs.  Customers and builders typically make the decision for the type of equipment to install at initial installation and use the chosen energy source for the life of the equipment.  The markets in our service territories have become increasingly competitive.  Changes in the competitive position of natural gas relative to electricity and other energy products have the potential of causing a decline in the number of future natural gas customers.

We believe that we must maintain a competitive advantage in order to retain our customers, and, accordingly, we focus on providing safe, reliable, efficient service and controlling costs.  Our Distribution segment is subject to competition from other pipelines for our existing industrial load.  Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service compete for service to large industrial and commercial customers, and competition has and may continue to impact margins.

Under our transportation tariffs, qualifying industrial and commercial customers are able to purchase their natural gas commodity from the supplier of their choice and have us transport it for a fee.  A portion of transportation services provided is at negotiated rates that are generally below the maximum approved transportation tariff rates.  Reduced rate transportation service may be negotiated when a competitive pipeline is in proximity or another viable energy option is available.  Increased competition could potentially lower these rates.  Texas Gas Service files all negotiated transportation service contracts under a separate, confidential tariff at the RRC.

Government Regulation - Rates charged by our Distribution segment for natural gas services are established by the OCC for Oklahoma Natural Gas and by the KCC for Kansas Gas Service.  Texas Gas Service is subject to regulatory oversight by the various municipalities that it serves, which have primary jurisdiction in their respective areas.  Rates in unincorporated areas and all appellate matters are subject to regulatory oversight by the RRC.  Natural gas purchase costs are included in the Purchased Gas Adjustment (PGA) clause rate that is billed to customers.  Our distribution companies do not make a profit on the cost of gas.  Other changes in costs must be recovered through periodic rate adjustments approved by the OCC, KCC, RRC and various municipalities in Texas.  See page 49 for a detailed description of our various regulatory initiatives.

Oklahoma Natural Gas has settled all known claims arising out of long-term gas supply contracts containing “take-or-pay” provisions that purport to require us to pay for volumes of natural gas contracted for but not taken.  The OCC has previously authorized recovery of the accumulated settlement costs over a 20-year period expiring in 2014, or approximately $7.0 million annually, through a combination of a surcharge from customers, revenue from transportation under Section 311(a) of the Natural Gas Policy Act and other intrastate transportation revenues.

Additionally, the operations of our assets are regulated by various state and federal government agencies.  See further discussion in the “Environmental and Safety Matters” section.



Energy Services

Business Strategy - Our Energy Services segment utilizes our network of contracted gas supply and leased transportation and storage assets to provide premium services to our customers.  The asset positions afford us the flexibility to develop innovative, customer-specific demand delivery services for those we serve, at a competitive cost.  With these services and a focus on customer relationships, we expect to attract new customers and retain existing customers that generate recurring margins.

We follow a strategy of optimizing our storage and cross-regional transportation capacity through the application of market knowledge and effective risk management.  We maximize value by actively hedging the time and locational spread risks that are inherent to storage and transportation contracts and will pursue hedging strategies that effectively mitigate these risks.  At the same time, we capitalize on opportunities created by market volatility, weather-related events, supply-demand imbalances and market liquidity inefficiency, which allows us to capture additional margin.  Using market information, we manage these asset-based positions and seek to provide incremental margin in our trading portfolio.

Through our wholesale marketing and risk management capabilities, we are able to be a full-service provider in our retail operations.  We are able to offer a broad range of products and are expanding our markets.  We plan to grow our retail business through internal growth initiatives, as well as expansion into areas that allow retail unbundling.  We manage the commodity price and volumetric risk in these operations through a variety of risk management and hedging activities.

It is our intention to minimize the mark-to-market earnings impact that our forward hedges have on current period earnings. When possible, we implement effective hedging strategies using derivative instruments that qualify as hedges under Statement 133, “Accounting for Derivative Instruments and Hedging Activities,” (Statement 133).

Our Energy Services segment requires working capital to purchase natural gas inventory and to meet cash collateral requirements associated with our risk management activities.  Our inventory purchases and hedging strategies are implemented with consideration given to ONEOK’s overall working capital requirements and liquidity.  Restrictions on our access to working capital may impact our inventory purchases and risk management activities, which could impact our results.

We are assessing the ongoing capital requirements of the wholesale energy business, which includes evaluating our contracted storage and transportation.  This review is focused on ensuring our contracted assets continue to be aligned with our key strategy of providing customer-specific premium delivery services that generate recurring demand revenues and margins.

Description of Business - Our Energy Services segment’s primary focus is to create value for our customers by delivering physical natural gas products and risk management services through our network of contracted transportation and storage capacity and natural gas supply.  These services include meeting our customers’ baseload, swing and peaking natural gas commodity requirements on a year-round basis.  Our contracted storage and transportation capacity connects major supply and demand centers throughout the United States and into Canada.  With these contracted assets, our business strategies include identifying, developing and delivering specialized premium products and services valued by our customers, which are primarily LDCs, electric utilities, and commercial and industrial end users.  Our storage and transportation capacity allows us opportunities to optimize value through our application of market knowledge and risk management skills.

We actively manage the commodity price and volatility risks associated with providing energy risk management services to our customers by executing derivative instruments in accordance with the parameters established in our commodity risk management policy.  The derivative instruments consist of over-the-counter transactions such as forward, swap and option contracts, and NYMEX futures and option contracts.

Numerous risk management opportunities and operational strategies exist that can be implemented through the use of storage facilities and transportation capacity.  We utilize our industry knowledge and expertise in order to capitalize on opportunities that are provided through market volatility.  We utilize our experience to optimize the value of our contracted assets, and we use our risk management and marketing capabilities to both manage risk and to generate additional margins.  We apply a combination of cash flow and fair value hedge accounting when implementing hedging strategies that take advantage of favorable market conditions.  See Note D of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional information.  Additionally, certain non-trading transactions, which are economic hedges of our accrual transactions, such as our storage and transportation contracts, will not qualify for hedge accounting treatment.  These economic hedges receive mark-to-market accounting treatment, as they are derivative contracts and are not designated as part of a hedge relationship.  As a result, the underlying risk being hedged receives accrual accounting treatment, while we use


mark-to-market accounting treatment for the economic hedges.  We cannot predict the earnings fluctuations from mark-to-market accounting, and the impact on earnings could be material.

Our working capital requirements related to our inventory in storage peaked in August 2008, with 61.0 Bcf valued at $614.6 million; this balance had decreased to $451.7 million by December 31, 2008.  During September 2008, we impaired our inventory value; were it not for this impairment, our highest inventory balance would have been in November 2008 with 84.3 Bcf in storage.  In addition, margin requirements can result in increased working capital requirements.  During 2008, our margin requirements with counterparties ranged from zero to $378 million.

Market Conditions and Seasonality - Supply - During periods of high natural gas demand, we utilize storage capacity to supplement natural gas supply volumes to meet our peak day demand obligations or market needs.

Demand - Demand met by our swing and peaking natural gas requirements contracts in our wholesale operation is driven by the extent to which temperatures vary from normal levels.  A significant portion of this business is contracted during the winter period of November through March.  Our retail business’ demand for natural gas is primarily driven by the use of space heating and is significantly impacted by temperature variations.

Seasonality - Due to seasonality of natural gas consumption, storage withdrawals and demand for our products and services, earnings are normally higher during the winter months than the summer months.  Our Energy Services segment’s margins are subject to fluctuations during the year, primarily due to the impact certain seasonal factors have on sales volumes and the price of natural gas.  Natural gas sales volumes are typically higher in the winter heating months than in the summer months, reflecting increased demand due to greater heating requirements and, typically, higher natural gas prices.

Competition - The recent market conditions affecting credit and liquidity have impacted competition by causing some of our competitors, including financial institutions, to either exit the business or scale back their operations.  In response to a competitive marketing environment, our strategy is to concentrate our efforts on providing reliable service during peak demand periods and capturing opportunities created by short-term pricing volatility.  We can effectively compete in the market by utilizing our leased storage and transportation assets.  We continue to focus on building and strengthening supplier and customer relationships to execute our strategy and increase our market presence.

Other

Description of Business - The primary companies in our Other segment include ONEOK Leasing Company and ONEOK Parking Company, L.L.C.

Through ONEOK Leasing Company and ONEOK Parking Company, L.L.C., we own a parking garage and an office building (ONEOK Plaza) in downtown Tulsa, Oklahoma, where our headquarters are located.  ONEOK Leasing Company leases excess office space to others and operates our headquarters office building.  ONEOK Parking Company, L.L.C. owns and operates a parking garage adjacent to our headquarters.

In July 2007, ONEOK Leasing Company gave notice of its intent to exercise its option to purchase ONEOK Plaza on or before the end of the lease term that was set to expire on September 30, 2009.  In March 2008, ONEOK Leasing Company, purchased ONEOK Plaza for a total purchase price of approximately $48 million, which included $17.1 million for the present value of the remaining lease payments and $30.9 million for the base purchase price.

ENVIRONMENTAL AND SAFETY MATTERS

Information about our environmental matters is included in Note K of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

Pipeline Safety - We are subject to United States Department of Transportation regulations, including integrity management regulations.  The Pipeline Safety Improvement Act requires pipeline companies to perform integrity assessments on pipeline segments that pass through densely populated areas or near specifically designated high consequence areas.  To our knowledge, we are in compliance with all material requirements associated with the various pipeline safety regulations.

Air and Water Emissions - The federal Clean Air Act, the federal Clean Water Act and analogous state laws impose restrictions and controls regarding the discharge of pollutants into the air and water in the United States.  Under the Clean Air Act, a federally enforceable operating permit is required for sources of significant air emissions.  We may be required to incur certain capital expenditures for air pollution-control equipment in connection with obtaining or maintaining permits and approvals for sources of air emissions.  The Clean Water Act imposes substantial potential liability for the removal of


pollutants discharged to waters of the United States and remediation of waters affected by such discharge.  To our knowledge, we are in compliance with all material requirements associated with the various regulations.

The United States Congress is actively considering legislation to reduce emissions of greenhouse gases, including carbon dioxide and methane.  In addition, state and regional initiatives to regulate greenhouse gas emissions are underway.  We are monitoring federal and state legislation to assess the potential impact on our operations.  Our most recent calculation of direct greenhouse gas emissions for ONEOK and ONEOK Partners is estimated to be less than 6 million metric tons of carbon dioxide equivalents on an annual basis.  We will continue efforts to quantify our direct greenhouse gas emissions and will report such emissions as required by any mandatory reporting rule, including the rules anticipated to be issued by the EPA in mid-2009.

Superfund - The Comprehensive Environmental Response, Compensation and Liability Act, also known as CERCLA or Superfund, imposes liability, without regard to fault or the legality of the original act, on certain classes of persons who contributed to the release of a hazardous substance into the environment.  These persons include the owner or operator of a facility where the release occurred and companies that disposed or arranged for the disposal of the hazardous substances found at the facility.  Under CERCLA, these persons may be liable for the costs of cleaning up the hazardous substances released into the environment, damages to natural resources and the costs of certain health studies.

Chemical Site Security - The United States Department of Homeland Security (Homeland Security) released an interim rule in April 2007 that requires companies to provide reports on sites where certain chemicals, including many hydrocarbon products, are stored.  We completed the Homeland Security assessments and our facilities were subsequently assigned to one of four risk-based tiers ranging from high (Tier 1) to low (Tier 4) risk, or not tiered at all due to low risk.  A majority of our facilities were not tiered.  We are waiting for Homeland Security’s analysis to determine if any of the tiered facilities will require Site Security Plans and possible physical security enhancements.

Climate Change - Our environmental and climate change strategy focuses on taking steps to minimize the impact of our operations on the environment.  These strategies include: (i) developing and maintaining an accurate greenhouse gas emissions inventory, according to rules anticipated to be issued by the EPA in mid-2009; (ii) improving the efficiency of our various pipelines, natural gas processing facilities and natural gas liquids fractionation facilities; (iii) following developing technologies for emission control; (iv) following developing technologies to capture carbon dioxide to keep it from reaching the atmosphere; and (v) analyzing options for future energy investment.

Currently, certain subsidiaries of ONEOK Partners participate in the Processing and Transmission sectors and LDCs in our Distribution segment participate in the Distribution sector of the EPA’s Natural Gas STAR Program to voluntarily reduce methane emissions.  A subsidiary in our ONEOK Partners’ segment was honored in 2008 as the “Natural Gas STAR Gathering and Processing Partner of the Year” for its efforts to positively address environmental issues through voluntary implementation of emission-reduction opportunities.  In addition, we continue to focus on maintaining low rates of lost-and-unaccounted-for methane gas through expanded implementation of best practices to limit the release of methane during pipeline and facility maintenance and operations.  Our most recent calculation of our annual lost-and-unaccounted-for natural gas, for all of our business operations, is less than 1 percent of total throughput.

EMPLOYEES

We employed 4,742 people at January 31, 2009, including 739 people employed by Kansas Gas Service, who were subject to collective bargaining contracts.  The following table sets forth our contracts with collective bargaining units at January 31, 2009.


Union
Employees
Contract Expires
United Steelworkers of America
414
   
June 30, 2009
International Union of Operating Engineers
13
   
June 30, 2009
International Brotherhood of Electrical Workers
312
   
June 30, 2010



EXECUTIVE OFFICERS

All executive officers are elected at the annual meeting of our Board of Directors and serve for a period of one year or until successors are duly elected.  Our executive officers listed below include the officers who have been designated by our Board of Directors as our Section 16 executive officers.
 
Name and Position
Age
Business Experience in Past Five Years
John W. Gibson
56
2007 to present
Chief Executive Officer
Chief Executive Officer
 
2006 to present
Member of the Board of Directors
and Member of the Board of Directors
 
2006
President and Chief Operating Officer of ONEOK Partners, L.P.
   
2005 to 2006
President, ONEOK Energy Companies
   
2000 to 2005
President, Energy
Jim Kneale
57
2007 to present
President and Chief Operating Officer
President and Chief Operating Officer
 
2004 to 2006
Executive Vice President - Finance and Administration and Chief Financial Officer
   
2001 to 2004
Senior Vice President, Treasurer and Chief Financial Officer
Curtis L. Dinan
41
2007 to present
Senior Vice President, Chief Financial Officer and Treasurer
Senior Vice President,
 
2004 to 2006
Senior Vice President and Chief Accounting Officer
Chief Financial Officer and Treasurer
 
2004
Vice President and Chief Accounting Officer
   
2002 to 2004
Assurance and Business Advisory Partner, Grant Thornton, LLP
John R. Barker
61
2004 to present
Senior Vice President and General Counsel
Senior Vice President and
 
1994 to 2004
Stockholder, President and Director, Gable & Gotwals
General Counsel
     
Caron A. Lawhorn
47
2007 to present
Senior Vice President and Chief Accounting Officer
Senior Vice President and
 
2005 to 2006
Senior Vice President, Financial Services and Treasurer
Chief Accounting Officer
 
2004 to 2005
Vice President and Controller
   
2003 to 2004
Vice President of Audit and Risk Control
 
No family relationships exist between any of the executive officers, nor is there any arrangement or understanding between any executive officer and any other person pursuant to which the officer was selected.

AVAILABLE INFORMATION

We make available on our Web site copies of our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, amendments to those reports filed or furnished to the SEC pursuant to Section 13(a) or 15(d) of the Exchange Act and reports of holdings of our securities filed by our officers and directors under Section 16 of the Exchange Act as soon as reasonably practicable after filing such material electronically or otherwise furnishing it to the SEC.  Copies of our Code of Business Conduct, Corporate Governance Guidelines and Director Independence Guidelines are also available on our Web site, and we will make available, free of charge, copies of these documents upon request.  However, our Web site and any contents thereof are not incorporated by reference into this document.

ITEM 1A.                      RISK FACTORS

Our investors should consider the following risks that could affect us and our business.  Although we have tried to discuss key factors, our investors need to be aware that other risks may prove to be important in the future.  New risks may emerge at any time, and we cannot predict such risks or estimate the extent to which they may affect our financial performance.  Investors should carefully consider the following discussion of risks and the other information included or incorporated by reference in this Annual Report on Form 10-K, including “Forward-Looking Statements,” which are included in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation.
 
RISK FACTORS INHERENT IN OUR BUSINESS

Current levels of market volatility are unprecedented.

The capital and credit markets have been experiencing volatility and disruption.  During the fourth quarter of 2008, the volatility and disruption reached unprecedented levels.  In many cases, the capital markets have exerted downward pressure on equity prices and reduced the credit capacity for certain companies.  Our ability to grow could be constrained if we do not have regular access to the capital and credit markets.  If current levels of market disruption and volatility continue or worsen, our access to capital and credit markets could be disrupted, making growth through acquisitions and development projects difficult or impractical to pursue until such time as markets stabilize.


Our operating results may be adversely affected by unfavorable economic and market conditions.

Economic conditions worldwide have from time to time contributed to slowdowns in the oil and gas industry, as well as in the specific segments and markets in which we operate, resulting in reduced demand and increased price competition for our products and services.  Our operating results in one or more geographic regions may also be affected by uncertain or changing economic conditions within that region.  Volatility in commodity prices might have an impact on many of our customers, which, in turn, could have a negative impact on their ability to meet their obligations to us.  If global economic and market conditions (including volatility in commodity markets), or economic conditions in the United States or other key markets, remain uncertain or persist, spread or deteriorate further, we may experience material impacts on our business, financial condition and results of operations.

The recent downturn in the credit markets has increased the cost of borrowing and has made financing difficult to obtain, each of which may have a material adverse effect on our results of operations and business.

Recent events in the financial markets have had an adverse impact on the credit markets.  As a result, credit has become more expensive and difficult to obtain.  Some lenders are imposing more stringent restrictions on the terms of credit and there may be a general reduction in the amount of credit available in the markets in which we conduct business.   The negative impact of the tightening of the credit markets may have a material adverse effect on us resulting from, but not limited to, an inability to obtain credit necessary to expand facilities or finance the acquisition of assets on favorable terms, if at all, increased financing costs or financing with increasingly restrictive covenants.

Our cash flow depends heavily on the earnings and distributions of ONEOK Partners.

Our partnership interest in ONEOK Partners is one of our largest cash-generating assets.  Therefore, our cash flow is heavily dependent upon the ability of ONEOK Partners to make distributions to its partners.  A significant decline in ONEOK Partners’ earnings and/or cash distributions would have a corresponding negative impact on us.  For information on the risk factors inherent in the business of ONEOK Partners, see the section below entitled “Risk Factors Related to ONEOK Partners’ Business” and the ONEOK Partners 2008 Annual Report on Form 10-K.

Some of our nonregulated businesses have a higher level of risk than our regulated businesses.
 
Some of our nonregulated operations, which include ONEOK Partners’ gathering and processing, natural gas liquids gathering and fractionation, and our energy services businesses, have a higher level of risk than our regulated operations, which include our distribution and ONEOK Partners’ natural gas and natural gas liquids pipelines businesses.  We and ONEOK Partners expect to continue investing in natural gas and natural gas liquids projects and other related projects, some or all of which may involve nonregulated businesses or assets.  These projects could involve risks associated with operational factors, such as competition and dependence on certain suppliers and customers, and financial, economic and political factors, such as rapid and significant changes in commodity prices, the cost and availability of capital and counterparty risk, including the inability of a counterparty, customer or supplier to fulfill a contractual obligation.
 
Our LDCs have recorded certain assets that may not be recoverable from our customers.

Accounting policies for our LDCs permit certain assets that result from the regulatory process to be recorded on our balance sheet that could not be recorded under GAAP for nonregulated entities.  We consider factors such as rate orders from regulators, previous rate orders for substantially similar costs, written approval from the regulators and analysis of recoverability from internal and external legal counsel to determine the probability of future recovery of these assets.  If we determine future recovery is no longer probable, we would be required to write off the regulatory assets at that time.

Terrorist attacks aimed at our facilities could adversely affect our business.

Since the September 11, 2001, terrorist attacks, the United States government has issued warnings that energy assets, specifically the nation’s pipeline infrastructure, may be future targets of terrorist organizations.  These developments may subject our operations to increased risks.  Any future terrorist attack that may target our facilities, those of our customers and, in some cases, those of other pipelines, could have a material adverse effect on our business.

Our businesses are subject to market and credit risks.
 
We are exposed to market and credit risks in all of our operations.  To minimize the risk of commodity price fluctuations, we periodically enter into derivative transactions to hedge anticipated purchases and sales of natural gas, NGLs, crude oil, fuel requirements and firm transportation commitments.  Interest-rate swaps are also used to manage interest-rate risk.  Currency


swaps are used to mitigate unexpected changes that may occur in anticipated revenue streams of our Canadian natural gas sales and purchases driven by currency rate fluctuations.  However, financial derivative instrument contracts do not eliminate the risks.  Specifically, such risks include commodity price changes, market supply shortages, interest rate changes and counterparty default.  The impact of these variables could result in our inability to fulfill contractual obligations, significantly higher energy or fuel costs relative to corresponding sales contracts, or increased interest expense.
 
We are subject to the risk of loss resulting from nonpayment and/or nonperformance by customers of our Energy Services segment.  The customers of our Energy Services segment are predominantly LDCs, industrial customers, natural gas producers and marketers that may experience deterioration of their financial condition as a result of changing market conditions or financial difficulties that could impact their creditworthiness or ability to pay for our services.  Although we attempt to obtain adequate security for these risks, if we fail to adequately assess the creditworthiness of existing or future customers, unanticipated deterioration in their creditworthiness and any resulting nonpayment and/or nonperformance could adversely impact results of operations for our Energy Services segment.  In addition, if any of our Energy Services segment’s customers filed for bankruptcy protection, we may not be able to recover amounts owed, which would negatively impact the results of operations for our Energy Services segment.

Increased competition could have a significant adverse financial impact on us.
 
The natural gas and natural gas liquids industries are expected to remain highly competitive, resulting from deregulation and other initiatives being pursued by the industry and regulatory agencies that allow customers increased options for energy supplies and service.  The demand for natural gas and NGLs is primarily a function of commodity prices, including prices for alternative energy sources, customer usage rates, weather, economic conditions and service costs.  Our ability to compete also depends on a number of other factors, including competition from other pipelines for our existing load, the efficiency, quality and reliability of the services we provide, and competition for throughput for our gathering systems and plants.
 
We cannot predict when we will be subject to changes in legislation or regulation, nor can we predict the impact of these changes on our financial position, results of operations or cash flows.  Although we believe our businesses are positioned to compete effectively in the energy market, there are no assurances that this will be true in the future.
 
We may not be able to successfully make additional strategic acquisitions or integrate businesses we acquire into our operations.
 
Our ability to successfully make strategic acquisitions and investments will depend on: (i) the extent to which acquisitions and investment opportunities become available; (ii) our success in bidding for the opportunities that do become available; (iii) regulatory approval, if required, of the acquisitions on favorable terms; and (iv) our access to capital, including our ability to use our equity in acquisitions or investments, and the terms upon which we obtain capital.  If we are unable to make strategic investments and acquisitions, we may be unable to grow.  If we are unable to successfully integrate new businesses into our operations, we could experience increased costs and losses on our investments.
 
Acquisitions that appear to be accretive may nevertheless reduce our cash from operations on a per share basis.

Any acquisition involves potential risks that may include, among other things:
·  
mistaken assumptions about volumes, revenues and costs, including synergies;
·  
an inability to successfully integrate the businesses we acquire;
·  
decrease in our liquidity as a result of our using a significant portion of our available cash or borrowing capacity to finance the acquisition;
·  
a significant increase in our interest expense or financial leverage if we incur additional debt to finance the acquisition;
·  
the assumption of unknown liabilities for which we are not indemnified or for which our indemnity is inadequate;
·  
an inability to hire, train or retain qualified personnel to manage and operate the acquired business and assets;
·  
limitations on rights to indemnity from the seller;
·  
mistaken assumptions about the overall costs of equity or debt;
·  
the diversion of management’s and employees’ attention from other business concerns;
·  
unforeseen difficulties operating in new product areas or new geographic areas; 
·  
increased regulatory burdens;
·  
customer or key employee losses at an acquired business; and
·  
increased regulatory requirements.


If we consummate any future acquisitions, our capitalization and results of operations may change significantly, and investors will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in determining the application of these funds and other resources.

Any reduction in our credit ratings could materially and adversely affect our business, financial condition, liquidity and results of operations.
 
Our long-term senior unsecured debt has been assigned an investment-grade rating by S&P of “BBB” (Stable) and Moody’s of “Baa2” (Stable).  However, we cannot provide assurance that any of our current ratings will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in its judgment, circumstances in the future so warrant.  Specifically, if S&P or Moody’s were to downgrade our long-term rating, particularly below investment grade, our borrowing costs would increase, which would adversely affect our financial results, and our potential pool of investors and funding sources could decrease.   If S&P or Moody’s were to downgrade the long-term ratings of ONEOK Partners below investment grade, ONEOK Partners would, under certain circumstances, be required to offer to repurchase certain of its senior notes.  Further, if our short-term ratings were to fall below A-2 (capacity to meet its financial commitment on the obligation is satisfactory) or P-2 (strong ability to repay short-term debt obligations), the current ratings assigned by S&P and Moody’s, respectively, it could significantly limit our access to the commercial paper market.  Any such downgrade of our long- or short-term ratings could increase our cost of capital and reduce the availability of capital and, thus, have a material adverse effect on our business, financial condition, liquidity and results of operations.  Ratings from credit agencies are not recommendations to buy, sell or hold our securities.  Each rating should be evaluated independently of any other rating.
 
A downgrade in our credit ratings below investment grade would negatively affect the operations of our Energy Services segment.  If our credit ratings fall below investment grade, ratings triggers and/or adequate assurance clauses in many of our financial and wholesale physical contracts would be in effect.  A ratings trigger or adequate assurance clause gives a counterparty the right to suspend or terminate the agreement unless margin thresholds are met.  The additional increase in capital required to support our Energy Services segment would negatively impact our ability to compete, as well as our ability to actively manage the risk associated with existing storage and transportation contracts.

Our indebtedness could impair our financial condition and our ability to fulfill our other obligations.

As of December 31, 2008, we had total indebtedness for borrowed money of approximately $3.0 billion, which excludes the debt of ONEOK Partners.  Our indebtedness could have significant consequences.  For example, it could:
·  
make it more difficult for us to satisfy our obligations with respect to our notes and our other indebtedness due to the increased debt-service obligations, which could in turn result in an event of default on such other indebtedness or our notes;
·  
impair our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions or general business purposes;
·  
diminish our ability to withstand a downturn in our business or the economy;
·  
require us to dedicate a substantial portion of our cash flow from operations to debt service payments, reducing the availability of cash for working capital, capital expenditures, acquisitions, or general purposes;
·  
limit our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate; and
·  
place us at a competitive disadvantage compared with our competitors that have proportionately less debt.

We are not prohibited under the indentures governing our senior notes from incurring additional indebtedness, but our debt agreements do subject us to certain operational limitations summarized in the next paragraph.  If we incur significant additional indebtedness, it could worsen the negative consequences mentioned above and could adversely affect our ability to repay our other indebtedness.

Our revolving debt agreements with banks contain provisions that restrict our ability to finance future operations or capital needs or to expand or pursue our business activities.  For example, certain of these agreements contain provisions that, among other things, limit our ability to make loans or investments, make material changes to the nature of our business, merge, consolidate or engage in asset sales, grant liens, or make negative pledges.  Certain of these agreements also require us to maintain certain financial ratios, which limits the amount of additional indebtedness we can incur.  These restrictions could result in higher costs of borrowing and impair our ability to generate additional cash.  Future financing agreements we may enter into may contain similar or more restrictive covenants.

If we are unable to meet our debt-service obligations, we could be forced to restructure or refinance our indebtedness, seek additional equity capital or sell assets.  We may be unable to obtain financing or sell assets on satisfactory terms, or at all.


We are subject to comprehensive energy regulation by governmental agencies, and the recovery of our costs is dependent on regulatory action.
 
We are subject to comprehensive regulation by several federal, state and municipal utility regulatory agencies, which significantly influences our operating environment and our ability to recover our costs from utility customers.  The utility regulatory authorities in Oklahoma, Kansas and Texas regulate many aspects of our utility operations, including customer service and the rates that we can charge customers.  Federal, state and local agencies also have jurisdiction over many of our other activities, including regulation by the FERC of our storage and interstate pipeline assets.  The profitability of our regulated operations is dependent on our ability to pass costs related to providing energy and other commodities through to our customers.  The regulatory environment applicable to our regulated businesses could impair our ability to recover costs historically absorbed by our customers.
 
We are unable to predict the impact that the future regulatory activities of these agencies will have on our operating results.  Changes in regulations or the imposition of additional regulations could have an adverse impact on our business, financial condition and results of operations.
 
Our business is subject to increased regulatory oversight and potential penalties.

The natural gas industry historically has been heavily regulated; therefore, there is no assurance that a more stringent regulatory approach will not be pursued by the FERC and United States Congress, especially in light of previous market power abuse by certain companies engaged in interstate commerce.  In response to this issue, the United States Congress, in the Energy Policy Act of 2005 (EPACT), developed requirements intended to ensure that the energy market is not impacted by the exercise of market power or manipulative conduct.  The FERC then adopted the Market Manipulation Rules to implement the authority granted under EPACT.  These rules are intended to prohibit fraud and manipulation and are subject to broad interpretation.  EPACT also gave the FERC increased penalty authority for violations of these rules, as well as other FERC rules.

Demand for services of our Distribution and Energy Services segments and for certain of ONEOK Partners’ products is highly weather sensitive and seasonal.

The demand for natural gas and for certain of ONEOK Partners’ products, such as propane, is weather sensitive and seasonal, with a significant portion of revenues derived from sales to retail marketers for heating during the winter months.  Weather conditions directly influence the volume of, among other things, natural gas and propane delivered to customers.  Deviations in weather from normal levels and the seasonal nature of certain of our segments’ business can create large variations in earnings and short-term cash requirements.

We are subject to environmental regulations that could be difficult and costly to comply with.
 
We are subject to multiple environmental laws and regulations affecting many aspects of present and future operations, including air emissions, water quality, wastewater discharges, solid and hazardous wastes and hazardous material and substance management.  These laws and regulations generally require us to obtain and comply with a wide variety of environmental registrations, licenses, permits, inspections and other approvals.  Failure to comply with these laws, regulations, permits and licenses may expose us to fines, penalties and/or interruptions in our operations that could be material to the results of operations.  If a leak or spill of hazardous substance occurs from our lines or facilities, in the process of transporting natural gas or NGLs, or at any facility that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including investigation and clean-up costs, which could materially affect our results of operations and cash flows.  In addition, emission controls required under the federal Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at our facilities.  We cannot assure that existing environmental regulations will not be revised or that new regulations will not be adopted or become applicable to us.  Revised or additional regulations that result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from customers, could have a material adverse effect on our business, financial condition and results of operations.  For further discussion on this topic, see Note K of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

We are subject to risks that could limit our access to capital, thereby increasing our costs and adversely affecting our results of operations.
 
We have grown rapidly in the last several years as a result of acquisitions.  Further acquisitions may require additional external capital.  If we are not able to access capital at competitive rates, our strategy of enhancing the earnings potential of our existing assets, including through acquisitions of complementary assets or businesses, will be adversely affected.  A


number of factors could adversely affect our ability to access capital, including: (i) general economic conditions; (ii) capital market conditions; (iii) market prices for natural gas, NGLs and other hydrocarbons; (iv) the overall health of the energy and related industries; (v) our ability to maintain our investment-grade credit ratings; and (vi) our capital structure.  Much of our business is capital intensive, and achievement of our long-term growth targets is dependent, at least in part, upon our ability to access capital at rates and on terms we determine to be attractive.  If our ability to access capital becomes significantly constrained, our interest costs will likely increase and our financial condition and future results of operations could be significantly harmed.
 
Energy efficiency and technological advances may affect the demand for natural gas and adversely affect our operating results.

The national trend toward increased conservation and technological advances, including installation of improved insulation and the development of more efficient furnaces and other heating devices, may decrease the demand for natural gas by retail customers.  More strict conservation measures in the future or technological advances in heating, conservation, energy generation or other devices could adversely affect our operations.

The cost of providing pension and postretirement health care benefits to eligible employees and qualified retirees is subject to changes in pension fund values and changing demographics and may increase.

We have a defined benefit pension plan for certain employees and postretirement welfare plans that provide postretirement medical and life insurance benefits to certain employees who retire with at least five years of service.  The cost of providing these benefits to eligible current and former employees is subject to changes in the market value of our pension and postretirement benefit plan assets, changing demographics, including longer life expectancy of plan participants and their beneficiaries and changes in health care costs.

Any sustained declines in equity markets and reductions in bond yields may have a material adverse effect on the value of our pension and postretirement benefit plan assets.  In these circumstances, cash contributions to our pension plans may be required.
 
Our business could be adversely affected by strikes or work stoppages by our unionized employees.
 
As of January 31, 2009, 739 of our 4,742 employees were represented by collective bargaining units under collective bargaining agreements.  We are involved periodically in discussions with collective bargaining units representing some of our employees to negotiate or renegotiate labor agreements.  We cannot predict the results of these negotiations, including whether any failure to reach new agreements will have a negative effect on our business, financial condition and results of operations or whether we will be able to reach any agreement with the collective bargaining units.  Any failure to reach agreement on new labor contracts might result in a work stoppage.  Any future work stoppage could, depending on the operations and the length of the work stoppage, have a material adverse effect on our business, financial condition and results of certain operations.
 
We may face significant costs to comply with the regulation of greenhouse gas emissions.

Global warming is a significant concern for the energy industry.  Various federal and state legislative proposals have been introduced to regulate the emission of greenhouse gases, particularly carbon dioxide and methane, and the United States Supreme Court has ruled that carbon dioxide is a pollutant subject to regulation by the EPA.  In addition, there have been international efforts seeking legally binding reductions in emissions of greenhouse gases.

We believe it is likely that future governmental legislation and/or regulation may require us either to limit greenhouse gas emissions from our operations or to purchase allowances for such emissions.  However, we cannot predict precisely what form these future regulations will take, the stringency of the regulations or when they will become effective.  Several bills have been introduced in the United States Congress that would compel carbon dioxide emission reductions.  Previously considered proposals have included, among other things, limitations on the amount of greenhouse gases that can be emitted (so called “caps”) together with systems of emissions allowances.  This type of system could require us to reduce emissions, even though the technology is not currently available for efficient reduction, or to purchase allowances for such emissions.  Emissions also could be taxed independently of limits.

In addition to activities on the federal level, state and regional initiatives could also lead to the regulation of greenhouse gas emissions sooner and/or independent of federal regulation.  These regulations could be more stringent than any federal legislation that is adopted.


Future legislation and/or regulation designed to reduce greenhouse gas emissions could make some of our activities uneconomic to maintain or operate and could affect future results of operations, cash flows or financial condition if such costs are not recovered through regulated rates.

We continue to monitor legislative and regulatory developments in this area.  Although we expect the regulation of greenhouse gas emissions may have a material impact on our operations and rates, we believe it is premature to attempt to quantify the potential costs of the impacts.
 
We do not fully hedge against price changes in commodities.  This could result in decreased revenues and increased costs, thereby resulting in lower margins and adversely affecting our results of operations.
 
Certain of our nonregulated businesses are exposed to market risk and the impact of market price fluctuations of natural gas, NGLs and crude oil.  Market risk refers to the risk of loss of cash flows and future earnings arising from adverse changes in commodity energy prices.  Our Energy Services segment’s primary exposures arise from fixed-price physical purchase or sale agreements that extend for periods of up to five years and natural gas in storage.  Our ONEOK Partners segment’s primary exposures arise from commodity prices with respect to processing agreements and the differentials between NGL and natural gas prices with respect to natural gas and NGL transportation, fractionation and exchange agreements, as well as the differential between the individual NGL products and the differentials in natural gas and NGLs in storage utilized in our operations.  Our ONEOK Partners and Energy Services segments are also exposed to the risk of changing prices or the cost of transportation resulting from purchasing natural gas or NGLs at one location and selling it at another (referred to as basis risk).  To minimize the risk from market price fluctuations of natural gas, NGLs and crude oil, we use commodity derivative instruments such as futures contracts, swaps and options to manage market risk of existing or anticipated purchases and sales of natural gas, NGLs and crude oil.  We adhere to policies and procedures that monitor our exposure to market risk from open positions.  However, we do not fully hedge against commodity price changes, and therefore, we retain some exposure to market risk.  Accordingly, any adverse changes to commodity prices could result in decreased revenue and increased costs.
 
Our Distribution segment uses storage to minimize the volatility of natural gas costs for our customers by storing natural gas in periods of low demand for consumption in peak demand periods.  In addition, various natural gas supply contracts allow us the option to convert index-based purchases to fixed prices.  Also, we use derivative instruments to hedge the cost of anticipated natural gas purchases during the winter heating months to protect customers from upward volatility in the market price of natural gas.

Federal, state and local jurisdictions may challenge our tax return positions.

The positions taken in our federal and state tax return filings require significant judgments, use of estimates and the interpretation and application of complex tax laws.  Significant judgment is also required in assessing the timing and amounts of deductible and taxable items.  Despite management’s belief that our tax return positions are fully supportable, certain positions may be successfully challenged by federal, state and local jurisdictions.

Although we control ONEOK Partners, we may have conflicts of interest with ONEOK Partners which could subject us to claims that we have breached our fiduciary duty to ONEOK Partners and its unitholders.

We are the sole general partner and own 47.7 percent of ONEOK Partners.  Conflicts of interest may arise between us and ONEOK Partners and its unitholders.  In resolving these conflicts, we may favor our own interests and the interests of our affiliates over the interests of ONEOK Partners and its unitholders as long as the resolution does not conflict with the ONEOK Partners’ partnership agreement or our fiduciary duties to ONEOK Partners and its unitholders.

We are subject to physical and financial risks associated with climate change.

There is a growing belief that emissions of greenhouse gases may be linked to global climate change.  Climate change creates physical and financial risk.  Our customers’ energy needs vary with weather conditions, primarily temperature and humidity.  For residential customers, heating and cooling represent their largest energy use.  To the extent weather conditions are affected by climate change, customers’ energy use could increase or decrease depending on the duration and magnitude of any changes.  Increased energy use due to weather changes may require us to invest in more pipeline and other infrastructure to serve increased demand.  A decrease in energy use due to weather changes may affect our financial condition, through decreased revenues.  Extreme weather conditions in general require more system backup, adding to costs, and can contribute to increased system stresses, including service interruptions.  Weather conditions outside of our service territory could also have an impact on our revenues.  Severe weather impacts our service territories primarily through hurricanes, thunderstorms, tornadoes and snow or ice storms.  To the extent the frequency of extreme weather events increases, this could increase our cost of providing service.  We may not be able to pass on the higher costs to our customers or recover all the costs related to


mitigating these physical risks.  To the extent financial markets view climate change and emissions of greenhouse gases as a financial risk, this could negatively affect our ability to access capital markets or cause us to receive less favorable terms and conditions in future financings.

We may be subject to legislative and regulatory responses to climate change, with which compliance could be difficult and costly.

Legislative and regulatory responses related to climate change create financial risk.  Increased public awareness and concern may result in more state, regional and/or federal requirements to reduce or mitigate the emission of greenhouse gases.  Numerous states have announced or adopted programs to stabilize and reduce greenhouse gases and federal legislation has been introduced in both houses of the United States Congress.  Our pipelines, natural gas processing facilities and natural gas liquids fractionation facilities will potentially be subject to regulation under climate change policies introduced at either the state or federal level within the next few years.  We may not be able to pass on the higher costs to our customers or recover all costs related to complying with climate change regulatory requirements, which could have a material adverse effect on our results of operations, cash flows or financial condition.

RISK FACTORS RELATED TO ONEOK PARTNERS’ BUSINESS

The volatility of natural gas, crude oil and NGL prices could adversely affect ONEOK Partners’ cash flow.

A significant portion of ONEOK Partners’ revenues are derived from the sale of commodities received as payment for its natural gas gathering and processing services, for transportation and storage of natural gas and NGLs, and for the fractionation of NGLs.  As a result, ONEOK Partners is sensitive to commodity price fluctuations.  Commodity prices have been volatile and are likely to continue to be so in the future.  Recent significant and steep declines in commodity prices and compressions in commodity price differentials could have material negative impacts on ONEOK Partners’ financial results.  The prices ONEOK Partners receives for its commodities are subject to wide fluctuations in response to a variety of factors beyond ONEOK Partners’ control, including the following:
·  
overall domestic and global economic conditions;
·  
relatively minor changes in the supply of, and demand for, domestic and foreign energy;
·  
market uncertainty;
·  
the availability and cost of transportation capacity;
·  
the level of consumer product demand;
·  
geopolitical conditions impacting supply and demand for natural gas and crude oil;
·  
weather conditions;
·  
domestic and foreign governmental regulations and taxes;
·  
the price and availability of alternative fuels;
·  
speculation in the commodity futures markets;
·  
overall domestic and global economic conditions;
·  
the price of natural gas, crude oil, NGL and liquefied natural gas imports; and
·  
the effect of worldwide energy conservation measures.

These external factors and the volatile nature of the energy markets make it difficult to reliably estimate future prices of commodities and the impact commodity price fluctuations have on our customers and their need for our services.  As commodity prices decline, ONEOK Partners is paid less for its commodities, thereby reducing its cash flow.  In addition, production and related volumes could also decline.

ONEOK Partners’ use of financial instruments to hedge market risk may result in reduced income.

ONEOK Partners utilizes financial instruments to mitigate its exposure to interest rate and commodity price fluctuations.  Hedging instruments that are used to reduce its exposure to interest rate fluctuations could expose it to risk of financial loss where it has contracted for variable-rate swap instruments to hedge fixed-rate instruments and the variable rate exceeds the fixed rate.  In addition, these hedging arrangements may limit the benefit ONEOK Partners would otherwise receive if it has contracted for fixed-rate swap agreements to hedge variable-rate instruments and the variable rate falls below the fixed rate.  Hedging arrangements that are used to reduce ONEOK Partners’ exposure to commodity price fluctuations may limit the benefit ONEOK Partners would otherwise receive if market prices for natural gas and NGLs exceed the stated price in the hedge instrument for these commodities.



ONEOK Partners’ inability to execute growth and development projects and acquire new assets could reduce cash distributions to its unitholders and to ONEOK.

ONEOK Partners’ primary business objectives are to generate cash flow sufficient to pay quarterly cash distributions to unitholders and to increase quarterly cash distributions over time.  ONEOK Partners’ ability to maintain and grow its distributions to unitholders, including ONEOK, depends on the growth of its existing businesses and strategic acquisitions.  Accordingly, if ONEOK Partners is unable to implement business development opportunities and finance such activities on economically acceptable terms, its future growth will be limited, which could adversely impact its and our results of operations and cash flows.

Growing ONEOK Partners’ business by constructing new pipelines and plants or making modifications to its existing facilities subjects ONEOK Partners to construction risks and risks that adequate natural gas or NGL supplies will not be available upon completion of the facilities.

One of the ways ONEOK Partners intends to grow its business is through the construction of new pipelines and new gathering, processing, storage and fractionation facilities and through modifications to ONEOK Partners’ existing pipelines and existing gathering, processing, storage and fractionation facilities.  The construction and modification of pipelines and gathering, processing, storage and fractionation facilities requires the expenditure of significant amounts of capital, which may exceed ONEOK Partners’ estimates, and involves numerous regulatory, environmental, political and legal uncertainties.  Construction projects in ONEOK Partners’ industry may increase demand for labor, materials and rights of way, which, may, in turn, impact ONEOK Partners’ costs and schedule.  If ONEOK Partners undertakes these projects, it may not be able to complete them on schedule or at the budgeted cost.  Additionally, ONEOK Partners’ revenues may not increase immediately upon the expenditure of funds on a particular project.  For instance, if ONEOK Partners builds a new pipeline, the construction will occur over an extended period of time, and ONEOK Partners will not receive any material increases in revenues until after completion of the project.  ONEOK Partners may have only limited natural gas or NGL supplies committed to these facilities prior to their construction.  Additionally, ONEOK Partners may construct facilities to capture anticipated future growth in production in a region in which anticipated production growth does not materialize.  ONEOK Partners may also rely on estimates of proved reserves in ONEOK Partners’ decision to construct new pipelines and facilities, which may prove to be inaccurate because there are numerous uncertainties inherent in estimating quantities of proved reserves.  As a result, new facilities may not be able to attract enough natural gas or NGLs to achieve ONEOK Partners’ expected investment return, which could adversely affect ONEOK Partners’ results of operations and financial condition.

ONEOK Partners does not own all of the land on which its pipelines and facilities are located, which could disrupt its operations.

ONEOK Partners does not own all of the land on which certain of its pipelines and facilities are located, and is, therefore, subject to the risk of increased costs to maintain necessary land use.  ONEOK Partners obtains the rights to construct and operate certain of its pipelines and related facilities on land owned by third parties and governmental agencies for a specific period of time.  ONEOK Partners’ loss of these rights, through its inability to renew right-of-way contracts, or increased costs to renew such rights, could have a material adverse effect on our financial condition, results of operations and cash flows.

ONEOK Partners’ operations are subject to operational hazards and unforeseen interruptions, which could adversely affect its business and for which ONEOK Partners may not be adequately insured.

ONEOK Partners’ operations are subject to all of the risks and hazards typically associated with the operation of natural gas and natural gas liquids gathering and transportation pipelines, storage facilities and processing and fractionation plants.  Operating risks include, but are not limited to, leaks, pipeline ruptures, the breakdown or failure of equipment or processes, and the performance of pipeline facilities below expected levels of capacity and efficiency.  Other operational hazards and unforeseen interruptions include adverse weather conditions, accidents, the collision of equipment with ONEOK Partners’ pipeline facilities (for example, this may occur if a third party were to perform excavation or construction work near ONEOK Partners’ facilities) and catastrophic events such as explosions, fires, hurricanes, earthquakes, floods or other similar events beyond ONEOK Partners’ control.  It is also possible that ONEOK Partners’ infrastructure facilities could be direct targets or indirect casualties of an act of terrorism. A casualty occurrence might result in injury or loss of life, extensive property damage or environmental damage.  Liabilities incurred and interruptions to the operation of ONEOK Partners’ pipeline caused by such an event could reduce revenues generated by ONEOK Partners and increase expenses, thereby impairing ONEOK Partners’ ability to meet its obligations.  Insurance proceeds may not be adequate to cover all liabilities or expenses incurred or revenues lost, and ONEOK Partners is not fully insured against all risks inherent to ONEOK Partners’ business. Additionally, in accordance with typical industry practice, ONEOK Partners does not have any property insurance on any of our underground pipeline systems that would cover damage to such systems.


As a result of market conditions, premiums and deductibles for certain insurance policies can increase substantially, and in some instances, certain insurance may become unavailable or available only for reduced amounts of coverage.  For example, change in the insurance markets subsequent to the terrorist attacks on September 11, 2001 and the hurricanes in 2005 and 2008 have made it more difficult for ONEOK Partners to obtain certain types of coverage.  Consequently, ONEOK Partners may not be able to renew existing insurance policies or procure other desirable insurance on commercially reasonable terms, if at all.  If ONEOK Partners was to incur a significant liability for which ONEOK Partners was not fully insured, it could have a material adverse effect on ONEOK Partners’ financial position and results of operations.  Further, the proceeds of any such insurance may not be paid in a timely manner and may be insufficient if such an event were to occur.

If the level of drilling and production in the Mid-Continent, Rocky Mountain, Texas and Gulf Coast regions substantially declines near its assets, ONEOK Partners’ volumes and revenue could decline.

ONEOK Partners’ ability to maintain or expand its businesses depends largely on the level of drilling and production in the Mid-Continent, Texas, Rocky Mountain and Gulf Coast regions.  Drilling and production are impacted by factors beyond ONEOK Partners’ control, including:
·  
demand for natural gas and refinery-grade crude oil;
·  
producers’ desire and ability to obtain necessary permits in a timely and economic manner;
·  
natural gas field characteristics and production performance;
·  
surface access and infrastructure issues; and
·  
capacity constraints on natural gas, crude oil and natural gas liquids pipelines from the producing areas and ONEOK Partners’ facilities.

In addition, drilling and production may be impacted by environmental regulations governing water discharge.  If the level of drilling and production in any of these regions substantially declines, ONEOK Partners’ volumes and revenue could be reduced.

If production from the Western Canada Sedimentary Basin remains flat or declines and demand for natural gas from the Western Canada Sedimentary Basin is greater in market areas other than the Midwestern United States, demand for ONEOK Partners’ interstate gas transportation services could significantly decrease.

ONEOK Partners depends on natural gas supply from the Western Canada Sedimentary Basin because ONEOK Partners’ interstate pipelines primarily transport Canadian natural gas from the Western Canada Sedimentary Basin to the Midwestern U.S. market area.  If demand for natural gas increases in Canada or other markets not served by ONEOK Partners’ interstate pipelines and production remains flat or declines, demand for transportation service on ONEOK Partners’ interstate natural gas pipelines could decrease significantly, which could adversely impact ONEOK Partners’ results of operations.

Pipeline integrity programs and repairs may impose significant costs and liabilities.

Pursuant to a United States Department of Transportation rule, pipeline operators were required to develop integrity management programs for intrastate and interstate natural gas and natural gas liquids pipelines located near high consequence areas, where a leak or rupture could do the most harm.  The rule also requires operators to perform ongoing assessments of pipeline integrity; identify and characterize applicable threats to pipeline segments that could impact a high consequence area; improve data collection, integration and analysis; repair and remediate the pipeline as necessary; and implement preventive and mitigating actions.  The results of these testing programs could cause ONEOK Partners to incur significant capital and operating expenditures to make repairs or take remediation, preventive or mitigating actions that are determined to be necessary.

ONEOK Partners’ regulated pipelines’ transportation rates are subject to review and possible adjustment by federal and state regulators.

ONEOK Partners’ regulated pipelines are subject to extensive regulation by the FERC and state regulatory agencies, which regulate most aspects of ONEOK Partners’ pipeline business, including ONEOK Partners’ transportation rates.  Under the Natural Gas Act, which is applicable to interstate natural gas pipelines, and the Interstate Commerce Act, which is applicable to crude oil and natural gas liquids pipelines, interstate transportation rates must be just and reasonable and not unduly discriminatory.

Action by the FERC or a state regulatory agency could adversely affect ONEOK Partners’ pipeline business’ ability to establish or charge rates that would cover future increases in their costs, or even to continue to collect rates that cover current costs, including a reasonable return.  ONEOK Partners cannot assure unitholders that its pipeline systems will be able to recover all of its costs through existing or future rates.


ONEOK Partners’ regulated pipeline companies have recorded certain assets that may not be recoverable from its customers.

Accounting policies for FERC-regulated companies permit certain assets that result from the regulated ratemaking process to be recorded on ONEOK Partners balance sheet that could not be recorded under GAAP for nonregulated entities.  ONEOK Partners considers factors such as regulatory changes and the impact of competition to determine the probability of future recovery of these assets.  If ONEOK Partners determines future recovery is no longer probable, ONEOK Partners would be required to write off the regulatory assets at that time.

ONEOK Partners’ operations are subject to federal and state laws and regulations relating to the protection of the environment, which may expose it to significant costs and liabilities.

The risk of incurring substantial environmental costs and liabilities is inherent in ONEOK Partners’ business.  ONEOK Partners’ operations are subject to extensive federal, state and local laws and regulations governing the discharge of materials into, or otherwise relating to the protection of, the environment.  Examples of these laws include:
·  
the federal Clean Air Act and analogous state laws that impose obligations related to air emissions;
·  
the federal Clean Water Act and analogous state laws that regulate discharge of wastewaters from ONEOK Partners’ facilities to state and federal waters;
·  
the federal Comprehensive Environmental Response, Compensation and Liability Act and analogous state laws that regulate the cleanup of hazardous substances that may have been released at properties currently or previously owned or operated by ONEOK Partners or locations to which ONEOK Partners has sent waste for disposal; and
·  
the federal Resource Conservation and Recovery Act and analogous state laws that impose requirements for the handling and discharge of solid and hazardous waste from ONEOK Partners’ facilities.

Various governmental authorities, including the EPA, have the power to enforce compliance with these laws and regulations and the permits issued under them.  Violators are subject to administrative, civil and criminal penalties, including civil fines, injunctions or both.  Joint and several, strict liability may be incurred without regard to fault under the Comprehensive Environmental Response, Compensation and Liability Act, Resource Conservation and Recovery Act and analogous state laws for the remediation of contaminated areas.

There is an inherent risk of incurring environmental costs and liabilities in ONEOK Partners’ business due to its handling of the products it gathers, transports and processes, air emissions related to its operations, historical industry operations and waste disposal practices, some of which may be material.  Private parties, including the owners of properties through which ONEOK Partners’ pipeline systems pass, may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage arising from ONEOK Partners’ operations.  Some sites ONEOK Partners operates are located near current or former third-party hydrocarbon storage and processing operations, and there is a risk that contamination has migrated from those sites to ONEOK Partners’ sites.  In addition, increasingly strict laws, regulations and enforcement policies could significantly increase ONEOK Partners’ compliance costs and the cost of any remediation that may become necessary, some of which may be material.  Additional information is included under Item 1, Business under “Environmental and Safety Matters” and in Note K of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

ONEOK Partners’ insurance may not cover all environmental risks and costs or may not provide sufficient coverage in the event an environmental claim is made against ONEOK Partners.  ONEOK Partners’ business may be adversely affected by increased costs due to stricter pollution control requirements or liabilities resulting from non-compliance with required operating or other regulatory permits.  New environmental regulations might also adversely affect ONEOK Partners’ products and activities, and federal and state agencies could impose additional safety requirements, all of which could materially affect ONEOK Partners’ profitability.

In the competition for customers, ONEOK Partners may have significant levels of uncontracted or discounted transportation and storage capacity on its natural gas and natural gas liquids pipelines and in its storage assets.

ONEOK Partners’ natural gas and natural gas liquids pipelines and storage assets compete with other pipelines and storage facilities for natural gas and NGL supplies delivered to the markets it serves.  As a result of competition, ONEOK Partners may have significant levels of uncontracted or discounted capacity on its pipelines and in its storage assets, which could have a material adverse impact on ONEOK Partners’ results of operations.



ONEOK Partners is exposed to the credit risk of its customers or counterparties, and its credit risk management may not be adequate to protect against such risk.

ONEOK Partners is subject to the risk of loss resulting from nonpayment and/or nonperformance by ONEOK Partners’ customers or counterparties.  ONEOK Partners’ customers or counterparties may experience deterioration of their financial condition as a result of changing market conditions or financial difficulties that could impact their creditworthiness or ability to pay ONEOK Partners for its services.  ONEOK Partners assesses the creditworthiness of its customers or counterparties and obtains security as it deems appropriate.  If ONEOK Partners fails to adequately assess the creditworthiness of existing or future customers or counterparties, unanticipated deterioration in their creditworthiness and any resulting nonpayment and/or nonperformance could adversely impact ONEOK Partners’ results of operations.  In addition, if any of ONEOK Partners’ customers or counterparties files for bankruptcy protection, this could have a material negative impact on ONEOK Partners’ results of operations.

Any reduction in ONEOK Partners’ credit ratings could materially and adversely affect its business, financial condition, liquidity and results of operations.  

ONEOK Partners’ senior unsecured long-term debt has been assigned an investment-grade rating by Moody’s of “Baa2” (Stable) and by S&P of “BBB” (Stable).  However, we cannot provide assurance that any of its current ratings will remain in effect for any given period of time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in its judgment, circumstances in the future so warrant.  Specifically, if Moody’s or S&P were to downgrade ONEOK Partners’ long-term debt rating, particularly below investment grade, its borrowing costs would increase, which would adversely affect its financial results, and its potential pool of investors and funding sources could decrease.  Ratings from credit agencies are not recommendations to buy, sell or hold ONEOK Partners’ securities.  Each rating should be evaluated independently of any other rating.

A downgrade of ONEOK Partners’ credit rating may require ONEOK Partners to offer to repurchase certain of its senior notes or may impair its ability to access capital.

ONEOK Partners could be required to offer to repurchase certain of its senior notes due 2010 and 2011 at par value, plus any accrued and unpaid interest, if Moody’s or S&P rates those senior notes below investment grade (Baa3 for Moody’s and BBB- for S&P) and the investment-grade rating is not reinstated within a period of 40 days.  Further, the indenture governing ONEOK Partners’ senior notes due 2010 and 2011 include an event of default upon acceleration of other indebtedness of $25 million or more and the indentures governing ONEOK Partners’ senior notes due 2012, 2016, 2036 and 2037 include an event of default upon the acceleration of other indebtedness of $100 million or more that would be triggered by such an offer to repurchase.  Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2010, 2011, 2012, 2016, 2036 and 2037 to declare those notes immediately due and payable in full.  ONEOK Partners may not have sufficient cash on hand to repurchase and repay any accelerated senior notes, which may cause ONEOK Partners to borrow money under its credit facilities or seek alternative financing sources to finance the repurchases and repayment.  ONEOK Partners could also face difficulties accessing capital or its borrowing costs could increase, impacting its ability to obtain financing for acquisitions or capital expenditures, to refinance indebtedness and to fulfill its debt obligations.

ONEOK Partners has adopted certain valuation methodologies that may result in a shift of income, gain, loss and deduction between the general partner and the unitholders.  The IRS may challenge this treatment, which could adversely affect the value of its limited partner units.

When ONEOK Partners issues additional units or engages in certain other transactions, ONEOK Partners determines the fair market value of its assets and allocates any unrealized gain or loss attributable to its assets to the capital accounts of its unitholders and its general partner.  ONEOK Partners’ methodology may be viewed as understating the value of its assets.  In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and the general partner, which may be unfavorable to such unitholders.  Moreover, under ONEOK Partners’ current valuation methods, subsequent purchasers of common units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to ONEOK Partners’ tangible assets and a lesser portion allocated to ONEOK Partners’ intangible assets.  The IRS may challenge ONEOK Partners’ valuation methods or ONEOK Partners’ allocation of the Section 743(b) adjustment attributable to ONEOK Partners’ tangible and intangible assets, and allocations of income, gain, loss and deduction between the general partner and certain of ONEOK Partners’ unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to ONEOK Partners’ unitholders.  It also could affect the amount of gain from ONEOK Partners unitholders’ sale


of common units and could have a negative impact on the value of the common units or result in audit adjustments to ONEOK Partners unitholders’ tax returns without the benefit of additional deductions.

ONEOK Partners’ treatment of a purchaser of common units as having the same tax benefits as the seller could be challenged, resulting in a reduction in value of the common units.

Because ONEOK Partners cannot match transferors and transferees of common units, ONEOK Partners is required to maintain the uniformity of the economic and tax characteristics of these units in the hands of the purchasers and sellers of these units.  ONEOK Partners does so by adopting certain depreciation conventions that do not conform to all aspects of the United States Treasury regulations.  An IRS challenge to these conventions could adversely affect the tax benefits to a unitholder of ownership of the common units and could have a negative impact on their value or result in audit adjustments to ONEOK Partners unitholders’ tax returns.

ITEM 1B.                       UNRESOLVED STAFF COMMENTS

Not applicable.

ITEM 2.                       PROPERTIES

DESCRIPTION OF PROPERTIES

ONEOK Partners

Property - Our ONEOK Partners segment owns the following assets:
·  
approximately 10,100 miles and 4,500 miles of natural gas gathering pipelines in the Mid-Continent and Rocky Mountain regions, respectively;
·  
nine active natural gas processing plants with approximately 645 MMcf/d of processing capacity in the Mid-Continent region and four active natural gas processing plants with approximately 80 MMcf/d of processing capacity in the Rocky Mountain region;
·  
approximately 18 MBbl/d of natural gas liquids fractionation capacity at various natural gas processing plants in the Mid-Continent and Rocky Mountain regions;
·  
approximately 1,320 miles of FERC-regulated interstate natural gas pipelines with approximately 2.5 Bcf/d of peak transportation capacity;
·  
approximately 5,560 miles of intrastate natural gas gathering and state-regulated intrastate transmission pipelines with peak transportation capacity of approximately 3.3 Bcf/d;
·  
approximately 51.6 Bcf of total active working natural gas storage capacity;
·  
approximately 2,011 miles of natural gas liquids gathering pipelines with peak capacity of approximately 247 MBbl/d;
·  
approximately 163 miles of natural gas liquids distribution pipelines with peak transportation capacity of approximately 66 MBbl/d;
·  
two natural gas liquids fractionators with operating capacity of approximately 260 MBbl/d;
·  
150 MBbl/d of fractionation capacity, including leased capacity;
·  
80 percent ownership interest in one natural gas liquids fractionator with operating capacity of approximately 160 MBbl/d;
·  
interest in one natural gas liquids fractionator with proportional operating capacity of approximately 11 MBbl/d;
·  
one 9 MBbl/d isomerization unit;
·  
six NGL storage facilities and four other leased facilities in Okalahoma, Kansas and Texas, with approximately 26.4 MMBbl of total operating underground NGL storage capacity;
·  
approximately 1,480 miles of FERC-regulated natural gas liquids gathering pipelines with peak capacity of approximately 203 MBbl/d;
·  
approximately 3,480 miles of FERC-regulated natural gas liquids and refined petroleum products distribution pipelines with peak transportation capacity of 691 MBbl/d;
·  
eight NGL product terminals in Missouri, Nebraska, Iowa and Illinois; and
·  
above- and below-ground storage facilities in Iowa, Illinois, Nebraska and Kansas with 978 MBbl operating capacity.



ONEOK Partners’ natural gas pipelines business owns five underground natural gas storage facilities in Oklahoma, three underground natural gas storage facilities in Kansas and three underground natural gas storage facilities in Texas.  One of its natural gas storage facilities has been idle since 2001 following natural gas explosions and eruptions of natural gas geysers in Hutchinson, Kansas.  ONEOK Partners began injecting brine into the idled facility in the first quarter of 2007 in order to ensure its long-term integrity.  ONEOK Partners expects to complete the injection process by the end of 2011.  Monitoring of the facility and review of the data for the geoengineering study are ongoing, in compliance with a KDHE order while ONEOK Partners evaluates the alternatives for the facility.  Following the testing of the gathered data, ONEOK Partners expects to return the facility to storage service, although most likely for a product other than natural gas.  The return to service will require KDHE approval.  It is possible, however, that testing could reveal that it is not safe to return the facility to service or that the KDHE will not grant the required permits to resume service.

Utilization - The utilization rates for ONEOK Partners’ various businesses for 2008 were as follows:
·  
natural gas processing plants were approximately 71 percent;
·  
natural gas pipelines were approximately 86 percent subscribed, and storage facilities were fully subscribed;
·  
natural gas liquids gathering pipelines were approximately 73 percent;
·  
ONEOK Partners’ average contracted storage volume were approximately 74 percent of storage capacity;
·  
natural gas liquids fractionators were approximately 87 percent;
·  
FERC-regulated natural gas liquids gathering pipelines were approximately 55 percent; and
·  
natural gas liquids distribution pipelines were approximately 49 percent.

ONEOK Partners calculated utilization on its assets using a weighted-average approach, adjusting for the in-service dates of assets placed in service during 2008.  The utilization rate of ONEOK Partners’ fractionation facilities reflects approximate proportional capacity associated with ownership interests noted above and partial service for the Bushton facilities, which were placed in service during the second half of 2008.

On January 1, 2007, the Bushton Plant was temporarily idled as a result of a decline in natural gas volumes available for natural gas processing at this straddle plant.  Volumes declined due to natural field declines and as a result of contract terminations, as advances in technology made it more cost efficient to process natural gas at other facilities.  ONEOK Partners has contracted for all of the capacity of the plant from ONEOK.

During 2007 and 2008, ONEOK Partners added new natural gas liquids fractionation facilities at the Bushton location, in conjunction with other changes that were made to the NGL fractionation capabilities of the existing plant.  Although the Bushton Plant remains idled, ONEOK Partners currently has 150 MBbl/d of active NGL fractionation capacity as a result of combining the previously existing fractionation equipment with the new fractionation facilities.  ONEOK Partners resumed fractionating NGLs at the facilities in the second half of 2008.

Distribution

Property - We own approximately 18,100 miles of pipeline and other distribution facilities in Oklahoma, approximately 12,800 miles of pipeline and other distribution facilities in Kansas, and approximately 9,600 miles of pipeline and other distribution facilities in Texas.

Energy Services

Property - Our total natural gas storage capacity under lease is 91 Bcf, with maximum withdrawal capability of 2.3 Bcf/d and maximum injection capability of 1.5 Bcf/d.  Our current natural gas transportation capacity is 1.8 Bcf/d.  Our contracted storage and transportation capacity connects major supply and demand centers throughout the United States and into Canada.  Our storage leases are spread across 25 different contracts and two facilities in Canada.

Other

Property - We own the 17-story ONEOK Plaza office building, with approximately 517,000 square feet of net rentable space, and the associated parking garage.  In March 2008, ONEOK Leasing Company purchased ONEOK Plaza for the total purchase price of approximately $48 million, which included $17.1 million for the present value of the remaining lease payments and $30.9 million for the base purchase price.



ITEM 3.                       LEGAL PROCEEDINGS

Will Price, et al. v. Gas Pipelines, et al. (f/k/a Quinque Operating Company, et al. v. Gas Pipelines, et al.), 26th Judicial District, District Court of Stevens County, Kansas, Civil Department, Case No. 99C30 (“Price I”). Plaintiffs brought suit on May 28, 1999, against us, five of our subsidiaries and one of our divisions, as well as approximately 225 other defendants.  Additionally, in connection with the completion of our acquisition of the natural gas liquids businesses owned by several Koch companies, on July 1, 2005, we acquired Koch Hydrocarbon, LP (renamed ONEOK Hydrocarbon, L.P.), which is also one of the defendants in this case.  Plaintiffs sought class certification for its claims for monetary damages that the defendants had underpaid gas producers and royalty owners throughout the United States by intentionally understating both the volume and the heating content of purchased gas.  After extensive briefing and a hearing, the Court refused to certify the class sought by plaintiffs.  Plaintiffs then filed an amended petition limiting the purported class to gas producers and royalty owners in Kansas, Colorado and Wyoming and limiting the claim to undermeasurement of volumes.  Oral argument on the plaintiffs’ motion to certify this suit as a class action was conducted on April 1, 2005.  The Court has not yet ruled on the class certification issue.

Will Price and Stixon Petroleum, et al. v. Gas Pipelines, et al. , 26th Judicial District, District Court of Stevens County, Kansas, Civil Department, Case No. 03C232 (“Price II”).   This action was filed by the plaintiffs on May 12, 2003, after the Court had denied class status in Price I.  Plaintiffs are seeking monetary damages based upon a claim that 21 groups of defendants, including us and four of our subsidiaries, intentionally underpaid gas producers and royalty owners by understating the heating content of purchased gas in Kansas, Colorado and Wyoming.  Additionally, in connection with the completion of our acquisition of the natural gas liquids businesses owned by several Koch companies, on July 1, 2005, we acquired Koch Hydrocarbon, LP (renamed ONEOK Hydrocarbon, L.P.), which is also one of the defendants in this case.  Price II has been consolidated with Price I for the determination of whether either or both cases may properly be certified as class actions.  Oral argument on the plaintiffs’ motion to certify this suit as a class action was conducted on April 1, 2005.   The Court has not yet ruled on the class certification issue.

Mont Belvieu Emissions , Texas Commission on Environmental Quality - Personnel of ONEOK Hydrocarbon Southwest, L.L.C. (OHSL), a subsidiary of ONEOK Partners, are in discussions with the Texas Commission on Environmental Quality (TCEQ) staff regarding air emissions from a heat exchanger at ONEOK Partners’ Mont Belvieu fractionator, which may have exceeded the emissions allowed under its air permit.  OHSL discovered the possibility of excessive air emissions in May 2008.  The TCEQ has not issued a notice of enforcement relating to the emissions under this permit.  Although no assurances can be given, ONEOK Partners does not believe that any penalties associated with any alleged violations will have a material adverse effect on its financial position, results of operations, or net cash flows.

Gas Index Pricing Litigation:   We, ONEOK Energy Services Company, L.P. (“OESC”) and one other affiliate are defending, either individually or together, against the following lawsuits that claim damages resulting from the alleged market manipulation or false reporting of prices to gas index publications by us and others:   Samuel P. Leggett, et al. v. Duke Energy Corporation, et al. (filed in the Chancery Court for the Twenty-Fifth Judicial District at Somerville, Tennessee, in January 2005); Sinclair Oil Corporation v. ONEOK Energy Services Corporation, L.P., et al. (filed in the United States District Court for the District of Wyoming in September 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada); J.P. Morgan Trust Company v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte County, Kansas, in October 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada); Learjet, Inc., et al. v. ONEOK, Inc., et al. (filed in the District Court of Wyandotte, Kansas, in November 2005, transferred to MDL-1566 in the United States District Court for the District of Nevada); Breckenridge Brewery of Colorado, LLC, et al. v. ONEOK, Inc., et al. (filed in the District Court of Denver County, Colorado, in May 2006, transferred to MDL-1566 in the United States District Court for the District of Nevada); Missouri Public Service Commission v. ONEOK, Inc., et al. (filed in the Sixth Judicial Circuit Court of Jackson County, Missouri, in October 2006); Arandell Corporation, et al. v. Xcel Energy, Inc., et al. (filed in the Circuit Court for Dane County, Wisconsin, in December 2006, transferred to MDL-1566 in the United States District Court for the District of Nevada); Heartland Regional Medical Center, et al. v. ONEOK, Inc., et al. (filed in the Circuit Court of Buchanan County, Missouri, transferred to MDL-1566 in the United States District Court for the District of Nevada).  In each of these lawsuits, the plaintiffs allege that we, OESC and one other affiliate and approximately ten other energy companies and their affiliates engaged in an illegal scheme to inflate natural gas prices by providing false information to gas price index publications during the years from 2000 to 2002.  All of the complaints arise out of the U.S. Commodity Futures Trading Commission investigation into and reports concerning false gas price index-reporting or manipulation in the energy marketing industry.  Other than as noted below, each of the cases are in pretrial discovery.



Motions to dismiss were granted in the Leggett, Sinclair, and Missouri Public Service Commission cases.  The dismissal of the Sinclair case was appealed to the United States Court of Appeals for the Ninth Circuit, but is in the process of being remanded back to the multi-district litigation matter MDL-1566 in the United States District Court for the District of Nevada for further proceedings.  The dismissal of the Leggett case was reversed by the Tennessee Court of Appeals on October 29, 2008, but the defendants, including us and OESC, have filed an application with the Tennessee Supreme Court to appeal the decision.  On January 8, 2009, summary judgment was granted in favor of all of the defendants except one in the Breckenridge case and judgment was entered against the plaintiffs in favor of those defendants, including us, OESC and our other affiliate.  We continue to analyze all of these claims and are vigorously defending against them.
 
ITEM 4.
SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
 
No matter was submitted to a vote of our security holders, through the solicitation of proxies or otherwise, during the fourth quarter 2008.

PART II

ITEM 5.
MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

MARKET INFORMATION AND HOLDERS

Our common stock is listed on the NYSE under the trading symbol “OKE.”  The corporate name ONEOK is used in newspaper stock listings.  The following table sets forth the high and low closing prices of our common stock for the periods indicated.

   
Year Ended
   
Year Ended
 
   
December 31, 2008
   
December 31, 2007
 
   
High
   
Low
   
High
   
Low
 
First Quarter
  $ 49.21     $ 43.93     $ 46.13     $ 40.12  
Second Quarter
  $ 50.63     $ 45.62     $ 54.58     $ 44.57  
Third Quarter
  $ 49.59     $ 33.41     $ 54.86     $ 43.65  
Fourth Quarter
  $ 34.35     $ 23.17     $ 52.05     $ 44.29  

At February 18, 2009, there were  13,804 holders of record of our 105,239,496 outstanding shares of common stock.

DIVIDENDS

The following table sets forth the quarterly dividends declared and paid per share of our common stock during the periods indicated.
 
 
Years Ended December 31,
     
2008
   
2007
 
First Quarter
  $
0.38
  $
0.34
 
Second Quarter
  $
0.38
  $
0.34
 
Third Quarter
  $
0.40
  $
0.36
 
Fourth Quarter
  $
0.40
  $
0.36
 (a)
(a) - Declared in the previous quarter.
 

In January 2009, we declared a dividend of $0.40 per share ($1.60 per share on an annualized basis) for the fourth quarter of 2008, which was paid on February 13, 2009, to shareholders of record as of January 30, 2009.



ISSUER PURCHASES OF EQUITY SECURITIES

The following table sets forth information relating to our purchases of our common stock for the periods shown.
 
Period
Total Number of Shares Purchased
Average Price Paid per Share
 
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
 
Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Be Purchased Under the Plans or Programs
 
                               
October 1-31, 2008
 
 -
   
 -
     
 -
     
 -
   
November 1-30, 2008
 
 -
   
 -
     
 -
     
 -
   
December 1-31, 2008
 
 10
   (1)
 
$27.38
     
 -
     
 -
   
Total
 
 10
   
$27.38
     
 -
     
 -
   
                               
(1) - Represents shares repurchased directly from employees, pursuant to our Employee Stock Award Program.

EMPLOYEE STOCK AWARD PROGRAM

Under our Employee Stock Award Program, we issued, for no consideration, to all eligible employees (all full-time employees and employees on short-term disability) one share of our common stock when the per-share closing price of our common stock on the NYSE was for the first time at or above $26 per share, and we have issued and will continue to issue, for no consideration, one additional share of our common stock to all eligible employees when the closing price on the NYSE is for the first time at or above each one dollar increment above $26 per share.  The total number of shares of our common stock available for issuance under this program is 300,000.

Through December 31, 2008, a total of 144,352 shares have been issued to employees under this program.  The shares issued under this program have not been registered under the Securities Act of 1933, as amended (1933 Act), in reliance upon the position taken by the SEC (see Release No. 6188, dated February 1, 1980) that the issuance of shares to employees pursuant to a program of this kind does not require registration under the 1933 Act.  See Note N of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional information.



PERFORMANCE GRAPH

The following performance graph compares the performance of our common stock with the S&P 500 Index and the S&P Utilities Index during the period beginning on December 31, 2003, and ending on December 31, 2008.  The graph assumes a $100 investment in our common stock and in each of the indices at the beginning of the period and a reinvestment of dividends paid on such investments throughout the period.
 
Value of $100 Investment Assuming Reinvestment of Dividends
At December 31, 2003, and at the End of Every Year Through December 31, 2008
Among ONEOK, Inc., The S&P 500 Index and The S&P Utilities Index
 

   
Cumulative Total Return
 
   
Years Ending December 31,
 
   
2003
   
2004
   
2005
   
2006
   
2007
   
2008
 
                                     
ONEOK, Inc.
  $ 100.00     $ 133.74     $ 130.01     $ 218.10     $ 233.19     $ 157.65  
S&P 500 Index
  $ 100.00     $ 110.88     $ 116.32     $ 134.69     $ 142.09     $ 89.52  
S&P Utilities Index (a)
  $ 100.00     $ 124.28     $ 145.21     $ 175.69     $ 209.73     $ 148.95  
(a) - The Standard & Poors Utilities Index is comprised of the following companies: AES Corp.; Allegheny Energy, Inc.;
 
Ameren Corp.; American Electric Power Co., Inc.; Centerpoint Energy, Inc.; CMS Energy Corp.; Consolidated Edison, Inc.;
 
Constellation Energy Group, Inc.; Dominion Resources, Inc.; DTE Energy Co.; Duke Energy Corp.; Dynegy, Inc.; Edison
 
International; Entergy Corp.; Equitable Resources, Inc.; Exelon Corp.; FirstEnergy Corp.; FPL Group, Inc.; Integrys Energy
 
Group, Inc.; Nicor, Inc.; NiSource, Inc.; Pepco Holdings, Inc.; PG&E Corp.; Pinnacle West Capital Corp.; PPL Corp.; Progress
 
Energy, Inc.; Public Service Enterprise Group, Inc.; Questar Corp.; SCANA Corp.; Sempra Energy; Southern Co.; TECO
 
Energy, Inc.; Wisconsin Energy Corp.; and Xcel Energy, Inc.
                                 



ITEM 6.                       SELECTED FINANCIAL DATA

The following table sets forth our selected financial data for each of the periods indicated.
 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
   
2005
   
2004
 
   
(Millions of dollars, except per share amounts)
 
Revenues
  $ 16,157.4     $ 13,477.4     $ 11,920.3     $ 12,676.2     $ 5,785.5  
Income from continuing operations
  $ 311.9     $ 304.9     $ 306.7     $ 403.1     $ 224.7  
Net income
  $ 311.9     $ 304.9     $ 306.3     $ 546.5     $ 242.2  
Total assets
  $ 13,126.1     $ 11,062.0     $ 10,391.1     $ 9,284.2     $ 7,199.2  
Long-term debt, including current maturities
  $ 4,230.8     $ 4,635.5     $ 4,049.0     $ 2,030.6     $ 1,884.7  
Basic earnings per share - continuing operations
  $ 2.99     $ 2.84     $ 2.74     $ 4.01     $ 2.21  
Basic earnings per share - total
  $ 2.99     $ 2.84     $ 2.74     $ 5.44     $ 2.38  
Diluted earnings per share - continuing operations
  $ 2.95     $ 2.79     $ 2.68     $ 3.73     $ 2.13  
Diluted earnings per share - total
  $ 2.95     $ 2.79     $ 2.68     $ 5.06     $ 2.30  
Dividends declared per common share
  $ 1.56     $ 1.40     $ 1.22     $ 1.09     $ 0.88  
 
Financial data for 2008, 2007 and 2006 is not directly comparable with 2005 and 2004 due to the significance of the sale of certain assets to ONEOK Partners in April 2006.  See discussion of acquisitions and dispositions beginning on page 36 under “Significant Acquisitions and Divestitures” in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation.

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

The following discussion and analysis should be read in conjunction with our audited consolidated financial statements and the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

EXECUTIVE SUMMARY

The following discussion highlights some of our achievements this past year.  Please refer to the “Financial Results and Operating Information,” “Liquidity and Capital Resources,” and “Capital Projects” sections of Management’s Discussion and Analysis of Financial Condition and Results of Operation and our consolidated financial statements for additional information.

Operating Results - Diluted earnings per share of common stock from continuing operations (EPS) increased to $2.95 in 2008, compared with $2.79 in 2007.  Operating income for 2008 increased to $917.0 million from $822.5 million for 2007.  This increase is primarily due to wider NGL product price differentials, higher realized commodity prices, increased NGL gathering and fractionation volumes, and incremental operating income associated with the assets acquired from Kinder Morgan Energy Partners, L.P. (Kinder Morgan), all in our ONEOK Partners segment.  This increase in operating income was partially offset by decreases in storage and marketing margins and transportation margins, net of hedging activities, in our Energy Services segment.

ONEOK Partners’ Equity Issuance - In March 2008, we purchased from ONEOK Partners, in a private placement, an additional 5.4 million of ONEOK Partners’ common units for a total purchase price of approximately $303.2 million.  In addition, ONEOK Partners completed a public offering of 2.5 million common units at $58.10 per common unit and received net proceeds of $140.4 million after deducting underwriting discounts but before offering expenses.  In conjunction with ONEOK Partners’ private placement and public offering of common units, ONEOK Partners GP contributed $9.4 million to ONEOK Partners in order to maintain its 2 percent general partner interest.

In April 2008, ONEOK Partners sold an additional 128,873 common units at $58.10 per common unit to the underwriters of the public offering upon the partial exercise of their option to purchase additional common units to cover over-allotments.  ONEOK Partners received net proceeds of approximately $7.2 million from the sale of these common units after deducting underwriting discounts but before offering expenses.  In conjunction with the partial exercise by the underwriters, ONEOK Partners GP contributed $0.2 million to ONEOK Partners in order to maintain its 2 percent general partner interest.  Following these transactions, our interest in ONEOK Partners is 47.7 percent.


ONEOK Partners used a portion of the proceeds from the sale of common units and the general partner contributions to repay borrowings under its $1.0 billion revolving credit agreement dated March 30, 2007, as amended July 31, 2007 (the ONEOK Partners Credit Agreement).

Dividends/Distributions - During 2008, we paid dividends totaling $1.56 per share, an increase of approximately 11 percent over the $1.40 per share paid during 2007.  We declared a quarterly dividend of $0.40 per share ($1.60 per share on an annualized basis) in January 2009, an increase of approximately 5 percent over the $0.38 declared in January 2008.  During 2008, ONEOK Partners paid cash distributions totaling $4.205 per unit, an increase of approximately 6 percent over the $3.98 per unit paid during 2007.  ONEOK Partners declared a cash distribution of $1.08 per unit ($4.32 per unit on an annualized basis) in January 2009, an increase of approximately 5 percent over the $1.025 declared in January 2008.

Capital Projects - ONEOK Partners placed the following projects in-service during 2008:
·  
January - Midwestern Gas Transmission’s eastern extension pipeline;
·  
July - final phase of Fort Union Gas Gathering expansion project;
·  
September - Woodford Shale natural gas liquids pipeline extension;
·  
October - Bushton Fractionation expansion;
·  
November - Overland Pass Pipeline from Opal, Wyoming to Conway, Kansas; and
·  
December - partial operations of the Guardian pipeline extension with interruptible service from Ixonia, Wisconsin, to Green Bay, Wisconsin.

Key Performance Indicators - Key performance indicators reviewed by management include:
·  
earnings per share;
·  
return on invested capital; and
·  
shareholder appreciation.

For 2008, our basic and diluted earnings per share from continuing operations were $2.99 and $2.95, respectively, representing a 5 percent increase in basic earnings per share and a 6 percent increase in diluted earnings per share from continuing operations compared with 2007.  For 2007, our basic and diluted earnings per share from continuing operations were $2.84 and $2.79, respectively, representing a 4 percent increase in basic earnings per share and a 4 percent increase in diluted earnings per share from continuing operations compared with 2006.  Return on invested capital was 13 percent in 2008 and 14 percent in 2007 and 2006, respectively.

To evaluate shareholder appreciation, we compare the total return over a three-year period of an investment in our stock with the total return of an investment in the stock of a group of peer companies.  For the three-year period ended December 31, 2008, we ranked fifth in this shareholder appreciation calculation when compared with 18 of our peers.

Outlook for 2009 - We expect continued deteriorating economic conditions in 2009, with significant downward pressures, relative to 2008, on commodity prices for natural gas, NGLs and crude oil.  We anticipate that lower commodity prices will result in reduced drilling activity, and economic conditions will reduce petrochemical demand.  We also expect continued volatility and disruption in the financial markets which could result in an increased cost of capital.  We expect depressed commodity prices and tighter capital markets to also result in the sale or consolidation of underperforming assets in the industry, which may present opportunities for us.

SIGNIFICANT ACQUISITIONS AND DIVESTITURES

Acquisition of NGL Pipeline - In October 2007, ONEOK Partners completed the acquisition of an interstate natural gas liquids and refined petroleum products pipeline system and related assets from a subsidiary of Kinder Morgan for approximately $300 million, before working capital adjustments.  The system extends from Bushton and Conway, Kansas, to Chicago, Illinois, and transports, stores and delivers a full range of NGL products and refined petroleum products.  The FERC-regulated system spans 1,624 miles and has a capacity to transport up to 134 MBbl/d. The transaction also included approximately 978 MBbl of owned storage capacity, eight NGL terminals and a 50 percent ownership of Heartland.  ConocoPhillips owns the other 50 percent of Heartland and is the managing partner of the Heartland joint venture, which consists primarily of a refined petroleum products terminal and pipelines with access to two other refined petroleum products terminals.  ONEOK Partners’ investment in Heartland is accounted for under the equity method of accounting.  Financing for this transaction came from a portion of the proceeds of ONEOK Partners’ September 2007 issuance of $600 million 6.85 percent Senior Notes due 2037 (the 2037 Notes).  See Note I of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for a discussion of the 2037 Notes.  The working capital settlement was finalized in April 2008, with no material adjustments.


Overland Pass Pipeline Company - See “Capital Projects” for discussion of Overland Pass Pipeline Company.

ONEOK Partners - In April 2006, we sold certain assets comprising our former gathering and processing, natural gas liquids, and pipelines and storage segments to ONEOK Partners for approximately $3 billion, including $1.35 billion in cash, before adjustments, and approximately 36.5 million Class B limited partner units in ONEOK Partners.  The Class B limited partner units and the related general partner interest contribution were valued at approximately $1.65 billion.  We also purchased, through ONEOK Partners GP, from an affiliate of TransCanada, 17.5 percent of the general partner interest in ONEOK Partners for $40 million.  This purchase resulted in our ownership of the entire 2 percent general partner interest in ONEOK Partners.  Following the completion of the transactions, we owned a total of approximately 37.0 million common and Class B limited partner units and the entire 2 percent general partner interest and control of the partnership.  Our overall interest in ONEOK Partners, including the 2 percent general partner interest, was 45.7 percent at the date of acquisition.

The sale of certain assets comprising our former gathering and processing, pipelines and storage, and natural gas liquids segments did not affect our consolidated operating income on our Consolidated Statements of Income or total assets on our Consolidated Balance Sheets, as we were already required under EITF 04-5 to consolidate our investment in ONEOK Partners effective January 1, 2006.  However, minority interest expense and net income were affected.  See Note A of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K beginning on page 76 for additional discussion of our consolidation of ONEOK Partners.

Disposition of 20 percent interest in Northern Border Pipeline - In April 2006, in connection with the transactions described immediately above, our ONEOK Partners segment completed the sale of a 20 percent partnership interest in Northern Border Pipeline to TC PipeLines for approximately $297 million.  Our ONEOK Partners segment recorded a gain on sale of approximately $113.9 million in the second quarter of 2006.  ONEOK Partners and TC PipeLines each now own a 50 percent interest in Northern Border Pipeline, and an affiliate of TransCanada became operator of the pipeline in April 2007.  As a result of this transaction, ONEOK Partners’ interest in Northern Border Pipeline is accounted for as an investment under the equity method applied on a retroactive basis to January 1, 2006.

Acquisition of Guardian Pipeline Interests - In April 2006, our ONEOK Partners segment acquired the 66-2/3 percent interest in Guardian Pipeline not previously owned by ONEOK Partners for approximately $77 million, increasing its ownership interest to 100 percent.  ONEOK Partners used borrowings from its credit facility to fund the acquisition of the additional interest in Guardian Pipeline.  Following the completion of the transaction, we consolidated Guardian Pipeline in our consolidated financial statements.  This change was accounted for on a retroactive basis to January 1, 2006.

CAPITAL PROJECTS

All of the capital projects discussed below are in our ONEOK Partners segment.

Woodford Shale Natural Gas Liquids Pipeline Extension - The 78-mile natural gas liquids gathering pipeline connecting two natural gas processing plants, operated by Devon Energy Corporation and Antero Resources Corporation, was placed into service in September 2008.  The cost of the project was approximately $36 million, excluding AFUDC.  These two plants have the capacity to produce approximately 25 MBbl/d of unfractionated NGLs.  The natural gas liquids production is gathered by ONEOK Partners’ existing Mid-Continent natural gas liquids gathering pipelines.  Upon completion of the Arbuckle Pipeline project, the Woodford Shale natural gas liquids production is expected to be transported through the Arbuckle Pipeline to ONEOK Partners’ Mont Belvieu, Texas, fractionation facility. 

Overland Pass Pipeline Company - In May 2006, a subsidiary of ONEOK Partners entered into an agreement with a subsidiary of The Williams Companies, Inc. (Williams) to form a joint venture called Overland Pass Pipeline Company.  In November 2008, Overland Pass Pipeline Company completed construction of a 760-mile natural gas liquids pipeline from Opal, Wyoming, to the Mid-Continent natural gas liquids market center in Conway, Kansas.  The Overland Pass Pipeline is designed to transport approximately 110 MBbl/d of unfractionated NGLs and can be increased to approximately 255 MBbl/d with additional pump facilities.  During 2006, ONEOK Partners paid $11.6 million to Williams for the acquisition of its interest in the joint venture and for reimbursement of initial capital expenditures.  A subsidiary of ONEOK Partners owns 99 percent of the joint venture, managed the construction project, advanced all costs associated with construction and is currently operating the pipeline.  On or before November 17, 2010, Williams will have the option to increase its ownership up to 50 percent, with the purchase price determined in accordance with the joint venture’s operating agreement.  If Williams exercises its option to increase its ownership to the full 50 percent, Williams would have the option to become operator.  The pipeline project cost was approximately $575 million, excluding AFUDC.

As part of a long-term agreement, Williams dedicated its NGL production from two of its natural gas processing plants in Wyoming, estimated to be approximately 60 MBbl/d, to the Overland Pass Pipeline.  Subsidiaries of ONEOK Partners will


provide downstream fractionation, storage and transportation services to Williams.  ONEOK Partners has also reached agreements with certain producers for supply commitments of up to an additional 80 MBbl/d and is negotiating agreements with other producers for supply commitments that could add an additional 60 MBbl/d of supply to this pipeline within the next three to five years.

ONEOK Partners also invested approximately $239 million, excluding AFUDC, to expand its existing fractionation and storage capabilities and to increase the capacity of its natural gas liquids distribution pipelines.  Part of this expansion included adding new fractionation facilities at ONEOK Partners’ Bushton location, increasing total fractionation capacity at Bushton to 150 MBbl/d.  The addition of the new facilities and the upgrade to the existing fractionator was completed in October 2008.  Additionally, portions of the natural gas liquids distribution pipeline upgrades were completed in the second and third quarters of 2008.

Piceance Lateral Pipeline - In March 2007, ONEOK Partners announced that Overland Pass Pipeline Company also plans to construct a 150-mile lateral pipeline with capacity to transport as much as 100 MBbl/d of unfractionated NGLs from the Piceance Basin in Colorado to the Overland Pass Pipeline.  Williams announced that it intends to construct a new natural gas processing plant in the Piceance Basin and will dedicate its NGL production from that plant and an existing plant, with estimated volumes totaling approximately 30 MBbl/d, to be transported by the lateral pipeline.  ONEOK Partners continues to negotiate with other producers for supply commitments.  In October 2008, this project received approval of various state and federal regulatory authorities allowing construction to commence.  Construction began during the fourth quarter of 2008 and is expected be completed during the third quarter of 2009.  The project is currently estimated to cost in the range of $110 million to $140 million, excluding AFUDC.

D-J Basin Lateral Pipeline - In September 2008, ONEOK Partners announced plans to construct a 125-mile natural gas liquids lateral pipeline from the Denver-Julesburg Basin in northeastern Colorado to the Overland Pass Pipeline, with capacity to transport as much as 55 MBbl/d of unfractionated NGLs.  The project is currently estimated to cost in the range of $70 million to $80 million, excluding AFUDC.  ONEOK Partners has supply commitments for up to 33 MBbl/d of unfractionated NGLs with potential for an additional 10 MBbl/d of supply from new drilling and plant upgrades in the next two years.  The pipeline is currently under construction and is expected to be fully completed during the first quarter of 2009.

Arbuckle Pipeline Natural Gas Liquids Pipeline - In March 2007, ONEOK Partners announced plans to build the 440-mile Arbuckle Pipeline, a natural gas liquids pipeline from southern Oklahoma through northern Texas and continuing on to the Texas Gulf Coast.  The Arbuckle Pipeline will have the capacity to transport 160 MBbl/d of unfractionated NGLs, expandable to 210 MBbl/d with additional pump facilities, and will connect with ONEOK Partners’ existing Mid-Continent infrastructure with its fractionation facility in Mont Belvieu, Texas, and other Gulf Coast region fractionators.  ONEOK Partners has supply commitments from producers that it expects will be sufficient to fill the 210 MBbl/d capacity level over the next three to five years.  Construction on the pipeline has been underway since the third quarter of 2008.  Much of the Oklahoma and north Texas portions are either complete or nearing completion.  However, right-of-way acquisition has been challenging, time consuming and expensive, which could affect the completion schedule and final cost of the project.  Many of Arbuckle Pipeline’s remaining right-of-way tracts are being acquired through a condemnation process, which adds to the cost and time to construct the pipeline.  The demand for surface easements has increased dramatically in Texas and Oklahoma in the last 12 to 18 months because of increased oil and natural gas exploration and production activities, as well as pipeline construction.  Because of the delays associated with right-of-way acquisition, we anticipate construction on the south end of the project will be more difficult and expensive due to wet low-lying areas and potential for spring rains.  Accordingly, we expect the project to be operational in the second quarter of 2009.  Based on the increased costs and delays associated with right-of-way acquisition and potential weather impacts, our project costs could increase 10 percent to 15 percent above the range of $340 million to $360 million, excluding AFUDC, as previously reported.

Williston Basin Gas Processing Plant Expansion - In March 2007, ONEOK Partners announced the expansion of its Grasslands natural gas processing facility in North Dakota, currently estimated to cost in the range of $40 million to $45 million, excluding AFUDC.  ONEOK Partners’ estimated project costs increased from $30 million primarily as a result of higher contract labor and equipment costs.  The Grasslands facility is ONEOK Partners’ largest natural gas processing plant in the Williston Basin.  The expansion increases processing capacity to approximately 100 MMcf/d from its current capacity of 63 MMcf/d and increases fractionation capacity to approximately 12 MBbl/d from 8 MBbl/d.  The construction of the expansion project is expected to be complete in the first quarter of 2009.

Fort Union Gas Gathering Expansion - In January 2007, Fort Union Gas Gathering announced plans to double its existing gathering pipeline capacity by adding 148 miles of new gathering lines, resulting in approximately 649 MMcf/d of additional capacity in the Powder River basin of Wyoming.  The expansion occurred in two phases and cost approximately $121 million, excluding AFUDC, which was financed within the Fort Union Gas Gathering partnership.  Any cost overruns are covered through escalation clauses to preserve the original economics of the project.  Phase I, with more than 200 MMcf/d


capacity, was placed in service during the fourth quarter of 2007.  Phase II, with approximately 450 MMcf/d capacity, was completed in July 2008.  The additional capacity has been fully subscribed for 10 years.  ONEOK Partners owns approximately 37 percent of Fort Union Gas Gathering, and accounts for its ownership under the equity method of accounting.

Guardian Pipeline Expansion and Extension - In December 2007, Guardian Pipeline received and accepted the certificate of public convenience and necessity issued by the FERC for its expansion and extension project.  The certificate authorizes ONEOK Partners to construct, install and operate approximately 119 miles of a 20-inch and 30-inch natural gas transportation pipeline with a capacity to transport 537 MMcf/d of natural gas north from Ixonia, Wisconsin to the Green Bay, Wisconsin, area.  The project is supported by 15-year shipper commitments with We Energies and Wisconsin Public Service Corporation and the capacity has been fully subscribed.  The project is currently estimated to cost in the range of $277 million and $305 million, excluding AFUDC.  ONEOK Partners’ estimated project costs increased from the initial estimate of $241 million in 2006, which excluded AFUDC, primarily due to weather delays, equipment delivery delays, construction in environmentally sensitive areas, rocky terrain, and escalating costs associated with crop damage and condemnation costs.  ONEOK Partners received the notice to proceed from the FERC in May 2008.  On December 22, 2008, the FERC issued a letter order granting Guardian Pipeline’s request for an extension of time for a phased in-service.  On December 29, 2008, the FERC issued a letter order granting Guardian Pipeline’s request to commence service.  On December 31, 2008, the pipeline and seven meter stations were placed into service with the ability to transport natural gas on a limited basis.  Construction on one compressor station is complete, and construction on a second compressor station is near completion.  The project is expected to be fully in service in the first quarter of 2009.

REGULATORY

Several regulatory initiatives positively impacted the earnings and future earnings potential for our Distribution segment.  See discussion of our Distribution segment’s regulatory initiative beginning on page 49.

IMPACT OF NEW ACCOUNTING STANDARDS

Information about the impact of the following new accounting standards is included in Note A of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K:
·  
Statement 123R, “Share-Based Payment;”
·  
Statement 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans;”
·  
FIN 48, “Accounting for Uncertainty in Income Taxes - An Interpretation of FASB Statement No. 109;”
·  
Statement 157, “Fair Value Measurements,” and related FASB Staff Position (FSP) 157-2, “Effective Date of FASB Statement no. 157,” and FSP 157-3, “Determining the Fair Value of a Financial Asset When the Market for That Asset Is Not Active;”
·  
Statement 159, “The Fair Value Option for Financial Assets and Financial Liabilities;”
·  
FSP FIN 39-1, “Amendment of FASB Interpretation No. 39;”
·  
Statement 141R, “Business Combinations;”
·  
Statement 160, “Noncontrolling Interest in Consolidated Financial Statements - an amendment to ARB No. 51;”
·  
Statement 161, “Disclosures about Derivative Instruments and Hedging Activities - an amendment to FASB Statement No. 133;”
·  
EITF 08-6, “Equity Method Investment Accounting Considerations;” and
·  
Statement 132R-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets.”

CRITICAL ACCOUNTING ESTIMATES

The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amount of assets and liabilities, and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements.  These estimates and assumptions also affect the reported amounts of revenue and expenses during the reporting period.  Although we believe these estimates and assumptions are reasonable, actual results could differ from our estimates.

The following is a summary of our most critical accounting estimates, which are defined as those estimates most important to the portrayal of our financial condition and results of operations and requiring management’s most difficult, subjective or complex judgment, particularly because of the need to make estimates concerning the impact of inherently uncertain matters.  We have discussed the development and selection of our critical accounting policies and estimates with the Audit Committee of our Board of Directors.


Fair Value Measurements -   General - In September 2006, the FASB issued Statement 157 that establishes a framework for measuring fair value and requires additional disclosures about fair value measurements.  Beginning January 1, 2008, we partially applied Statement 157 as allowed by FSP 157-2 that delayed the effective date of Statement 157 for nonrecurring fair value measurements associated with our nonfinancial assets and liabilities.  As of January 1, 2008, we applied the provisions of Statement 157 to our recurring fair value measurements, and the impact was not material upon adoption.  As of January 1, 2009, we have applied the provisions of Statement 157 to our nonrecurring fair value measurements associated with our nonfinancial assets and liabilities, and the impact was not material.  FSP 157-3, which clarified the application of Statement 157 in inactive markets, was issued in October 2008 and was effective for our September 30, 2008, consolidated financial statements.  FSP 157-3 did not have a material impact on our consolidated financial statements.

In February 2007, the FASB issued Statement 159 that allows companies to elect to measure specified financial assets and liabilities, firm commitments, and nonfinancial warranty and insurance contracts at fair value on a contract-by-contract basis, with changes in fair value recognized in earnings each reporting period.  At January 1, 2008, we did not elect the fair value option under Statement 159, and therefore there was no impact on our consolidated financial statements.

Determining Fair Value - Statement 157 defines fair value as the price that would be received to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date.  We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed.  While many of the contracts in our portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist but the market may be relatively inactive.  This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  Inputs into our fair value estimates include commodity exchange prices, over-the-counter quotes, volatility, historical correlations of pricing data and LIBOR and other liquid money market instrument rates.  We also utilize internally developed basis curves that incorporate observable and unobservable market data.  We validate our valuation inputs with third-party information and settlement prices from other sources, where available.  In addition, as prescribed by the income approach, we compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value.  The interest rate yields used to calculate the present value discount factors are derived from LIBOR, Eurodollar futures and Treasury swaps.  The projected cash flows are then multiplied by the appropriate discount factors to determine the present value or fair value of our derivative instruments.  We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions.  Finally, we consider credit risk of our counterparties on the fair value of our derivative assets, as well as our own credit risk for derivative liabilities, using default probabilities and recovery rates, net of collateral.  We also take into consideration current market data in our evaluation when available, such as bond prices and yields and credit default swaps.  Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.

Fair Value Hierarchy - Statement 157 establishes the fair value hierarchy that prioritizes inputs to valuation techniques based on observable and unobservable data and categorizes the inputs into three levels, with the highest priority given to Level 1 and the lowest priority given to Level 3.  The levels are described below.
·  
Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities;
·  
Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are either directly or indirectly observable as of the reporting date.  Essentially, this represents inputs that are derived principally from or corroborated by observable market data; and
·  
Level 3 - Generally unobservable inputs, which are developed based on the best information available and may include our own internal data.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data.  Transfers in and out of Level 3 typically result from derivatives for which fair value is determined based on multiple inputs.  If prices change for a particular input from the previous measurement date to the current measurement date, the impact could result in the derivative being moved between Level 2 and Level 3, depending upon management judgment of the significance of the price change of that particular input to the total fair value of the derivative.  

See Note C of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for more discussion of fair value measurements.

Derivatives, Accounting for Financially Settled Transactions and Risk Management Activities - We engage in wholesale energy marketing, retail marketing, trading and risk management activities.  We account for derivative instruments utilized in connection with these activities and services in accordance with Statement 133, as amended.


Under Statement 133, entities are required to record derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery.  See previous discussion in “Fair Value Measurements” for additional information.  Market value changes result in a change in the fair value of our derivative instruments.  The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the nature of the risk being hedged and how we will determine if the hedging instrument is effective.  If the derivative instrument does not qualify or is not designated as part of a hedging relationship, then we account for changes in fair value of the derivative in earnings as they occur.  Commodity price volatility may have a significant impact on the gain or loss in any given period.  For more information on fair value sensitivity and a discussion of the market risk of pricing changes, see Item 7A, Quantitative and Qualitative Disclosures about Market Risk.

To reduce our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter into futures, forwards, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs and condensate and fuel requirements.  Interest-rate swaps are also used to manage interest-rate risk.  Under certain conditions, we designate these derivative instruments as a hedge of exposure to changes in fair values or cash flow.  For hedges of exposure to changes in cash flow, the effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) and is subsequently recorded to earnings when the forecasted transaction affects earnings.  Any ineffectiveness of designated hedges is reported in earnings during the period the ineffectiveness occurs.  For hedges of exposure to changes in fair value, the gain or loss on the derivative instrument is recognized in earnings during the period of change together with the offsetting gain or loss on the hedged item attributable to the risk being hedged.

Upon election, many of our purchase and sale agreements that otherwise would be required to follow derivative accounting qualify as normal purchases and normal sales under Statement 133 and are therefore exempt from fair value accounting treatment.

The presentation of settled derivative instruments on either a gross or net basis in our Consolidated Statements of Income is dependent on a number of factors, including whether the derivative instrument (i) is held for trading purposes; (ii) is financially settled; (iii) results in physical delivery or services rendered; and (iv) qualifies for the normal purchase or sale exception as defined in Statement 133.  In accordance with EITF 03-11, “Reporting Realized Gains and Losses on Derivative Instruments That Are Subject to FASB Statement No. 133 and not ‘Held for Trading’ as Defined in EITF Issue No. 02-3,” EITF 99-19, “Reporting Revenue Gross as a Principal versus Net as an Agent,” and Statement 133, we report settled derivative instruments as follows:
·  
all financially settled derivative contracts are reported on a net basis;
·  
derivative instruments considered held for trading purposes that result in physical delivery are reported on a net basis;
·  
derivative instruments not considered held for trading purposes that result in physical delivery or services rendered are reported on a gross basis; and
·  
derivatives that qualify for the normal purchase or sale exception as defined in Statement 133 are reported on a gross basis.

We apply the indicators in EITF 99-19 to determine the appropriate accounting treatment for non-derivative contracts that result in physical delivery.

See Note D of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional discussion of derivatives and risk management activities.

Impairment of Long-Lived Assets, Goodwill and Intangible Assets - We assess our long-lived assets for impairment based on Statement 144, “Accounting for the Impairment or Disposal of Long-Lived Assets.”  A long-lived asset is tested for impairment whenever events or changes in circumstances indicate that its carrying amount may exceed its fair value.  Fair values are based on the sum of the undiscounted future cash flows expected to result from the use and eventual disposition of the assets.

We assess our goodwill and indefinite-lived intangible assets for impairment at least annually based on Statement 142, “Goodwill and Other Intangible Assets.”  There were no impairment charges resulting from our July 1, 2008, impairment test.  As a result of recent events in the financial markets and current economic conditions, we performed a review and determined that interim testing of goodwill as of December 31, 2008, was not necessary.  As a part of our impairment test, an initial assessment is made by comparing the fair value of a reporting unit with its book value, including goodwill.  If the fair value is less than the book value, an impairment is indicated, and we must perform a second test to measure the amount of the


impairment.  In the second test, we calculate the implied fair value of the goodwill by deducting the fair value of all tangible and intangible net assets of the reporting unit from the fair value determined in step one of the assessment.  If the carrying value of the goodwill exceeds the implied fair value of the goodwill, we will record an impairment charge.

We use two generally accepted valuation approaches, an income approach and a market approach, to estimate the fair value of a reporting unit.  Under the income approach, we use anticipated cash flows over a three-year period plus a terminal value and discount these amounts to their present value using appropriate rates of return.  Under the market approach, we apply multiples to forecasted EBITDA amounts.  The multiples used are consistent with historical asset transactions, and the EBITDA amounts are based on average EBITDA for a reporting unit over a three-year forecasted period.  At December 31, 2008 we had $602.8 million of goodwill recorded on our Consolidated Balance Sheet as shown below.
                 
      (Thousands of dollars)
ONEOK Partners
      $ 433,537        
Distribution
        157,953        
Energy Services
        10,255        
Other
        1,099        
Total goodwill
      $ 602,844        

Intangible assets with a finite useful life are amortized over their estimated useful life, while intangible assets with an indefinite useful life are not amortized.  All intangible assets are subject to impairment testing.  We had $435.4 million of intangible assets recorded on our Consolidated Balance Sheet as of December 31, 2008, of which $279.8 million in our ONEOK Partners segment is being amortized over an aggregate weighted-average period of 40 years, while the remaining balance has an indefinite life.

Our impairment tests require the use of assumptions and estimates.  If actual results are not consistent with our assumptions and estimates or our assumptions and estimates change due to new information, we may be exposed to an impairment charge.

During 2006, we recorded a goodwill and asset impairment related to ONEOK Partners’ Black Mesa Pipeline of $8.4 million and $3.6 million, respectively, which was recorded as depreciation and amortization.  The reduction to our net income, net of minority interests and income taxes, was $3.0 million.

For the investments we account for under the equity method, the premium or excess cost over underlying fair value of net assets is referred to as equity method goodwill and under Statement 142, is not subject to amortization but rather to impairment testing pursuant to APB Opinion No. 18, “The Equity Method of Accounting for Investments in Common Stock.”  The impairment test under APB Opinion No. 18 considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary.  Therefore, we periodically reevaluate the amount at which we carry the excess of cost over fair value of net assets accounted for under the equity method to determine whether current events or circumstances warrant adjustments to our carrying value in accordance with APB Opinion No. 18.  

Pension and Postretirement Employee Benefits - We have defined benefit retirement plans covering certain full-time employees.  We sponsor welfare plans that provide postretirement medical and life insurance benefits to certain employees who retire with at least five years of service.  Our actuarial consultant calculates the expense and liability related to these plans and uses statistical and other factors that attempt to anticipate future events.  These factors include assumptions about the discount rate, expected return on plan assets, rate of future compensation increases, age and employment periods.  In determining the projected benefit obligations and costs, assumptions can change from period to period and result in material changes in the costs and liabilities we recognize.  See Note J of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional information.

Assumed health care cost trend rates have a significant effect on the amounts reported for our health care plans.  A one-percentage point change in assumed health care cost trend rates would have the following effects.

   
One-Percentage
   
One-Percentage
 
   
Point Increase
   
Point Decrease
 
   
(Thousands of dollars)
Effect on total of service and interest cost
  $ 1,989       $ (1,706 )  
Effect on postretirement benefit obligation
  $ 19,585       $ (17,171 )  



During 2008, we recorded net periodic benefit costs of $19.8 million related to our defined benefit pension plans and $28.3 million related to postretirement benefits.  We estimate that in 2009, we will record net periodic benefit costs of $26.6 million related to our defined benefit pension plans and $26.1 million related to postretirement benefits.  In determining our estimated expenses for 2009, our actuarial consultant assumed an 8.50 percent expected return on plan assets and a discount rate of 6.25 percent.  A decrease in our expected return on plan assets to 8.25 percent would increase our 2009 estimated net periodic benefit costs by approximately $1.9 million for our defined benefit pension plans and would not have a significant impact on our postretirement benefit plan.  A decrease in our assumed discount rate to 6.00 percent would increase our 2009 estimated net periodic benefit costs by approximately $2.4 million for our defined benefit pension plans and $0.6 million for our postretirement benefit plan.  For 2009, we anticipate our total contributions to our defined benefit pension plans and postretirement benefit plan to be $31.2 million and $11.4 million, respectively, and the expected benefit payments for our postretirement benefit plan are estimated to be $16.2 million.

Contingencies - Our accounting for contingencies covers a variety of business activities, including contingencies for legal and environmental exposures.  We accrue these contingencies when our assessments indicate that it is probable that a liability has been incurred or an asset will not be recovered, and an amount can be reasonably estimated in accordance with Statement 5, “Accounting for Contingencies.”  We base our estimates on currently available facts and our estimates of the ultimate outcome or resolution.  Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remediation feasibility study.  Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is deemed probable.  Actual results may differ from our estimates resulting in an impact, positive or negative, on earnings.  See Note K of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional discussion of contingencies.

FINANCIAL RESULTS AND OPERATING INFORMATION

Consolidated Operations

Selected Financial Results - The following table sets forth certain selected financial results for the periods indicated.
 
               
Variances
   
Variances
 
   
Years Ended December 31,
 
2008 vs. 2007
   
2007 vs. 2006
 
Financial Results
 
2008
 
2007
 
2006
 
Increase (Decrease)
   
Increase (Decrease)
 
   
(Millions of dollars)
 
Revenues
  $ 16,157.4   $ 13,477.4   $ 11,920.3   $ 2,680.0   20 %   $ 1,557.1   13 %
Cost of sales and fuel
    14,221.9     11,667.3     10,198.3     2,554.6   22 %     1,469.0   14 %
Net margin
    1,935.5     1,810.1     1,722.0     125.4   7 %     88.1   5 %
Operating costs
    776.9     761.5     740.8     15.4   2 %     20.7   3 %
Depreciation and amortization
    243.9     228.0     235.5     15.9   7 %     (7.5 ) (3 %)
Gain (loss) on sale of assets
    2.3     1.9     116.5     0.4   21 %     (114.6 ) (98 %)
Operating income
  $ 917.0   $ 822.5   $ 862.2   $ 94.5   11 %   $ (39.7 ) (5 %)
Equity earnings from investments
  $ 101.4   $ 89.9   $ 95.9   $ 11.5   13 %   $ (6.0 ) (6 %)
Allowance for equity funds used
     during construction
  $ 50.9   $ 12.5   $ 2.2   $ 38.4   *     $ 10.3   *  
Other income (expense)
  $ (10.6 ) $ 14.1   $ 1.9   $ (24.7
)
*     $ 12.2   *  
Interest expense
  $ (264.2 ) $ (256.3 ) $ (239.7 ) $ 7.9   3 %   $ 16.6   7 %
Minority interests in income of
     consolidated subsidiaries
  $ (288.6 ) $ (193.2 ) $ (222.0 ) $ 95.4   49 %   $ (28.8 ) (13 %)
Capital expenditures
  $ 1,473.1   $ 883.7   $ 376.3   $ 589.4   67 %   $ 507.4   *  
                                           
* Percentage change is greater than 100 percent.
                   
 
2008 vs. 2007 - Net margin increased primarily due to wider NGL product price differentials, higher realized commodity prices, incremental net margin associated with the assets acquired from Kinder Morgan, and increased NGL gathering and fractionation volumes, all in our ONEOK Partners segment.  Additionally, net margin increased due to implementation of new rate mechanisms in our Distribution segment.  These increases were partially offset by decreases in storage and marketing margins and transportation margins, net of hedging activities, in our Energy Services segment.



Operating costs increased primarily due to incremental operating expenses associated with the assets acquired from Kinder Morgan, outside services primarily associated with scheduled maintenance expenses at ONEOK Partners’ Medford and Mont Belvieu fractionators, and chemical costs.  Operating costs also increased due to costs associated with the startup of the newly expanded Bushton fractionator and Overland Pass Pipeline, both in our ONEOK Partners segment.

Depreciation and amortization increased primarily due to the assets acquired from Kinder Morgan and depreciation expense associated with ONEOK Partners’ completed capital projects.  Additionally, our Distribution segment had an increase in depreciation and amortization, primarily due to additional investment in property, plant and equipment.

Equity earnings from investments increased primarily due to ONEOK Partners’ share of the gain on the sale of Bison Pipeline LLC by Northern Border Pipeline and ONEOK Partners’ earnings related to higher gathering revenues in its natural gas gathering and processing business’ various investments, partially offset by reduced throughput on Northern Border Pipeline.  ONEOK Partners owns a 50 percent equity interest in Northern Border Pipeline.

Allowance for equity funds used during construction and capital expenditures increased due to ONEOK Partners’ capital projects.

Other income (expense) fluctuated primarily due to investment gains (losses) and fluctuations in interest income.  In addition, other income (expense) was impacted by realized and unrealized gains on available-for-sale securities sold and transferred to trading.  Our available-for-sale securities were reclassified to trading securities due to a reconsideration event in August 2008 when our NYMEX Holding, Inc. Class A shares held were converted to CME Group, Inc. (CME) Class A shares, due to the NYMEX Holding, Inc. and CME merger.  A modification was made to the number of shares required to be maintained by NYMEX Holding, Inc. Class A Members, which resulted in our sale of certain shares and the reclassification of the remaining shares to trading.

Interest expense increased primarily due to increased borrowings to fund ONEOK Partners’ capital projects.

Minority interest in income of consolidated subsidiaries for 2008 and 2007 reflects the remaining 52.3 percent and 54.3 percent, respectively, of ONEOK Partners that we did not own.  The increase in minority interest is due to the increase in income for our ONEOK Partners segment, partially offset by our increased equity ownership interest in ONEOK Partners.

2007 vs. 2006 - Net margin increased primarily due to the implementation of new rate schedules in Kansas and Texas in our Distribution segment.  Net margin was also positively impacted by our ONEOK Partners segment due to its natural gas liquids businesses, which benefited primarily from new supply connections that increased volumes gathered, transported, fractionated and sold.  Net margin also increased due to ONEOK Partners’ natural gas liquids gathering and fractionation business benefiting from higher product price differentials and higher isomerization price differentials, as well as the incremental net margin related to the assets acquired from Kinder Morgan in October 2007.  These increases were offset by decreased transportation margins in our Energy Services segment and decreased net margin in ONEOK Partners’ natural gas gathering and processing business, primarily due to lower natural gas volumes processed as a result of contract terminations in late 2006.

Gain on sale of assets decreased primarily due to the $113.9 million gain on sale of a 20 percent partnership interest in Northern Border Pipeline recorded in the second quarter of 2006 in our ONEOK Partners segment.

Equity earnings from investments decreased primarily due to the decrease in ONEOK Partners’ share of Northern Border Pipeline’s earnings from 70 percent in the first quarter of 2006 to 50 percent beginning in the second quarter of 2006.

Allowance for equity funds used during construction and capital expenditures increased due to ONEOK Partners’ capital projects.

Other income (expense) fluctuated primarily due to increased civic donations and expenses incurred by ONEOK Partners in 2006 related to costs associated with transitioning operations from Omaha, Nebraska.

Interest expense increased primarily due to the additional borrowings by ONEOK Partners to complete the April 2006 transactions with us.  The additional borrowings resulted in $21.3 million in higher interest expense in the first quarter of 2007.  Increased interest expense was partially offset by lower interest expense on ONEOK’s short-term debt of $11.8 million during 2007, as a result of the proceeds from the sale of assets to ONEOK Partners, which reduced ONEOK’s short-term debt.



Minority interest in income of consolidated subsidiaries for 2007 and 2006 reflects the remaining 54.3 percent of ONEOK Partners that we did not own.  For 2007, minority interest was lower due to the $113.9 million gain on sale of a 20 percent partnership interest in Northern Border Pipeline recorded in the second quarter of 2006 in our ONEOK Partners segment.  Additionally, minority interest in net income of consolidated subsidiaries for our ONEOK Partners’ segment for 2006 included the 66-2/3 percent interest in Guardian Pipeline that ONEOK Partners did not own until April 2006.  ONEOK Partners owned 100 percent of Guardian Pipeline beginning in April 2006, resulting in no minority interest in income of consolidated subsidiaries related to Guardian Pipeline after March 31, 2006.

More information regarding our results of operations is provided in the following discussion of operating results for each of our segments.

ONEOK Partners

Selected Financial Results and Operating Information - The following tables set forth certain selected financial results and operating information for our ONEOK Partners segment for the periods indicated.

               
Variances
   
Variances
 
 
Years Ended December 31,
 
2008 vs. 2007
   
2007 vs. 2006
 
Financial Results
 
2008
 
2007
 
2006
 
Increase (Decrease)
   
Increase (Decrease)
 
 
(Millions of dollars)
 
Revenues
  $ 7,720.2   $ 5,831.6   $ 4,738.2   $ 1,888.6   32 %   $ 1,093.4   23 %
Cost of sales and fuel
    6,579.5     4,935.7     3,894.7     1,643.8   33 %     1,041.0   27 %
Net margin
    1,140.7     895.9     843.5     244.8   27 %     52.4   6 %
Operating costs
    371.8     337.4     325.8     34.4   10 %     11.6   4 %
Depreciation and amortization
    124.8     113.7     122.0     11.1   10 %     (8.3 ) (7 %)
Gain on sale of assets
    0.7     2.0     115.5     (1.3 ) (65 %)     (113.5 ) (98 %)
Operating income
  $ 644.8   $ 446.8   $ 511.2   $ 198.0   44 %   $ (64.4 ) (13 %)
Equity earnings from investments
  $ 101.4   $ 89.9   $ 95.9   $ 11.5   13 %   $ (6.0 ) (6 %)
Allowance for equity funds used
     during construction
  $ 50.9   $ 12.5   $ 2.2   $ 38.4   *     $ 10.3   *  
Minority interests in income of
     consolidated subsidiaries
  $ (0.4 ) $ (0.4 ) $ (2.4 ) $ -   0 %   $ 2.0   83 %
Capital expenditures
  $ 1,253.9   $ 709.9   $ 201.7   $ 544.0   77 %   $ 508.2   *  
                                           
* Percentage change is greater than 100 percent.
                                   

   
Years Ended December 31,
 
Operating Information
 
2008
   
2007
   
2006
 
Natural gas gathered (BBtu/d) (a)
    1,164       1,171       1,168  
Natural gas processed (BBtu/d) (a)
    641       621       988  
Natural gas transported (MMcf/d)
    3,665       3,579       3,634  
Residue gas sales (BBtu/d) (a)
    279       281       302  
NGLs gathered (MBbl/d)
    276       248       226  
NGL sales (MBbl/d)
    283       231       207  
NGLs fractionated (MBbl/d)
    373       356       313  
NGLs transported (MBbl/d)
    333       299       200  
Conway-to-Mont Belvieu OPIS average price differential
                       
   Ethane ($/gallon)
  $ 0.15     $ 0.06     $ 0.05  
Realized composite NGL sales prices ($/gallon) (a)
  $ 1.27     $ 1.06     $ 0.93  
Realized condensate sales price ($/Bbl) (a)
  $ 89.30     $ 67.35     $ 57.84  
Realized residue gas sales price ($/MMBtu) (a)
  $ 7.34     $ 6.21     $ 6.31  
Realized gross processing spread ($/MMBtu) (a)
  $ 7.47     $ 5.21     $ 5.05  
(a) - Statistics relate to ONEOK Partners’ natural gas gathering and processing business.
 



2008 vs. 2007 - Net margin increased primarily due to the following:
·  
an increase in ONEOK Partners’ natural gas liquids gathering and fractionation business due to the following:
o  
an increase of $70.8 million in wider NGL product price differentials;
o  
an increase of $32.1 million due to increased NGL gathering and fractionation volumes; and
o  
an increase of $8.4 million in certain operational measurement gains, primarily at NGL storage caverns;
·  
an increase in ONEOK Partners’ natural gas gathering and processing business due to the following:
o  
an increase of $58.4 million due to higher realized commodity prices;
o  
an increase of $11.9 million due to improved contractual terms;
o  
an increase of $7.0 million due to higher volumes sold and processed; partially offset by
o  
a decrease of $8.6 million due to a one-time favorable contract settlement that occurred in the fourth quarter of 2007;
·  
an increase of $44.3 million in incremental margin in ONEOK Partners’ natural gas liquids pipelines business, due to the assets acquired from Kinder Morgan in October 2007, including $10.3 million due to increased throughput during the fourth quarter of 2008, compared with the fourth quarter of 2007;
·  
an increase of $11.7 million due to increased transportation and storage margins primarily as a result of the impact of higher natural gas prices on retained fuel, and new and renegotiated storage contracts in ONEOK Partners’ natural gas pipelines business; and
·  
an increase of $6.9 million primarily due to increased throughput from new NGL supply connections, including $2.6 million from Overland Pass Pipeline, which began operations during the fourth quarter 2008.

Operating costs increased primarily due to incremental operating expenses associated with the assets acquired from Kinder Morgan, outside service costs primarily associated with scheduled maintenance expenses at ONEOK Partners’ Medford and Mont Belvieu fractionators, and chemical costs.  Operating costs also increased due to costs associated with the startup of ONEOK Partners’ newly expanded Bushton fractionator and Overland Pass Pipeline.

Depreciation and amortization increased primarily due to depreciation expense associated with ONEOK Partners’ completed capital projects and the assets acquired from Kinder Morgan.

Equity earnings from investments increased primarily due to higher gathering revenues in ONEOK Partners’ various investments, as well as a $8.3 million gain on the sale of Bison Pipeline LLC by Northern Border Pipeline, partially offset by reduced throughput on Northern Border Pipeline.  ONEOK Partners owns a 50 percent equity interest in Northern Border Pipeline.

Allowance for equity funds used during construction and capital expenditures increased due to ONEOK Partners’ capital projects.

2007 vs. 2006 - Net margin increased primarily due to the following:
·  
an increase of $27.3 million from increased performance of ONEOK Partners’ natural gas liquids businesses, which benefited primarily from new supply connections that increased volumes gathered, transported, fractionated and sold;
·  
an increase of $20.6 million from new and renegotiated contractual terms and increased volumes in ONEOK Partners’ natural gas and natural gas liquids businesses;
·  
an increase of $13.5 million in higher NGL product price differentials and higher isomerization price differentials in ONEOK Partners’ natural gas liquids gathering and fractionation business;
·  
an increase of $11.5 million in incremental net margin in ONEOK Partners’ natural gas liquids pipeline business, due to the assets acquired from Kinder Morgan in October 2007; and
·  
an increase of $5.4 million in storage margins in ONEOK Partners’ natural gas pipelines business; partially offset by
·  
a decrease of $32.9 million in natural gas processing and transportation margins in ONEOK Partners’ natural gas businesses resulting primarily from lower throughput, higher fuel costs and lower volumes processed as a result of various contract terminations.

Operating costs increased primarily due to higher employee-related costs and the incremental operating expenses associated with the assets acquired from Kinder Morgan, partially offset by lower litigation costs.

Depreciation and amortization decreased primarily due to a goodwill and asset impairment charge of $12.0 million recorded in the second quarter of 2006 related to Black Mesa Pipeline.

Gain on sale of assets decreased primarily due to the $113.9 million gain on the sale of a 20 percent partnership interest in Northern Border Pipeline recorded in the second quarter of 2006.


Equity earnings from investments primarily include earnings from ONEOK Partners’ interest in Northern Border Pipeline.  The decrease for 2007 was primarily due to the decrease in ONEOK Partners’ share of Northern Border Pipeline’s earnings from 70 percent in the first quarter of 2006 to 50 percent beginning in the second quarter of 2006.  See page 85 for discussion of the disposition of the 20 percent partnership interest in Northern Border Pipeline.

Allowance for equity funds used during construction and capital expenditures increased due to ONEOK Partners’ capital projects.

Minority interest in income of consolidated subsidiaries decreased primarily due to our acquisition of the remaining interest in Guardian Pipeline.  Minority interest in net income of consolidated subsidiaries for our ONEOK Partners’ segment for 2006 included the 66-2/3 percent interest in Guardian Pipeline that ONEOK Partners did not own until April 2006.  ONEOK Partners owned 100 percent of Guardian Pipeline beginning in April 2006, resulting in no minority interest in income of consolidated subsidiaries related to Guardian Pipeline after March 31, 2006.

Commodity Price Risk - ONEOK Partners is exposed to commodity price risk, primarily from NGLs, as a result of its contractual obligations for services provided.  A small percentage of its services, based on volume, is provided through keep-whole arrangements.  See discussion regarding ONEOK Partners’ commodity price risk beginning on page 63 under “Commodity Price Risk” in Item 7A, Quantitative and Qualitative Disclosures about Market Risk.

Distribution

Selected Financial Results - The following table sets forth certain selected financial results for our Distribution segment for the periods indicated.

               
Variances
   
Variances
 
   
Years Ended December 31,
 
2008 vs. 2007
   
2007 vs. 2006
 
Financial Results
 
2008
 
2007
 
2006
 
Increase (Decrease)
   
Increase (Decrease)
 
   
(Millions of dollars)
 
Gas sales
  $ 2,049.0   $ 1,976.3   $ 1,836.9   $ 72.7   4 %   $ 139.4   8 %
Transportation revenues
    87.3     87.3     88.3     -   0 %     (1.0 ) (1 %)
Cost of gas
    1,496.7     1,435.4     1,358.4     61.3   4 %     77.0   6 %
Net margin, excluding other
    639.6     628.2     566.8     11.4   2 %     61.4   11 %
Other revenues
    41.3     35.4     33.0     5.9   17 %     2.4   7 %
Net margin
    680.9     663.6     599.8     17.3   3 %     63.8   11 %
Operating costs
    375.3     377.8     371.5     (2.5 ) (1 %)     6.3   2 %
Depreciation and amortization
    116.8     111.6     110.9     5.2   5 %     0.7   1 %
Gain (loss) on sale of assets
    -     (0.1 )   -     0.1   100 %     (0.1 ) (100 %)
Operating income
  $ 188.8   $ 174.1   $ 117.4   $ 14.7   8 %   $ 56.7   48 %
Capital expenditures
  $ 169.0   $ 162.0   $ 159.0   $ 7.0   4 %   $ 3.0   2 %
 
2008 vs. 2007 - Net margin increased primarily due to:
·  
an increase of $15.7 million resulting from the implementation of new rate mechanisms, which includes a $12.4 million increase in Oklahoma and a $3.3 million increase in Texas; and
·  
an increase of $2.2 million related to recovery of carrying costs for natural gas in storage.

Operating costs decreased primarily due to:
·  
a decrease of $4.3 million in employee-related costs; and
·  
a decrease of $1.0 million in bad debt expense; partially offset by
·  
an increase of $2.4 million in fuel-related vehicle costs.

Depreciation and amortization increased primarily due to:
·  
an increase of $4.0 million in depreciation expense related to our investment in property, plant and equipment; and
·  
an increase of $1.2 million of regulatory amortization associated with revenue rider recoveries.

2007 vs. 2006 - Net margin increased primarily due to:
·  
an increase of $55.2 million resulting from the implementation of new rate schedules, which includes $51.1 million in Kansas and $4.1 million in Texas; and
·  
an increase of $8.0 million from higher customer sales volumes as a result of a return to more normal weather in our entire service territory.


Operating costs increased primarily due to:
·  
an increase of $4.8 million in bad debt expense, primarily in Oklahoma; and
·  
an increase of $5.3 million due to higher property taxes in Kansas; partially offset by
·  
a decrease of $4.0 million in labor and employee benefit costs.

Capital Expenditures - Our capital expenditure program includes expenditures for extending service to new areas, modifying customer service lines, increasing system capabilities, general replacements and improvements.  It is our practice to maintain and upgrade facilities to ensure safe, reliable and efficient operations.  Our capital expenditure program included $51.8 million, $50.6 million and $54.9 million for new business development in 2008, 2007 and 2006, respectively.

Selected Operating Information - The following tables set forth certain selected operating information for our Distribution segment for the periods indicated.
 
   
Years Ended December 31,
Operating Information
 
2008
 
2007
 
2006
Customers per employee
    719       732       713  
Inventory storage balance (Bcf)
    25.1       22.7       26.3  
 
   
Years Ended December 31,
 
Volumes (MMcf)
 
2008
   
2007
   
2006
 
Gas sales
                 
Residential
    125,834       121,587       110,123  
Commercial
    37,758       37,295       34,865  
Industrial
    1,395       1,758       1,624  
Wholesale
    7,186       13,231       29,263  
Public Authority
    2,592       2,679       2,520  
Total volumes sold
    174,765       176,550       178,395  
Transportation
    219,398       204,049       200,828  
Total volumes delivered
    394,163       380,599       379,223  
 
   
Years Ended December 31,
 
Margin
 
2008
   
2007
   
2006
 
Gas Sales
 
(Millions of dollars)
 
Residential
  $ 444.0     $ 440.9     $ 390.2  
Commercial
    101.3       99.5       88.8  
Industrial
    2.6       2.3       2.9  
Wholesale
    0.6       1.2       4.8  
Public Authority
    3.8       3.7       3.2  
Net margin on gas sales
    552.3       547.6       489.9  
Transportation revenues
    87.3       80.6       76.9  
Net margin, excluding other
  $ 639.6     $ 628.2     $ 566.8  
 
   
Years Ended December 31,
 
Number of Customers
 
2008
   
2007
   
2006
 
Residential
    1,886,118       1,876,054       1,859,480  
Commercial
    159,748       160,517       159,214  
Industrial
    1,420       1,455       1,528  
Wholesale
    28       27       18  
Public Authority
    2,963       2,952       2,645  
Transportation
    10,376       9,762       8,666  
Total customers
    2,060,653       2,050,767       2,031,551  

Residential volumes increased during 2008, compared with 2007, due to colder temperatures in our Oklahoma and Kansas service territories; however, margins were moderated by weather normalization mechanisms.


Residential and commercial volumes increased during 2007, compared with 2006, primarily due to a return to more normal weather from the unseasonably warm weather in 2006.

Wholesale sales represent contracted gas volumes that exceed the needs of our residential, commercial and industrial customer base and are available for sale to other parties.  Wholesale volumes decreased during 2008, compared with 2007 and 2006, due to reduced volumes available for sale.

Public authority natural gas volumes reflect volumes used by state agencies and school districts served by Texas Gas Service.

Transportation margins increased during 2008, compared with 2007, primarily due to increased transportation volumes in Oklahoma and Kansas.

Regulatory Initiatives

Oklahoma - In August 2007, Oklahoma Natural Gas filed an application for authorization of a capital investment recovery mechanism.  In February 2008, the OCC approved a joint stipulation, which allows Oklahoma Natural Gas to collect a rate of return, depreciation and 50 percent of the property tax expense associated with non-revenue producing incremental capital investments since its 2005 rate case.  The rates, which were effective in March 2008, generated margins of approximately $7.7 million in 2008.  In July 2008, Oklahoma Natural Gas filed to increase the capital investment recovery mechanism from $7.6 million to $12.6 million annually.  In October 2008, the parties signed a joint stipulation approving the request, and an administrative law judge of the OCC subsequently recommended approval of the joint stipulation.  The final order was approved by the OCC in December 2008, and the increased recovery level was effective in January 2009.

The OCC has authorized Oklahoma Natural Gas to defer transmission pipeline Integrity Management Program (IMP) costs incurred (inclusive of operations and maintenance expense, depreciation, property taxes and a rate of return) in compliance with the Federal Pipeline Safety Improvement Act of 2002.  On January 31, 2007, Oklahoma Natural Gas filed the first application with the OCC seeking recovery of these costs.  On August 31, 2007, the OCC issued an order approving a stipulation of the parties, which provided for recovery of $7.2 million in IMP deferrals incurred as of July 31, 2007, and these deferrals were recovered during the months of October 2007 through June 2008.

The second IMP application was made at the OCC on January 31, 2008, and covered the IMP deferrals for the months of August through December 2007 and the true-ups associated with the prior recovery period.  This filing also requested $7.2 million to be recovered with a new IMP billing rate to be put in place in July 2008.  The OCC approved this request, and billings under the 2008 IMP application began in July 2008.  The third IMP application was made at the OCC on January 30, 2009, and covered the IMP deferrals for 2008, and the true-ups associated with the prior recovery period.  This filing requests a total of $10.8 million with a new IMP billing rate to be put in place in July 2009.  Oklahoma Natural Gas will continue to defer IMP costs as they are incurred and will make future filings to recover those costs.

In August 2008, Oklahoma Natural Gas filed with the OCC for approval to include the fuel-related portion of bad debts in the Purchased Gas Adjustment mechanism for cost recovery.  In October 2008, all parties signed the joint stipulation approving the request, and an administrative law judge of the OCC subsequently recommended approval of the joint stipulation.  The joint stipulation allows Oklahoma Natural Gas to begin deferring its fuel-related bad debts beginning in January 2009 and to collect those amounts above the levels in base rates through the Purchased Gas Adjustment beginning in January 2010.  The final order was issued by the OCC in December 2008.  The associated deferrals began in January 2009.

In October 2008, a joint application for incentive-based rates was filed by the OCC staff and Oklahoma Natural Gas.  This application proposes that the OCC adopt an incentive-based rate design and more streamlined regulatory process.  If approved, this will provide for more timely rate changes.

Kansas - In October 2006, Kansas Gas Service reached a settlement with the KCC staff and all other parties to increase annual revenues by approximately $52 million.  The terms of the settlement were approved by the KCC in November 2006.  The rate increase is effective for services rendered on or after January 1, 2007.

In August 2008, Kansas Gas Service filed an application with the KCC to impose a surcharge designed to annually collect approximately $2.9 million in costs associated with its Gas System Reliability Surcharge (GSRS) mechanism.  The GSRS mechanism allows natural gas utilities to earn a return and recover carrying costs associated with investments made to comply with state and federal pipeline safety requirements or costs to relocate existing facilities pursuant to requests made by a government entity.  The KCC approved the request in December 2008, with authorized GSRS collections effective with customer billings on January 1, 2009. 


Texas - Texas Gas Service has received several regulatory approvals to implement rate increases in various municipalities in Texas.  A total of $1.7 million in annual rate increases were approved and implemented in 2007.  A total of $5.5 million in annual rate increases were approved and implemented in 2006.

In August 2007, Texas Gas Service filed for a rate adjustment with the city of El Paso, Texas, and the municipalities of Anthony, Clint, Horizon City, Socorro and Vinton.  Texas Gas Service requested a total annual increase of $5.5 million.  In February 2008, the El Paso City Council approved an annual rate increase of approximately $3.1 million.  The increase was effective in February 2008.

In April 2008, the RRC approved a rate increase in our South Texas jurisdiction.  The rate increase was effective May 2008 and will increase revenues by $1.1 million annually.

In May 2008, Texas Gas Service filed for interim rate relief under the Gas Reliability Infrastructure Program with the city of El Paso, Texas, and surrounding communities for approximately $1.1 million.  This program is a capital recovery mechanism that allows for an interim rate adjustment providing recovery and a return on incremental capital investments made between rate cases.  In August 2008, an annual rate increase of approximately $1.0 million was approved; the new rates were effective in September 2008.

In February 2009, Texas Gas Service filed a statement of intent to increase rates in its central Texas service area for approximately $3.6 million.  If approved, new rates are expected to become effective in June 2009.

General - Certain costs to be recovered through the ratemaking process have been recorded as regulatory assets in accordance with Statement 71, “Accounting for the Effects of Certain Types of Regulation.”  Should recovery cease due to regulatory actions, certain of these assets may no longer meet the criteria of Statement 71, and accordingly, a write-off of regulatory assets and stranded costs may be required.

Energy Services

Selected Financial Results - The following table sets forth certain selected financial results for our Energy Services segment for the periods indicated.

               
Variances
   
Variances
 
   
Years Ended December 31,
 
2008 vs. 2007
   
2007 vs. 2006
 
Financial Results
 
2008
 
2007
 
2006
 
Increase (Decrease)
   
Increase (Decrease)
 
   
(Millions of dollars)
 
Revenues
  $ 7,585.8   $ 6,629.4   $ 6,335.8   $ 956.4   14 %   $ 293.6   5 %
Cost of sales and fuel
    7,475.1     6,382.0     6,062.0     1,093.1   17 %     320.0   5 %
Net margin
    110.7     247.4     273.8     (136.7 ) (55 %)     (26.4 ) (10 %)
Operating costs
    35.6     39.9     42.5     (4.3 ) (11 %)     (2.6 ) (6 %)
Depreciation and amortization
    0.9     2.1     2.1     (1.2 ) (57 %)     -   0 %
Gain on sale of assets
    1.5     -     -     1.5   100 %     -   0 %
Operating income
  $ 75.7   $ 205.4   $ 229.2   $ (129.7 ) (63 %)   $ (23.8 ) (10 %)
Capital expenditures
  $ 0.1   $ 0.2   $ -   $ (0.1 ) (50 %)   $ 0.2   100 %

Energy markets were affected by higher commodity prices during 2008, compared with 2007.  The increase in commodity prices had a direct impact on our revenues and the cost of sales and fuel.

2008 vs. 2007 - Net margin decreased primarily due to the following:
·  
a net decrease of $40.3 million in transportation margins, net of hedging activities, primarily due to decreased basis differentials between the Rocky Mountain and Mid-Continent regions, and increased transportation-related costs in 2008;
·  
a decrease of $13.9 million in financial trading margins; and
·  
a net decrease of $83.3 million in storage and marketing margins, net of hedging activities, primarily due to:
o  
a net decrease of $87.3 million in physical storage margins net of hedging activities, as a result of:
·  
hedging opportunities associated with weather related events that led to higher storage margins in 2007 compared with 2008;


·  
lower 2008 storage margins related to storage risk management positions and the impact of changes in natural gas prices on these positions; and
·  
fewer opportunities to optimize storage capacity due to the significant decline in natural gas prices in the second half of 2008;
o  
a  decrease of $9.7 million in physical storage margins due to a lower of cost or market write-down on natural gas inventory; and
o  
a decrease of $2.1 million due to colder than anticipated weather and market conditions that increased the supply cost of managing our peaking and load-following services and provided fewer opportunities to increase margins through optimization activities, primarily in the first quarter of 2008; partially offset by
o  
an increase of $15.8 million from changes in the unrealized fair value of derivative instruments associated with storage and marketing activities and improved marketing margins, which benefited from price movements and optimization activities.

Operating costs decreased primarily due to lower employee-related costs and depreciation expense.

2007 vs. 2006 - Net margin decreased primarily due to:
·  
a decrease of $22.0 million in transportation margins, net of hedging activities, associated with changes in the unrealized fair value of derivative instruments and the impact of a force majeure event on the Cheyenne Plains Gas Pipeline, as more fully described below;
·  
a decrease of $5.0 million in retail activities from lower physical margins due to market conditions and increased competition;
·  
a decrease of $4.3 million in financial trading margins that was partially offset by
·  
an increase of $4.9 million in storage and marketing margins, net of hedging activities, related to:
o  
an increase in physical storage margins, net of hedging activity, due to higher realized seasonal storage spreads and optimization activities; partially offset by
o  
a decrease in marketing margins; and
o  
a net increase in the cost associated with managing our peaking and load following services, slightly offset by higher demand fees collected for these services.

In September 2007, a portion of the volume contracted under our firm transportation agreement with Cheyenne Plains Gas Pipeline Company was curtailed due to a fire at a Cheyenne Plains pipeline compressor station.  The fire damaged a significant amount of instrumentation and electrical wiring, causing Cheyenne Plains Gas Pipeline Company to declare a force majeure event on the pipeline.  This firm commitment was hedged in accordance with Statement 133.  The discontinuance of fair value hedge accounting on the portion of the firm commitment that was impacted by the force majeure event resulted in a loss of approximately $5.5 million that was recognized in the third quarter of 2007, of which $2.4 million of insurance proceeds were recovered and recognized in the first quarter of 2008.  Cheyenne Plains Gas Pipeline Company resumed full operations in November 2007.

Operating costs decreased primarily due to decreased legal and employee-related costs, and reduced ad-valorem tax expense.

Selected Operating Information - The following table sets forth certain selected operating information for our Energy Services segment for the periods indicated.
 
   
Years Ended December 31,
 
Operating Information
 
2008
   
2007
   
2006
 
Natural gas marketed (Bcf)
    1,160       1,191       1,132  
Natural gas gross margin ($/Mcf)
  $ 0.07     $ 0.19     $ 0.22  
Physically settled volumes (Bcf)
    2,359       2,370       2,288  

Our natural gas in storage at December 31, 2008, was 81.9 Bcf, compared with 66.7 Bcf at December 31, 2007.  At December 31, 2008, our total natural gas storage capacity under lease was 91 Bcf, compared with 96 Bcf at December 31, 2007.

Natural gas volumes marketed decreased slightly during 2008, compared with 2007, due to increased injections in the third quarter of 2008.  In addition, demand for natural gas was impacted by weather-related events in the third quarter of 2008, including a 15 percent decrease in cooling degree-days and demand disruption caused by Hurricane Ike.


Natural gas volumes marketed increased during 2007, compared with 2006, due to an increase in sales activity in the southeastern United States in the third quarter of 2007.  Natural gas volumes were also impacted by a 14 percent increase in heating degree-days in our service territory, compared with the same period in 2006.

The acquisition of natural gas storage capacity is more competitive as a result of new market entrants.  The increased demand for storage capacity has resulted in an increase in both the cost of leasing storage capacity and the required term of the lease.  Longer terms and increased costs for storage capacity leases could result in significant increases in the cost of our contractual commitments.

The following table shows our margins by activity for the periods indicated.
 
 
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
 
(Millions of dollars)
 
Marketing, storage and transportation, gross
  $ 313.4     $ 409.1     $ 414.9  
Less:  Storage and transportation costs
    (219.8 )     (191.9 )     (180.7 )
   Marketing, storage and transportation, net
    93.6       217.2       234.2  
Retail marketing
    14.8       14.0       19.0  
Financial trading
    2.3       16.2       20.6  
Net margin
  $ 110.7     $ 247.4     $ 273.8  

Marketing, storage and transportation, net, primarily includes physical marketing, purchases and sales, firm storage and transportation capacity expense, including the impact of cash flow and fair value hedges, and other derivative instruments used to manage our risk associated with these activities.  Risk management and operational decisions have a significant impact on the net result of our marketing and storage activities.  Origination gains are also a component of marketing activity, which is the fair value recognition of contracts that our wholesale marketing department structures to meet the risk management needs of our customers.

Retail marketing includes revenues from providing physical marketing and supply services, coupled with risk management services, to residential, municipal, and small commercial and industrial customers.

Financial trading margin includes activities that are generally executed using financially settled derivatives.  These activities are normally short term in nature, with a focus on capturing short-term price volatility.  Revenues in our Consolidated Statements of Income include financial trading margins, as well as certain physical natural gas transactions with our trading counterparties.  Revenues and cost of sales and fuel from such physical transactions are required to be reported on a net basis.

Contingencies

Legal Proceedings - We are a party to various litigation matters and claims that are normal in the course of our operations.  While the results of litigation and claims cannot be predicted with certainty, we believe the final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or liquidity.

FERC Matter - As a result of a transaction that was brought to the attention of one of our affiliates by a third party, we conducted an internal review of transactions that may have violated FERC natural gas capacity release rules or related rules and determined that there were transactions that should be disclosed to the FERC.  We notified the FERC of this review and filed a report with the FERC regarding these transactions in March 2008.  We cooperated fully with the FERC in its investigation of this matter and have taken steps to better ensure that current and future transactions comply with applicable FERC regulations by implementing a compliance plan dealing with capacity release.  We entered into a global settlement with the FERC to resolve this matter and other FERC enforcement matters, which was approved by the FERC on January 15, 2009.  The global settlement provides for a total civil penalty of $4.5 million and approximately $2.2 million in disgorgement of profits and interest, of which $1.7 million of the civil penalty was allocated to ONEOK Partners.  The amounts were recorded as a liability on our Consolidated Balance Sheet as of December 31, 2008.  We made the required payments in January 2009.



LIQUIDITY AND CAPITAL RESOURCES

General - Part of our strategy is to grow through acquisitions and internally generated growth projects that strengthen and complement our existing assets.  We have relied primarily on operating cash flow, borrowings from commercial paper and credit agreements, and issuance of debt and equity in the capital markets for our liquidity and capital resource requirements.  We expect to continue to use these sources for liquidity and capital resource needs on both a short- and long-term basis.  We have no material guarantees of debt or other similar commitments to unaffiliated parties.

During 2008 and continuing into 2009, the capital markets experienced volatility and disruption, which could limit our access to those markets or increase the cost of issuing new securities in the future.  Higher commodity prices and wider basis differentials, particularly in 2008, have also resulted in higher collateral requirements and natural gas inventory costs in our Energy Services segment.  Throughout this period, ONEOK has continued to have access to its $1.2 billion revolving credit agreement (ONEOK Credit Agreement); also, ONEOK Partners has continued to have access to the ONEOK Partners Credit Agreement, which has been adequate to fund short-term liquidity needs.  In addition, beginning in August 2008, ONEOK had access to its new short-term credit agreement.  In the third quarter of 2008, ONEOK began to utilize both of its credit agreements and lessened its use of commercial paper due to decreased liquidity and rising costs in the commercial paper market.  See discussion below under “Short-term Liquidity.”  Also in 2008, ONEOK Partners issued common units and received additional contributions from ONEOK Partners GP.  See discussion below under “Long-term Financing.”

We expect continued deteriorating economic conditions in 2009, with downward pressures, relative to 2008, on commodity prices.  We also expect continued volatility and disruption in the financial markets, which could result in an increased cost of capital.  ONEOK and ONEOK Partners’ ability to continue to access capital markets for debt and equity financing under reasonable terms depends on the Company’s and Partnership’s respective financial condition, credit ratings and market conditions.  ONEOK and ONEOK Partners anticipate that cash flow generated from operations, existing capital resources and ability to obtain financing will enable both to maintain current levels of operations and planned operations, collateral requirements and capital expenditures.

Capitalization Structure - The following table sets forth our capitalization structure for the periods indicated.
 
 
Years Ended December 31,
   
2008
 
2007
 
Long-term debt
 
67%
 
70%
 
Equity
 
33%
 
30%
 
           
Debt (including notes payable)
 
76%
 
71%
 
Equity
 
24%
 
29%
 

ONEOK does not guarantee the debt of ONEOK Partners.  For purposes of determining compliance with financial covenants in the ONEOK Credit Agreement and ONEOK’s $400 million 364-day revolving credit facility dated August 6, 2008 (the 364-Day Facility), the debt of ONEOK Partners is excluded.  At December 31, 2008, ONEOK’s capitalization structure, excluding the debt of ONEOK Partners, was 44 percent long-term debt and 56 percent equity, compared with 51 percent long-term debt and 49 percent equity at December 31, 2007.  At December 31, 2008, ONEOK’s capitalization structure, including notes payable and excluding the debt of ONEOK Partners, was 59 percent debt and 41 percent equity, compared with 52 percent debt and 48 percent equity at December 31, 2007.  In February 2008, ONEOK repaid $402.3 million of maturing long-term debt with cash from operations and short-term borrowings.  In February 2009, ONEOK repaid $100 million of maturing long-term debt with cash from operations and short-term borrowings.

Cash Management - ONEOK and ONEOK Partners each use similar centralized cash management programs that concentrate the cash assets of their operating subsidiaries in joint accounts for the purpose of providing financial flexibility and lowering the cost of borrowing, transaction costs and bank fees.  Both centralized cash management programs provide that funds in excess of the daily needs of the operating subsidiaries are concentrated, consolidated or otherwise made available for use by other entities within the respective consolidated groups.  ONEOK Partners’ operating subsidiaries participate in these programs to the extent they are permitted under FERC regulations.  Under these cash management programs, depending on whether a participating subsidiary has short-term cash surpluses or cash requirements, ONEOK and ONEOK Partners provide cash to their subsidiary or the subsidiary provides cash to them. 



Short-term Liquidity - ONEOK’s principal sources of short-term liquidity consist of cash generated from operating activities, quarterly distributions from ONEOK Partners, the ONEOK Credit Agreement and the 364-Day Facility, as discussed below.  ONEOK also has a commercial paper program that can be utilized for short-term liquidity needs, to the extent funds are available under the ONEOK Credit Agreement and the 364-Day Facility.  ONEOK Partners’ principal sources of short-term liquidity consist of cash generated from operating activities and the ONEOK Partners Credit Agreement.

During late 2008, ONEOK and ONEOK Partners decided to borrow under their available credit facilities to fund their respective anticipated working capital requirements for the remainder of 2008 and into 2009.

In August 2008, ONEOK entered into the 364-Day Facility.  The interest rate is based, at ONEOK’s election, on either (i) the higher of prime or one-half of one percent above the Federal Funds Rate or (ii) the Eurodollar rate plus a set number of basis points based on ONEOK’s current long-term unsecured debt ratings by Moody’s and S&P.  The 364-Day Facility is being used for working capital, capital expenditures and other general corporate purposes.

In September 2008, ONEOK entered into an amendment to the ONEOK Credit Agreement.  The amendment changed certain sublimits but did not change the lenders’ aggregate commitment to lend up to $1.2 billion under the ONEOK Credit Agreement.

The total amount of short-term borrowings authorized by ONEOK’s Board of Directors is $2.5 billion.  At December 31, 2008, ONEOK had no commercial paper outstanding, $1.4 billion in borrowings outstanding, $64.9 million in letters of credit issued, which includes $64.6 million under the ONEOK Credit Agreement and an additional $0.3 million in other letters of credit, and available cash and cash equivalents of approximately $332.4 million.  Considering outstanding borrowings, commercial paper and letters of credit under the ONEOK Credit Agreement, ONEOK had $135.4 million of credit available at December 31, 2008, under the ONEOK Credit Agreement and the 364-Day Facility.  As of December 31, 2008, ONEOK could have issued $1.5 billion of additional short- and long-term debt under the most restrictive provisions contained in its various borrowing agreements.

The total amount of short-term borrowings authorized by the Board of Directors of ONEOK Partners GP, the general partner of ONEOK Partners, is $1.5 billion.  At December 31, 2008, ONEOK Partners had $870 million in borrowings outstanding and $130 million of credit available under the ONEOK Partners Credit Agreement and available cash and cash equivalents of approximately $177.6 million.  As of December 31, 2008, ONEOK Partners could have issued a $772.6 million of additional short- and long-term debt under the most restrictive provisions of its agreements.

ONEOK Partners has an outstanding $25 million letter of credit issued by Royal Bank of Canada, which is used for counterparty credit support.

ONEOK Partners also has a $15 million Senior Unsecured Letter of Credit Facility and Reimbursement Agreement with Wells Fargo Bank, N.A., of which $12 million is currently being used, and an agreement with Royal Bank of Canada, pursuant to which a $12 million letter of credit was issued.  Both agreements are used to support various permits required by the KDHE for ONEOK Partners’ ongoing business in Kansas.

The ONEOK Credit Agreement and the 364-Day Facility contain certain financial, operational and legal covenants.  These requirements include, among others:
·  
a $400 million sublimit for the issuance of standby letters of credit;
·  
a limitation on ONEOK’s stand-alone debt-to-capital ratio, which may not exceed 67.5 percent at the end of any calendar quarter;
·  
a requirement that ONEOK maintains the power to control the management and policies of ONEOK Partners,
·  
a limit on new investments in master limited partnerships; and
·  
other customary affirmative and negative covenants, including covenants relating to liens, investments, fundamental changes in ONEOK’s businesses, changes in the nature of ONEOK’s businesses, transactions with affiliates, the use of proceeds and a covenant that prevents ONEOK from restricting its subsidiaries’ ability to pay dividends.

The debt covenant calculations in the ONEOK Credit Agreement and the 364-Day Facility exclude the debt of ONEOK Partners.  Upon breach of any covenant by ONEOK, amounts outstanding under the ONEOK Credit Agreement or the 364-Day Facility may become immediately due and payable.  At December 31, 2008, ONEOK’s stand-alone debt-to-capital ratio was 58.2 percent, and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement and the ONEOK 364-Day Facility.


Under the ONEOK Partners Credit Agreement, ONEOK Partners is required to comply with certain financial, operational and legal covenants.  Among other things, these requirements include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA plus minority interest in income of consolidated subsidiaries, distributions received from investments and EBITDA related to any approved capital projects less equity earnings from investments and the equity portion of AFUDC) of no more than 5 to 1.  If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will be increased to 5.5 to 1 for the three calendar quarters following the acquisition.  Upon any breach of any covenant by ONEOK Partners in its ONEOK Partners Credit Agreement, amounts outstanding under the ONEOK Partners Credit Agreement may become immediately due and payable.  At December 31, 2008, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.1 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

The average interest rate on ONEOK and ONEOK Partners short-term debt outstanding at December 31, 2008, was 4.51 percent and 4.22 percent, respectively, compared with a weighted average rate of 3.88 percent and 3.94 percent, respectively, for the year ended December 31, 2008.  Based on the forward LIBOR curve, we expect the interest rate on ONEOK and ONEOK Partners’ short-term borrowings to decrease in 2009, compared with 2008.

Long-term Financing - In addition to the principal sources of short-term liquidity discussed above, options available to ONEOK to meet its longer-term cash requirements include the issuance of equity, issuance of long-term notes, issuance of convertible debt securities, asset securitization and sale/leaseback of facilities.  Options available to ONEOK Partners to meet its longer-term cash requirements include the issuance of common units, issuance of long-term notes, issuance of convertible debt securities, and asset securitization and sale/leaseback of facilities.

ONEOK and ONEOK Partners are subject, however, to changes in the equity and debt markets, and there is no assurance they will be able or willing to access the public or private markets in the future.  ONEOK and ONEOK Partners may choose to meet their cash requirements by utilizing some combination of cash flows from operations, altering the timing of controllable expenditures, restricting future acquisitions and capital projects, borrowing under existing credit facilities or pursuing other debt or equity financing alternatives.  Some of these alternatives could involve higher costs or negatively affect their respective credit ratings.  Based on ONEOK’s and ONEOK Partners’ investment-grade credit ratings, general financial condition and market expectations regarding their future earnings and projected cash flows, ONEOK and ONEOK Partners believe that they will be able to meet their respective cash requirements and maintain their investment-grade credit ratings.

ONEOK Partners Debt Issuance - In September 2007, ONEOK Partners completed an underwritten public offering of $600 million aggregate principal amount of 6.85 percent Senior Notes due 2037 (the 2037 Notes).  The 2037 Notes were issued under ONEOK Partners’ existing shelf registration statement filed with the SEC.

ONEOK Partners may redeem the 2037 Notes, in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount of the 2037 Notes, plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the 2037 Notes plus accrued and unpaid interest.  The 2037 Notes are senior unsecured obligations, ranking equally in right of payment with all of ONEOK Partners’ existing and future unsecured senior indebtedness, and effectively junior to all of the existing debt and other liabilities of its non-guarantor subsidiaries.  The 2037 Notes are non-recourse to ONEOK.

Debt Covenants - The terms of ONEOK’s long-term notes are governed by indentures containing covenants that include, among other provisions, limitations on ONEOK’s ability to place liens on its property or assets and its ability to sell and lease back its property.

We filed a new form of indenture in 2008.  The new indenture includes covenants that are similar to those contained in our prior indentures.  The new indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series.

The indenture governing ONEOK Partners’ 2037 Notes does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series.  The indenture contains covenants including, among other provisions, limitations on ONEOK Partners’ ability to place liens on its property or assets and its ability to sell and lease back its property.

ONEOK Partners’ $250 million and $225 million senior notes, due 2010 and 2011, respectively, contain provisions that require ONEOK Partners to offer to repurchase the senior notes at par value if its Moody’s or S&P credit rating falls below investment grade (Baa3 for Moody’s or BBB- for S&P) and the investment-grade rating is not reinstated within a period of 40 days.  Further, the indentures governing ONEOK Partners’ senior notes due 2010 and 2011 include an event of default


upon acceleration of other indebtedness of $25 million or more and the indentures governing the senior notes due 2012, 2016, 2036 and 2037 include an event of default upon the acceleration of other indebtedness of $100 million or more that would be triggered by such an offer to repurchase.  Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2010, 2011, 2012, 2016, 2036 and 2037 to declare those notes immediately due and payable in full.

ONEOK Partners Equity Issuance   -   In March 2008, ONEOK purchased from ONEOK Partners, in a private placement, an additional 5.4 million of ONEOK Partners’ common units for a total purchase price of approximately $303.2 million.  In addition, ONEOK Partners completed a public offering of 2.5 million common units at $58.10 per common unit and received net proceeds of $140.4 million after deducting underwriting discounts but before offering expenses.  In conjunction with ONEOK Partners’ private placement and the public offering of common units, ONEOK Partners GP contributed $9.4 million to ONEOK Partners in order to maintain its 2 percent general partner interest.  ONEOK and ONEOK Partners GP funded these amounts with available cash and short-term borrowings.

In April 2008, ONEOK Partners sold an additional 128,873 common units at $58.10 per common unit to the underwriters of the public offering upon the partial exercise of their option to purchase additional common units to cover over-allotments.  ONEOK Partners received net proceeds of approximately $7.2 million from the sale of these common units after deducting underwriting discounts but before offering expenses.  In conjunction with the partial exercise by the underwriters, ONEOK Partners GP contributed $0.2 million to ONEOK Partners in order to maintain its 2 percent general partner interest.  Following these transactions, our interest in ONEOK Partners is 47.7 percent.

ONEOK Partners used a portion of the proceeds from the sale of common units and the general partner contributions to repay borrowings under its existing ONEOK Partners Credit Agreement.

Capital Expenditures - ONEOK’s and ONEOK Partners’ capital expenditures are typically financed through operating cash flows, short- and long-term debt and the issuance of equity.  Total capital expenditures for 2008 were $1,473.1 million, compared with $883.7 million in 2007, exclusive of acquisitions.  Of these amounts, ONEOK Partners’ capital expenditures for 2008 were $1,253.9 million, compared with $709.9 million in 2007, exclusive of acquisitions.  The increase in capital expenditures for 2008, compared with 2007, is driven primarily by ONEOK Partners’ internal capital projects discussed beginning on page 37, and ONEOK’s purchase of ONEOK Plaza.  ONEOK and ONEOK Partners expect to continue to finance future capital expenditures with a combination of operating cash flows, short- and long-term debt, and the issuance of common units by ONEOK Partners.

The following table summarizes our 2009 projected capital expenditures, excluding AFUDC.

2009 Projected Capital Expenditures
   
        (Millions of dollars)
ONEOK Partners
      $ 425    
Distribution
        137    
Energy Services
        -    
Other
        19    
Total projected capital expenditures
      $ 581    

Projected 2009 capital expenditures are significantly less than 2008 capital expenditures, primarily due to the completion of the Overland Pass Pipeline and related projects and the Guardian Pipeline expansion and extension.  Additional information about our capital expenditures is included under “Capital Projects” on page 37.  ONEOK Partners anticipates spending $300 million to $500 million per year on growth capital expenditures for the years 2010 through 2015.

Investment in Northern Border Pipeline  - Northern Border Pipeline anticipates an equity contribution of approximately $85 million that will be required of its partners in 2009, of which ONEOK Partners’ share will be approximately $43 million for its 50 percent equity interest.

Credit Ratings - Our credit ratings as of December 31, 2008, are shown in the table below.

   
ONEOK
   
ONEOK Partners
Rating Agency
 
Rating
 
Outlook
   
Rating
 
Outlook
Moody's
 
Baa2
 
Stable
   
Baa2
 
Stable
S&P
 
BBB
 
Stable
   
BBB
 
Stable



ONEOK’s commercial paper is rated P2 by Moody’s and A2 by S&P.  ONEOK’s and ONEOK Partners’ credit ratings, which are currently investment grade, may be affected by a material change in financial ratios or a material event affecting the business.  The most common criteria for assessment of credit ratings are the debt-to-capital ratio, business risk profile, pretax and after-tax interest coverage, and liquidity.  ONEOK and ONEOK Partners do not anticipate their respective credit ratings to be downgraded.  However, if our credit ratings were downgraded, the interest rates on our commercial paper borrowings, the ONEOK Credit Agreement and the 364-Day Facility would increase, resulting in an increase in our cost to borrow funds, and we could potentially lose access to the commercial paper market.  Likewise, ONEOK Partners would see increased borrowing costs under the ONEOK Partners Credit Agreement.  In the event that ONEOK is unable to borrow funds under its commercial paper program and there has not been a material adverse change in its business, ONEOK would continue to have access to the ONEOK Credit Agreement, which expires in July 2011, and the 364-Day Facility, which expires in August 2009.  An adverse rating change alone is not a default under the ONEOK Credit Agreement, the 364-Day Facility or the ONEOK Partners Credit Agreement but could trigger repurchase obligations with respect to certain long-term debt.  See additional discussion about our credit ratings under “Debt Covenants.”

If ONEOK Partners’ repurchase obligations are triggered, it may not have sufficient cash on hand to repurchase and repay any accelerated senior notes, which may cause it to borrow money under its credit facilities or seek alternative financing sources to finance the repurchases and repayment.  ONEOK Partners could also face difficulties accessing capital or its borrowing costs could increase, impacting its ability to obtain financing for acquisitions or capital expenditures, to refinance indebtedness and to fulfill its debt obligations.

Our Energy Services segment relies upon the investment-grade rating of ONEOK’s senior unsecured long-term debt to reduce its collateral requirements.  If ONEOK’s credit ratings were to decline below investment grade, our ability to participate in energy marketing and trading activities could be significantly limited.  Without an investment-grade rating, we may be required to fund margin requirements with our counterparties with cash, letters of credit or other negotiable instruments.  At December 31, 2008, we could have been required to fund approximately $36.2 million in margin requirements related to financial contracts upon such a downgrade.  A decline in ONEOK’s credit rating below investment grade may also significantly impact other business segments.

Other than ONEOK Partners’ note repurchase obligations and the margin requirements for our Energy Services segment described above, we have determined that we do not have significant exposure to rating triggers under ONEOK’s trust indentures, building leases, equipment leases and other various contracts.  Rating triggers are defined as provisions that would create an automatic default or acceleration of indebtedness based on a change in our credit rating.

In the normal course of business, ONEOK’s and ONEOK Partners’ counterparties provide secured and unsecured credit.  In the event of a downgrade in ONEOK’s or ONEOK Partners’ credit rating or a significant change in ONEOK’s or ONEOK Partners’ counterparties’ evaluation of our creditworthiness, ONEOK or ONEOK Partners could be asked to provide additional collateral in the form of cash, letters of credit or other negotiable instruments.

ONEOK Partners’ Class B Units - The units we received from ONEOK Partners were newly created Class B limited partner units.  Distributions on the Class B limited partner units were prorated from the date of issuance.  As of April 7, 2007, the Class B limited partner units are no longer subordinated to distributions on ONEOK Partners’ common units and generally have the same voting rights as the common units.

At a special meeting of the ONEOK Partners common unitholders held March 29, 2007, the unitholders approved a proposal to permit the conversion of all or a portion of the Class B limited partner units issued in the acquisition and consolidation of certain companies comprising our former gathering and processing, natural gas liquids, and pipelines and storage segments in a series of transactions (collectively the ONEOK Transactions) into common units at the option of the Class B unitholder.  The March 29, 2007, special meeting was adjourned to May 10, 2007, to allow unitholders additional time to vote on a proposal to approve amendments to the ONEOK Partners’ Partnership Agreement, which had the amendments been approved, would have granted voting rights for units held by us and our affiliates if a vote is held to remove us as the general partner and would have required fair market value compensation for our general partner interest if we are removed as general partner.  While a majority of ONEOK Partners common unitholders voted in favor of the proposed amendments to the ONEOK Partners Partnership Agreement at the reconvened meeting of the common unitholders held May 10, 2007, the proposed amendments were not approved by the required two-thirds affirmative vote of the outstanding units, excluding the common units and Class B units held by us and our affiliates.  As a result, effective April 7, 2007, the Class B limited partner units are entitled to receive increased quarterly distributions and distributions upon liquidation equal to 110 percent of the distributions paid with respect to the common units.

On June 21, 2007, we, as the sole holder of ONEOK Partners’ Class B limited partner units, waived our right to receive the increased quarterly distributions on the Class B units for the period April 7, 2007, through December 31, 2007, and


continuing thereafter until we give ONEOK Partners no less than 90 days advance notice that we have withdrawn our waiver.  Any such withdrawal of the waiver will be effective with respect to any distribution on the Class B units declared or paid on or after 90 days following delivery of the notice.

In addition, since the proposed amendments to the ONEOK Partners’ Partnership Agreement were not approved by the common unitholders, if the common unitholders vote at any time to remove us or our affiliates as the general partner, quarterly distributions payable on Class B limited partner units would increase to 123.5 percent of the distributions payable with respect to the common units, and distributions payable upon liquidation of the Class B limited partner units would increase to 123.5 percent of the distributions payable with respect to the common units.

Stock Repurchase Plan - For more information regarding the Stock Repurchase Plan, refer to discussion in Note G of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

Commodity Prices - We are subject to commodity price volatility.  Significant fluctuations in commodity price in either physical or financial energy contracts may impact our overall liquidity due to the impact the commodity price changes have on our cash flows from operating activities, including the impact on working capital for NGLs and natural gas held in storage, margin requirements and certain energy-related receivables.  We believe that ONEOK’s and ONEOK Partners’ available credit and cash and cash equivalents are adequate to meet liquidity requirements associated with commodity price volatility.  See discussion beginning on page 63 under “Commodity Price Risk” in Item 7A, Quantitative and Qualitative Disclosures about Market Risk for information on our hedging activities.

Pension and Postretirement Benefit Plans - Information about our pension and postretirement benefits plans, including anticipated contributions, is included under Note J of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

At December 31, 2007, the funded status of our pension plans exceeded 94 percent as required by federal regulations.  General market factors in 2008 negatively impacted the fair value of our plan assets, and as a result, we made a voluntary contribution to our pension plans of $112 million on December 31, 2008.  We do not expect that our funding requirements in 2009 will have a material impact on our liquidity.

ENVIRONMENTAL LIABILITIES

Information about our environmental liabilities is included in Note K of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

CASH FLOW ANALYSIS

We use the indirect method to prepare our Consolidated Statements of Cash Flows.  Under this method, we reconcile net income to cash flows provided by operating activities by adjusting net income for those items that impact net income but may not result in actual cash receipts or payments during the period.  These reconciling items include depreciation and amortization, allowance for equity funds used during construction, gain on sale of assets, minority interests in income of consolidated affiliates, undistributed earnings from equity investments in excess of distributions received, deferred income taxes, stock-based compensation expense, allowance for doubtful accounts, inventory adjustments and investment securities gains.  The following table sets forth the changes in cash flows by operating, investing and financing activities for the periods indicated.

           
Variances
 
Variances
   
Years Ended December 31,
 
2008 vs. 2007
 
2007 vs. 2006
   
2008
 
2007
 
2006
 
Increase (Decrease)
 
Increase (Decrease)
   
(Millions of dollars)
 
Total cash provided by (used in):
                               
Operating activities
  $ 475.7   $ 1,029.7   $ 873.3   $ (554.0 ) (54 %)   $ 156.4   18 %
Investing activities
    (1,454.3 )   (1,151.8 )   (237.2 )   (302.5 ) (26 %)     (914.6 ) *  
Financing activities
    1,469.6     72.9     (618.8 )   1,396.7   *       691.7   *  
Change in cash and cash equivalents
    491.0     (49.2 )   17.3     540.2   *       (66.5 ) *  
Cash and cash equivalents at beginning of period
    19.1     68.3     7.9     (49.2 ) (72 %)     60.4   *  
Effect of Accounting Change
    on Cash and Cash Equivalents
    -     -     43.1     -   0 %     (43.1 ) (100 %)
Cash and cash equivalents at end of period
  $ 510.1   $ 19.1   $ 68.3   $ 491.0   *     $ (49.2 ) (72 %)
* Percentage change is greater than 100 percent.
                                         



Operating Cash Flows - Operating cash flows decreased by $554.0 million for 2008, compared with 2007, primarily due to changes in working capital.  These changes decreased operating cash flows by $515.3 million for 2008, compared with an increase of $203.6 million for 2007, primarily due to decreases in accounts payable and increased funding for our pension plans, partially offset by decreases in accounts and notes receivable.  The decrease in operating cash flows due to increases in working capital for 2008 was partially offset by higher net income.

Operating cash flows increased by $156.4 million for 2007, compared with 2006.  Working capital increased operating cash flows by $203.6 million for 2007, compared with an increase of $59.7 million for 2006.

Investing Cash Flows - The increased use of cash during 2008 was primarily related to a $589.4 million increase in capital expenditures, compared with 2007.  Capital expenditures increased $507.4 for 2007, compared with 2006.  These increases are primarily related to ONEOK Partners’ capital projects.

In October 2007, ONEOK Partners acquired an interstate natural gas liquids and refined petroleum products pipeline system and related assets from a subsidiary of Kinder Morgan for approximately $300 million, before working capital adjustments.

In April 2006, our ONEOK Partners segment received $297.0 million for the sale of a 20 percent partnership interest in Northern Border Pipeline.  Our Energy Services segment received $53.0 million for the sale of our discontinued component, Spring Creek, in October 2006.

Acquisitions in 2006 primarily relate to our ONEOK Partners segment acquiring the 66-2/3 percent interest in Guardian Pipeline not previously owned by ONEOK Partners for approximately $77 million.  We also purchased from TransCanada its 17.5 percent general partner interest in ONEOK Partners for $40 million.  Additionally, ONEOK Partners paid $11.6 million to Williams for a 99 percent interest in, and initial capital expenditures related to, the Overland Pass Pipeline Company natural gas liquids pipeline joint venture.

We had a decrease in short-term investments of $31.1 million for 2007, compared with a total investment of $31.1 million for 2006.  During 2007, we had less cash to invest following our repurchase of 7.5 million shares of our outstanding common stock in June.

Investing cash flows for 2006 also include the impact of the deconsolidation of Northern Border Pipeline and consolidation of Guardian Pipeline.

Financing Cash Flows - Net short-term borrowings were $2.1 billion for 2008, compared with $196.6 million for 2007.  The increased short-term borrowings during 2008 were used to repay a portion of $402.3 million of maturing long-term debt.  Short-term borrowings also increased as the result ONEOK’s and ONEOK Partners’ decision in late 2008 to borrow under their available credit facilities to fund their respective anticipated working capital requirements for the remainder of 2008 and into 2009, and ONEOK Partners’ capital projects.

During 2008, ONEOK Partners’ public sale of 2.6 million common units generated approximately $147 million, after deducting underwriting discounts but before offering expenses.

In 2007, short-term financing was primarily used to fund ONEOK Partners’ capital projects.  ONEOK Partners’ $598 million debt issuance, net of discounts, was used to repay borrowings under the ONEOK Partners Credit agreement and finance the $300 million acquisition of assets, before working capital adjustments, from a subsidiary of Kinder Morgan in October 2007.

In 2006, we repaid the remaining $900 million outstanding on our $1.0 billion short-term bridge financing agreement.  During the second quarter of 2006, ONEOK Partners borrowed $1.05 billion under its $1.1 billion 364-day credit facility dated April 6, 2006, (Bridge Facility) to finance a portion of the acquisition of the ONEOK Energy Assets and $77 million under its then existing credit agreement to acquire the 66-2/3 percent interest in Guardian Pipeline not previously owned by ONEOK Partners.  During the third quarter of 2006, ONEOK Partners completed the underwritten public offering of senior notes totaling $1.4 billion in net proceeds, before offering expenses, which were used to repay all of the amounts outstanding of the $1.05 billion borrowed under the ONEOK Partners Bridge Facility and to repay $335 million of indebtedness outstanding under its then existing credit agreement.

On February 16, 2006, we successfully settled our 16.1 million equity units to 19.5 million shares of our common stock.  With the settlement of the equity units, we received $402.4 million in cash, which we used to repay a portion of our commercial paper.  We repaid a total of $641.5 million of our commercial paper during 2006.  See Note G of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for additional discussion regarding the equity unit conversion.


In March 2006, our ONEOK Partners segment borrowed $33 million under its then existing credit agreement to redeem all of the outstanding Viking Gas Transmission Series A, B, C and D senior notes and paid a redemption premium of $3.6 million.

During 2007, we paid $20.1 million for the settlement of the forward purchase contract related to our stock repurchase in February and approximately $370 million for our stock repurchase in June.  We paid $281.4 million to repurchase shares in August 2006.

CONTRACTUAL OBLIGATIONS AND COMMERCIAL COMMITMENTS

The following table sets forth our contractual obligations related to debt, operating leases and other long-term obligations as of December 31, 2008.  For additional discussion of the debt and operating lease agreements, see Notes I and K, respectively, of the Notes to the Consolidated Financial Statements in this Annual Report on Form 10-K.

   
Payments Due by Period
 
Contractual Obligations
 
Total
 
2009
 
2010
 
2011
 
2012
 
2013
 
Thereafter
 
ONEOK
 
(Thousands of dollars)
 
$1.2 billion credit agreement
  $ 1,100,000   $ 1,100,000   $ -   $ -   $ -   $ -   $ -  
$400 million credit agreement
    300,000     300,000     -     -     -     -     -  
Long-term debt
    1,584,053     106,265     6,284     406,306     6,329     6,205     1,052,664  
Interest payments on debt
    1,100,500     92,100     91,400     70,900     62,100     61,700     722,300  
Operating leases
    300,795     88,837     55,888     61,232     32,943     25,376     36,519  
Firm transportation contracts
    552,509     123,352     103,157     81,833     80,389     57,249     106,529  
Financial and physical derivatives
    927,635     816,319     97,225     13,623     468     -     -  
Employee benefit plans
    42,602     42,602     -     -     -     -     -  
Other
    850     567     283     -     -     -     -  
    $ 5,908,944   $ 2,670,042   $ 354,237   $ 633,894   $ 182,229   $ 150,530   $ 1,918,012  
                                             
ONEOK Partners
                                           
$1 billion credit agreement
  $ 870,000   $ 870,000   $ -   $ -   $ -   $ -   $ -  
Long-term debt
    2,596,711     11,931     261,931     236,931     361,062     7,650     1,717,206  
Interest payments on debt
    2,686,400     176,700     163,700     140,000     120,200     114,300     1,971,500  
Operating leases
    86,508     18,362     16,027     15,527     8,755     2,063     25,774  
Firm transportation contracts
    14,765     11,086     3,679     -     -     -     -  
Financial and physical derivatives
    48,467     48,467     -     -     -     -     -  
Purchase commitments,
                                           
rights-of-way and other
    35,582     30,914     977     976     977     977     761  
    $ 6,338,433   $ 1,167,460   $ 446,314   $ 393,434   $ 490,994   $ 124,990   $ 3,715,241  
Total
  $ 12,247,377   $ 3,837,502   $ 800,551   $ 1,027,328   $ 673,223   $ 275,520   $ 5,633,253  

Long-term Debt - Long-term debt as reported in our Consolidated Balance Sheets includes unamortized debt discount and the mark-to-market effect of interest-rate swaps.

Interest Payments on Debt - Interest expense is calculated by multiplying long-term debt by the respective coupon rates, adjusted for active swaps.

Operating Leases - Our operating leases include a natural gas processing plant, storage contracts, office space, pipeline equipment, rights of way and vehicles.  Operating lease obligations for ONEOK exclude intercompany payments related to the lease of a gas processing plant.

Firm Transportation Contracts - Our ONEOK Partners, Distribution and Energy Services segments are party to fixed-price transportation contracts.  However, the costs associated with our Distribution segment’s contracts are recovered through rates as allowed by the applicable regulatory agency and are excluded from the table above.  Firm transportation agreements with our ONEOK Partners segment’s natural gas gathering and processing joint ventures require minimum monthly payments.

Financial and Physical Derivatives - These are obligations arising from our ONEOK Partners and Energy Services segments’ physical and financial derivatives for fixed-price purchase commitments and are based on market information at December 31, 2008.  Not included in these amounts are offsetting cash inflows from our Energy Services segment’s product sales and net positive settlements.  As market information changes daily and is potentially volatile, these values may change significantly.  Additionally, product sales may require additional purchase obligations to fulfill sales obligations that are not reflected in these amounts.


Employee Benefit Plans - Employee benefit plans include our minimum required contribution to our pension and postretirement benefit plans for 2009.  See Note J of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for discussion of our employee benefit plans.

Purchase Commitments - Purchase commitments include commitments related to ONEOK Partners’ growth capital expenditures and other rights of way commitments.  Purchase commitments exclude commodity purchase contracts, which are included in the “Financial and physical derivatives” amounts.

FORWARD-LOOKING STATEMENTS

Some of the statements contained and incorporated in this Annual Report on Form 10-K are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities and Exchange Act of 1934, as amended.  The forward-looking statements relate to our anticipated financial performance, management’s plans and objectives for our future operations, our business prospects, the outcome of regulatory and legal proceedings, market conditions and other matters.  We make these forward-looking statements in reliance on the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995.  The following discussion is intended to identify important factors that could cause future outcomes to differ materially from those set forth in the forward-looking statements.

Forward-looking statements include the items identified in the preceding paragraph, the information concerning possible or assumed future results of our operations and other statements contained or incorporated in this Annual Report on Form 10-K identified by words such as “anticipate,” “estimate,” “expect,” “project,” “intend,” “plan,” “believe,” “should,” “goal,” “forecast,” “could,” “may,” “continue,” “might,” “potential,” “scheduled,” and other words and terms of similar meaning.

You should not place undue reliance on forward-looking statements.  Known and unknown risks, uncertainties and other factors may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by forward-looking statements.  Those factors may affect our operations, markets, products, services and prices.  In addition to any assumptions and other factors referred to specifically in connection with the forward-looking statements, factors that could cause our actual results to differ materially from those contemplated in any forward-looking statement include, among others, the following:

·  
the effects of weather and other natural phenomena on our operations, including energy sales and demand for our services and energy prices;
·  
competition from other United States and Canadian energy suppliers and transporters as well as alternative forms of energy, including, but not limited to, biofuels such as ethanol and biodiesel;
·  
the status of deregulation of retail natural gas distribution;
·  
the capital intensive nature of our businesses;
·  
the profitability of assets or businesses acquired or constructed by us;
·  
our ability to make cost-saving changes in operations;
·  
risks of marketing, trading and hedging activities, including the risks of changes in energy prices or the financial condition of our counterparties;
·  
the uncertainty of estimates, including accruals and costs of environmental remediation;
·  
the timing and extent of changes in energy commodity prices;
·  
the effects of changes in governmental policies and regulatory actions, including changes with respect to income and other taxes, environmental compliance, climate change initiatives, and authorized rates or recovery of gas and gas transportation costs;
·  
the impact on drilling and production by factors beyond our control, including the demand for natural gas and refinery-grade crude oil; producers’ desire and ability to obtain necessary permits; reserve performance; and capacity constraints on the pipelines that transport crude oil, natural gas and NGLs from producing areas and our facilities;
·  
changes in demand for the use of natural gas because of market conditions caused by concerns about global warming;
·  
the impact of unforeseen changes in interest rates, equity markets, inflation rates, economic recession and other external factors over which we have no control, including the effect on pension expense and funding resulting from changes in stock and bond market returns;
·  
our indebtedness could make us vulnerable to general adverse economic and industry conditions, limit our ability to borrow additional funds, and/or place us at competitive disadvantages compared to our competitors that have less debt, or have other adverse consequences;
·  
actions by rating agencies concerning the credit ratings of ONEOK and ONEOK Partners;

 
·  
the results of administrative proceedings and litigation, regulatory actions and receipt of expected clearances involving the OCC, KCC, Texas regulatory authorities or any other local, state or federal regulatory body, including the FERC;
·  
our ability to access capital at competitive rates or on terms acceptable to us;
·  
risks associated with adequate supply to our gathering, processing, fractionation and pipeline facilities, including production declines that outpace new drilling;
·  
the risk that material weaknesses or significant deficiencies in our internal controls over financial reporting could emerge or that minor problems could become significant;
·  
the impact and outcome of pending and future litigation;
·  
the ability to market pipeline capacity on favorable terms, including the effects of:
-  
future demand for and prices of natural gas and NGLs;
-  
competitive conditions in the overall energy market;
-  
availability of supplies of Canadian and United States natural gas; and
-  
availability of additional storage capacity;
·  
performance of contractual obligations by our customers, service providers, contractors and shippers;
·  
the timely receipt of approval by applicable governmental entities for construction and operation of our pipeline and other projects and required regulatory clearances;
·  
our ability to acquire all necessary permits, consents or other approvals in a timely manner, to promptly obtain all necessary materials and supplies required for construction, and to construct gathering, processing, storage, fractionation and transportation facilities without labor or contractor problems;
·  
the mechanical integrity of facilities operated;
·  
demand for our services in the proximity of our facilities;
·  
our ability to control operating costs;
·  
adverse labor relations;
·  
acts of nature, sabotage, terrorism or other similar acts that cause damage to our facilities or our suppliers’ or shippers’ facilities;
·  
economic climate and growth in the geographic areas in which we do business;
·  
the risk of a prolonged slowdown in growth or decline in the United States economy or the risk of delay in growth recovery in the United States economy, including increasing liquidity risks in United States credit markets;
·  
the impact of recently issued and future accounting pronouncements and other changes in accounting policies;
·  
the possibility of future terrorist attacks or the possibility or occurrence of an outbreak of, or changes in, hostilities or changes in the political conditions in the Middle East and elsewhere;
·  
the risk of increased costs for insurance premiums, security or other items as a consequence of terrorist attacks;
·  
risks associated with pending or possible acquisitions and dispositions, including our ability to finance or integrate any such acquisitions and any regulatory delay or conditions imposed by regulatory bodies in connection with any such acquisitions and dispositions;
·  
the possible loss of gas distribution franchises or other adverse effects caused by the actions of municipalities;
·  
the impact of unsold pipeline capacity being greater or less than expected;
·  
the ability to recover operating costs and amounts equivalent to income taxes, costs of property, plant and equipment and regulatory assets in our state and FERC-regulated rates;
·  
the composition and quality of the natural gas and NGLs we gather and process in our plants and transport on our pipelines;
·  
the efficiency of our plants in processing natural gas and extracting and fractionating NGLs;
·  
the impact of potential impairment charges;
·  
the risk inherent in the use of information systems in our respective businesses, implementation of new software and hardware, and the impact on the timeliness of information for financial reporting;
·  
our ability to control construction costs and completion schedules of our pipelines and other projects; and
·  
the risk factors listed in the reports we have filed and may file with the SEC, which are incorporated by reference.
 
These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements.  Other factors could also have material adverse effects on our future results.  These and other risks are described in greater detail in Item 1A, Risk Factors, in this Annual Report on Form 10-K.  All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors.  Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise.


ITEM  7A.                       QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Risk Policy and Oversight - We control the scope of risk management, marketing and trading operations through a comprehensive set of policies and procedures involving senior levels of management.  The Audit Committee of our Board of Directors has oversight responsibilities for our risk management limits and policies.  Our risk oversight committee, comprised of corporate and business segment officers, oversees all activities related to commodity price and credit risk management, and marketing and trading activities.  The committee also monitors risk metrics including value-at-risk (VAR) and mark-to-market losses.  We have a risk control group that is assigned responsibility for establishing and enforcing the policies and procedures and monitoring certain risk metrics.  Key risk control activities include risk measurement and monitoring, validation of transactions, portfolio valuation, VAR and other risk metrics.

Our exposure to market risk discussed below includes forward-looking statements and represents an estimate of possible changes in future earnings that would occur assuming hypothetical future movements in interest rates or commodity prices.  Our views on market risk are not necessarily indicative of actual results that may occur and do not represent the maximum possible gains and losses that may occur since actual gains and losses will differ from those estimated based on actual fluctuations in interest rates or commodity prices and the timing of transactions.

COMMODITY PRICE RISK

We are exposed to commodity price risk and the impact of market price fluctuations of natural gas, NGLs and crude oil prices.  Commodity price risk refers to the risk of loss in cash flows and future earnings arising from adverse changes in commodity energy prices.  To minimize the risk from market price fluctuations of natural gas, NGLs and crude oil, we use commodity derivative instruments such as futures, physical forward contracts, swaps and options to manage commodity price risk associated with existing or anticipated purchase and sale agreements, existing physical natural gas in storage, and basis risk.

ONEOK Partners

ONEOK Partners is exposed to commodity price risk, primarily with respect to NGLs, as a result of receiving commodities in exchange for its gathering and processing services.  To a lesser extent, ONEOK Partners is exposed to the relative price differential between NGLs and natural gas, or the gross processing spread, with respect to its keep-whole processing contracts.  ONEOK Partners is also exposed to the risk of price fluctuations and the cost of intervening transportation at various market locations.  As part of ONEOK Partners’ hedging strategy, ONEOK Partners uses commodity fixed-price physical forwards and derivative contracts, including NYMEX-based futures and over-the-counter swaps, to minimize earnings volatility in its natural gas gathering and processing business related to natural gas, NGL and condensate price fluctuations.

ONEOK Partners reduces its gross processing spread exposure through a combination of physical and financial hedges.  ONEOK Partners utilizes a portion of its percent-of-proceeds equity natural gas as an offset, or natural hedge, to an equivalent portion of its keep-whole shrink requirements.  This has the effect of converting ONEOK Partners’ gross processing spread risk to NGL commodity price risk, and ONEOK Partners then uses financial instruments to hedge the sale of NGLs.

The following table sets forth ONEOK Partners’ hedging information for the year ending December 31, 2009.

 
Year Ending December 31, 2009
 
Volumes Hedged
   
Average Price
Percentage Hedged
NGLs (Bbl/d) (a)
5,010
    $
1.18
/ gallon
57%
Condensate (Bbl/d) (a)
666
    $
3.23
/ gallon
32%
Total liquid sales (Bbl/d)
5,676
    $
1.42
/ gallon
52%
(a) - Hedged with fixed-price swaps.
             



ONEOK Partners’ commodity price risk is estimated as a hypothetical change in the price of NGLs, crude oil and natural gas at December 31, 2008, excluding the effects of hedging and assuming normal operating conditions.  ONEOK Partners’ condensate sales are based on the price of crude oil.  ONEOK Partners estimates the following:
·  
a $0.01 per gallon decrease in the composite price of NGLs would decrease annual net margin by approximately $1.2 million;
·  
a $1.00 per barrel decrease in the price of crude oil would decrease annual net margin by approximately $1.0 million; and
·  
a $0.10 per MMBtu decrease in the price of natural gas would decrease annual net margin by approximately $0.6 million.

The above estimates of commodity price risk do not include any effects on demand for its services that might be caused by, or arise in conjunction with, price changes.  For example, a change in the gross processing spread may cause a change in the amount of ethane extracted from the natural gas stream, impacting gathering and processing margins, NGL exchange revenues, natural gas deliveries, and NGL volumes shipped and fractionated.

ONEOK Partners is also exposed to commodity price risk primarily as a result of NGLs in storage, the relative values of the various NGL products to each other, the relative value of NGLs to natural gas and the relative value of NGL purchases at one location and sales at another location, known as basis risk.  ONEOK Partners utilizes fixed-price physical forward contracts to reduce earnings volatility related to NGL price fluctuations.  ONEOK Partners has not entered into any financial instruments with respect to its NGL marketing activities.

In addition, ONEOK Partners is exposed to commodity price risk as its natural gas interstate and intrastate pipelines collect natural gas from its customers for operations or as part of its fee for services provided.  When the amount of natural gas consumed in operations by these pipelines differs from the amount provided by its customers, the pipelines must buy or sell natural gas, or store or use natural gas from inventory, which exposes ONEOK Partners to commodity price risk.  At December 31, 2008, there were no hedges in place with respect to natural gas price risk from ONEOK Partners’ natural gas pipeline business.

Distribution

Our Distribution segment uses derivative instruments to hedge the cost of anticipated natural gas purchases during the winter heating months to protect their customers from upward volatility in the market price of natural gas.  Gains or losses associated with these derivative instruments are included in, and recoverable through, the monthly purchased gas cost mechanism.

Energy Services

Our Energy Services segment is exposed to commodity price risk, basis risk and price volatility arising from natural gas in storage, requirement contracts, asset management contracts and index-based purchases and sales of natural gas at various market locations.  We minimize the volatility of our exposure to commodity price risk through the use of derivative instruments, which, under certain circumstances, are designated as cash flow or fair value hedges.  We are also exposed to commodity price risk from fixed-price purchases and sales of natural gas, which we hedge with derivative instruments.  Both the fixed-price purchases and sales and related derivatives are recorded at fair value.

Fair Value Component of the Energy Marketing and Risk Management Assets and Liabilities - The following table sets forth the fair value component of the energy marketing and risk management assets and liabilities, excluding $21.0 million of net liabilities from derivative instruments declared as either fair value or cash flow hedges.
 
Fair Value Component of Energy Marketing and Risk Management Assets and Liabilities
   
    (Thousands of dollars)
Net fair value of derivatives outstanding at December 31, 2007
    $ 25,171    
Derivatives reclassified or otherwise settled during the period
      (55,874 )  
Fair value of new derivatives entered into during the period
      236,772    
Other changes in fair value
      52,731    
Net fair value of derivatives outstanding at December 31, 2008 (a)
    $ 258,800    
             
(a) - The maturities of derivatives are based on injection and withdrawal periods from
 April through March, which is consistent with our business strategy. The maturities
 are as follows: $225.0 million matures through March 2009, $33.9 million matures
 through March 2012 and $(0.1) million matures through March 2014.
   



The change in the net fair value of derivatives outstanding includes the effect of settled energy contracts and current period changes resulting primarily from newly originated transactions and the impact of market movements on the fair value of energy marketing and risk management assets and liabilities.  Fair value of new derivatives entered into during the period includes $298.8 million of cash flow hedges reclassified into earnings from accumulated other comprehensive income (loss) related to the write-down of our natural gas in storage to its lower of weighted-average cost or market.

For further discussion of fair value measurements and trading activities and assumptions used in our trading activities, see the “Critical Accounting Policies and Estimates” section of Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operation.  Also, see Notes C and D of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.

Value-at-Risk (VAR) Disclosure of Commodity Price Risk -   We measure commodity price risk in our Energy Services segment using a VAR methodology, which estimates the expected maximum loss of our portfolio over a specified time horizon within a given confidence interval.  Our VAR calculations are based on the Monte Carlo approach.  The quantification of commodity price risk using VAR provides a consistent measure of risk across diverse energy markets and products with different risk factors in order to set overall risk tolerance and to determine risk thresholds.  The use of this methodology requires a number of key assumptions, including the selection of a confidence level and the holding period to liquidation.  Inputs to the calculation include prices, volatilities, positions, instrument valuations and the variance-covariance matrix.  Historical data is used to estimate our VAR with more weight given to recent data, which is considered a more relevant predictor of immediate future commodity market movements.  We rely on VAR to determine the potential reduction in the portfolio values arising from changes in market conditions over a defined period.  While management believes that the referenced assumptions and approximations are reasonable, no uniform industry methodology exists for estimating VAR.  Different assumptions and approximations could produce materially different VAR estimates.

Our VAR exposure represents an estimate of potential losses that would be recognized due to adverse commodity price movements in our Energy Services segment’s portfolio of derivative financial instruments, physical commodity contracts, leased transport, storage capacity contracts and natural gas in storage.  A one-day time horizon and a 95 percent confidence level are used in our VAR data.  Actual future gains and losses will differ from those estimated by the VAR calculation based on actual fluctuations in commodity prices, operating exposures and timing thereof, and the changes in our derivative financial instruments, physical contracts and natural gas in storage.  VAR information should be evaluated in light of these assumptions and the methodology’s other limitations.

The potential impact on our future earnings, as measured by VAR, was $7.9 million and $6.0 million at December 31, 2008 and 2007, respectively.  The following table details the average, high and low VAR calculations for the periods indicated.


 
Years Ended December 31,
Value-at-Risk
 
2008
   
2007
 
 
(Millions of dollars)
Average
  $ 12.3     $ 8.9  
High
  $ 24.9     $ 23.0  
Low
  $ 4.0     $ 3.4  

Our VAR calculation includes derivatives, executory storage and transportation agreements and their related hedges.  The variations in the VAR data are reflective of market volatility and changes in our portfolio during the year.  The increase in average VAR for 2008, compared with 2007, was primarily due to a significant increase in natural gas prices during the second quarter of 2008.

Our VAR calculation uses historical prices, placing more emphasis on the most recent price movements.  We revised our assumptions in the third quarter of 2008 to decrease the weight given to the most recent price changes and spread the relative weighting over more historical data.  This methodology reduces the effects of the market anomalies and better reflects an efficient market.  We believe this methodology is more reflective of portfolio risk and have applied the change on a prospective basis.

During 2008, we also began calculating the VAR on our mark-to-market derivative positions, which reflects the risk associated with derivatives whose change in fair value will impact current period earnings.  These transactions are subject to mark-to-market accounting treatment because they are not part of a hedging relationship under Statement 133.  VAR associated with these derivative positions was not material during 2008.  To the extent open commodity positions exist, fluctuating commodity prices can impact our financial results and financial position either favorably or unfavorably.  As a result, we cannot predict with precision the impact risk management decisions may have on the business, operating results or financial position.


INTEREST RATE RISK

General - We are subject to the risk of interest-rate fluctuation in the normal course of business.  We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and, at times, interest-rate swaps.  Fixed-rate swaps are used to reduce our risk of increased interest costs during periods of rising interest rates.  Floating-rate swaps are used to convert the fixed rates of long-term borrowings into short-term variable rates.  At December 31, 2008, the interest rate on 89.3 percent of our long-term debt, exclusive of the debt of our ONEOK Partners segment, was fixed after considering the impact of interest-rate swaps.  At December 31, 2008, the interest rate on all of ONEOK Partners’ long-term debt was fixed.

We terminated a $100 million interest-rate swap in the fourth quarter of 2008.  The total value we received was $19.2 million, which includes $0.3 million of swap savings previously recorded.  The remaining savings of $18.9 million will be recognized in interest expense over the remaining term of the debt instrument originally hedged.

In the fourth quarter of 2008, our counterparties exercised the option to terminate two additional interest-rate swap agreements totaling $140 million.  The swap terminations were effective in December 2008 and January 2009.  The total value we received for the terminated swaps was not material.

At December 31, 2008, a 100 basis point move in the annual interest rate on all of our swapped long-term debt would change our annual interest expense by $1.7 million before taxes.  This 100 basis point change assumes a parallel shift in the yield curve.  If interest rates changed significantly, we would take actions to manage our exposure to the change.  Since a specific action and the possible effects are uncertain, no change has been assumed.

Fair Value Hedges - See Note D of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K for discussion of the impact of interest-rate swaps and net interest expense savings from terminated swaps.

Total net swap savings for 2008 were $17.4 million, compared with $8.2 million for 2007.  Total swap savings for 2009 are expected to be $10.5 million.

CURRENCY EXCHANGE RATE RISK

As a result of our Energy Services segment’s operations in Canada, we are exposed to currency exchange rate risk from our commodity purchases and sales related to our firm transportation and storage contracts.  To reduce our exposure to exchange-rate fluctuations, we use physical forward transactions, which result in an actual two-way flow of currency on the settlement date since we exchange U.S. dollars for Canadian dollars with another party.  We have not designated these transactions for hedge accounting treatment; therefore, the gains and losses associated with the change in fair value are recorded in net margin.  At December 31, 2008 and 2007, our exposure to risk from currency translation was not material.  We recognized a currency translation loss of $3.1 million during 2008 and currency translation gains of $4.1 million and $2.5 million during 2007 and 2006, respectively.

COUNTERPARTY CREDIT RISK

ONEOK and ONEOK Partners assess the creditworthiness of their counterparties on an on going basis and require security, including prepayments and other forms of cash collateral, when appropriate.




ITEM 8.                       FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA


  REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders
ONEOK, Inc.:

In our opinion, the accompanying consolidated balance sheets and the related consolidated statements of income, shareholders equity and comprehensive income and cash flows present fairly, in all material respects, the financial position of ONEOK, Inc. and its subsidiaries (the Company)   at December 31, 2008 and 2007, and the results of their operations and their cash flows for each of the two years in the period ended December 31, 2008,   in conformity with accounting principles generally accepted in the United States of America.  Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2008, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).  The Company s management is responsible for these financial statements, for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in Management s Report on Internal Control over Financial Reporting appearing under Item 9A in the Company s Form 10-K for the year ended December 31, 2008.  Our responsibility is to express opinions on these financial statements and on the Company s internal control over financial reporting based on our integrated 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 audits to obtain reasonable assurance about whether the financial statements are free of material misstatement and whether effective internal control over financial reporting was maintained in all material respects.  Our audits of the financial statements included examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, and evaluating the overall financial statement presentation.  Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk.  Our audits also included performing such other procedures as we considered necessary in the circumstances.  We believe that our audits provide a reasonable basis for our opinions.

A 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 generally accepted accounting principles.  A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) 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 (iii) 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 its inherent limitations, internal control over financial reporting may not prevent or detect misstatements.  Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.



/s/  PricewaterhouseCoopers LLP

February 24, 2009
Tulsa, Oklahoma






REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders
ONEOK, Inc.:

We have audited the accompanying consolidated statement of income, cash flows, and shareholders’ equity and comprehensive income of ONEOK, Inc. and subsidiaries as of December 31, 2006.  The consolidated financial statements are the responsibility of the Company’s management.  Our responsibility is to express an opinion on these consolidated financial statements 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 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 audit provides a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the results of operations and cash flows of ONEOK, Inc. and subsidiaries for the year ended December 31, 2006, in conformity with U.S. generally accepted accounting principles.

As discussed in Note A of Notes to the Consolidated Financial Statements, the Company adopted the provisions of Statement of Financial Accounting Standards (SFAS) No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans,” Emerging Issues Task Force Issue 04-5, “Determining Whether a General Partner, or General Partners as a Group Controls a Limited Partnership or Similar Entity When the Limited Partners Have Certain Rights,” and SFAS No. 123R, “Share-Based Payment.”


/s/ KPMG LLP

Tulsa, Oklahoma
February 28, 2007




 
ONEOK, Inc. and Subsidiaries
                 
CONSOLIDATED  STATEMENTS OF INCOME
                 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
    (Thousands of dollars, except per share amounts)
                   
Revenues
  $ 16,157,433     $ 13,477,414     $ 11,920,326  
Cost of sales and fuel
    14,221,906       11,667,306       10,198,342  
Net Margin
    1,935,527       1,810,108       1,721,984  
Operating Expenses
                       
Operations and maintenance
    694,597       675,575       662,681  
Depreciation and amortization
    243,927       227,964       235,543  
General taxes
    82,315       85,935       78,086  
Total Operating Expenses
    1,020,839       989,474       976,310  
Gain (Loss) on Sale of Assets
    2,316       1,909       116,528  
Operating Income
    917,004       822,543       862,202  
Equity earnings from investments (Note O)
    101,432       89,908       95,883  
Allowance for equity funds used during construction
    50,906       12,538       2,205  
Other income
    16,838       21,932       26,030  
Other expense
    (27,475 )     (7,879 )     (24,154 )
Interest expense
    (264,167 )     (256,325 )     (239,725 )
Income before Minority Interests and Income Taxes
    794,538       682,717       722,441  
Minority interests in income of consolidated subsidiaries
    (288,558 )     (193,199 )     (222,000 )
Income taxes (Note L)
    (194,071 )     (184,597 )     (193,764 )
Income from Continuing Operations
    311,909       304,921       306,677  
Gain (Loss) from operations of discontinued components, net of tax
    -       -       (365 )
Net Income
  $ 311,909     $ 304,921     $ 306,312  
                         
Earnings Per Share of Common Stock (Note P)
                       
Net Earnings Per Share, Basic
  $ 2.99     $ 2.84     $ 2.74  
Net Earnings Per Share, Diluted
  $ 2.95     $ 2.79     $ 2.68  
                         
Average Shares of Common Stock (Thousands)
                       
Basic
    104,369       107,346       112,006  
Diluted
    105,760       109,298       114,477  
                         
Dividends Declared Per Share of Common Stock
  $ 1.56     $ 1.40     $ 1.22  
See accompanying Notes to Consolidated Financial Statements.
                       
 
 
 
 
ONEOK, Inc. and Subsidiaries
           
CONSOLIDATED BALANCE SHEETS
           
   
December 31,
   
December 31,
 
   
2008
   
2007
 
Assets
 
(Thousands of dollars)
 
             
Current Assets
           
Cash and cash equivalents
  $ 510,058     $ 19,105  
Accounts receivable, net
    1,265,300       1,723,212  
Gas and natural gas liquids in storage
    858,966       841,362  
Commodity exchanges and imbalances
    56,248       82,938  
Energy marketing and risk management assets (Notes C and D)
    362,808       143,941  
Other current assets
    324,222       140,917  
Total Current Assets
    3,377,602       2,951,475  
                 
Property, Plant and Equipment
               
Property, plant and equipment
    9,476,619       7,893,492  
Accumulated depreciation and amortization
    2,212,850       2,048,311  
Net Property, Plant and Equipment (Note A)
    7,263,769       5,845,181  
                 
Investments and Other Assets
               
Goodwill and intangible assets (Note E)
    1,038,226       1,043,773  
Energy marketing and risk management assets (Notes C and D)
    45,900       3,978  
Investments in unconsolidated affiliates (Note O)
    755,492       756,260  
Other assets
    645,073       461,367  
Total Investments and Other Assets
    2,484,691       2,265,378  
Total Assets
  $ 13,126,062     $ 11,062,034  
See accompanying Notes to Consolidated Financial Statements.
               

 
 

ONEOK, Inc. and Subsidiaries
           
CONSOLIDATED BALANCE SHEETS
           
   
December 31,
   
December 31,
 
   
2008
   
2007
 
Liabilities and Shareholders’ Equity
 
(Thousands of dollars)
 
             
Current Liabilities
           
Current maturities of long-term debt (Note I)
  $ 118,195     $ 420,479  
Notes payable
    2,270,000       202,600  
Accounts payable
    1,122,761       1,436,005  
Commodity exchanges and imbalances
    188,030       252,095  
Energy marketing and risk management liabilities (Notes C and D)
    175,006       133,903  
Other current liabilities
    319,772       436,585  
Total Current Liabilities
    4,193,764       2,881,667  
                 
Long-term Debt, excluding current maturities (Note I)
    4,112,581       4,215,046  
                 
Deferred Credits and Other Liabilities
               
Deferred income taxes
    890,815       680,543  
Energy marketing and risk management liabilities (Notes C and D)
    46,311       26,861  
Other deferred credits
    715,052       486,645  
Total Deferred Credits and Other Liabilities
    1,652,178       1,194,049  
                 
Commitments and Contingencies (Note K)
               
                 
Minority Interests in Consolidated Subsidiaries
    1,079,369       801,964  
                 
Shareholders’ Equity
               
Common stock, $0.01 par value:
               
authorized 300,000,000 shares; issued 121,647,007 shares
               
and outstanding 104,845,231 shares at December 31, 2008;
               
issued 121,115,217 shares and outstanding 103,987,476
               
shares at December 31, 2007
    1,216       1,211  
Paid in capital
    1,301,153       1,273,800  
Accumulated other comprehensive loss (Note F)
    (70,616 )     (7,069 )
Retained earnings
    1,553,033       1,411,492  
Treasury stock, at cost: 16,801,776 shares at December 31,
               
2008 and 17,127,741 shares at December 31, 2007
    (696,616 )     (710,126 )
Total Shareholders’ Equity
    2,088,170       1,969,308  
Total Liabilities and Shareholders’ Equity
  $ 13,126,062     $ 11,062,034  
See accompanying Notes to Consolidated Financial Statements.
               
 
 






















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ONEOK, Inc. and Subsidiaries
           
CONSOLIDATED STATEMENTS OF CASH FLOWS
           
 
Years Ended December 31,
 
 
2008
 
2007
 
2006
 
Operating Activities
(Thousands of dollars)
 
Net income
$ 311,909   $ 304,921   $ 306,312  
Depreciation and amortization
  243,927     227,964     235,543  
Allowance for equity funds used during construction
  (50,906 )   (12,538 )   (2,205 )
Gain on sale of assets
  (2,316 )   (1,909 )   (116,528 )
Minority interests in income of consolidated subsidiaries
  288,558     193,199     222,000  
Equity earnings from investments
  (101,432 )   (89,908 )   (95,883 )
Distributions received from unconsolidated affiliates
  93,261     103,785     123,427  
Deferred income taxes
  165,191     65,017     115,384  
Stock-based compensation expense
  30,791     20,909     16,499  
Allowance for doubtful accounts
  13,476     14,578     9,056  
Inventory adjustment, net
  9,658     -     -  
Investment securities gains
  (11,142 )   -     -  
Changes in assets and liabilities (net of acquisition and disposition effects):
                 
Accounts and notes receivable
  433,859     (378,876 )   649,415  
Gas and natural gas liquids in storage
  (370,662 )   88,937     (13,801 )
Accounts payable
  (340,584 )   343,144     (425,715 )
Commodity exchanges and imbalances, net
  (37,375 )   40,572     18,001  
Unrecovered purchased gas costs
  (35,790 )   9,530     (73,534 )
Accrued interest
  16,002     9,001     25,329  
Energy marketing and risk management assets and liabilities
  60,846     41,649     (63,040 )
Fair value of firm commitments
  505     5,631     190,795  
Pension and postretirement benefit plans
  (83,254 )   28,573     (14,496 )
Other assets and liabilities
  (158,845 )   15,481     (233,283 )
Cash Provided by Operating Activities
  475,677     1,029,660     873,276  
Investing Activities
                 
Changes in investments in unconsolidated affiliates
  3,963     (3,668 )   (6,608 )
Acquisitions
  2,450     (299,560 )   (148,892 )
Capital expenditures (less allowance for equity funds used during construction)
  (1,473,136 )   (883,703 )   (376,306 )
Proceeds from sale of discontinued component
  -     -     53,000  
Proceeds from sale of assets
  2,630     4,022     298,964  
Proceeds from insurance
  9,792     -     -  
Changes in short-term investments
  -     31,125     (31,125 )
Increase in cash and cash equivalents attributable to previously unconsolidated subsidiaries
  -     -     1,334  
Decrease in cash and cash equivalents attributable to previously consolidated subsidiaries
  -     -     (22,039 )
Other investing activities
  -     -     (5,565 )
Cash Used in Investing Activities
  (1,454,301 )   (1,151,784 )   (237,237 )
Financing Activities
                 
Borrowing (repayment) of notes payable, net
  1,197,400     196,600     (842,000 )
Borrowing (repayment) of notes payable with maturities over 90 days
  870,000     -     (900,000 )
Issuance of debt, net of issuance costs
  -     598,146     1,397,328  
Long-term debt financing costs
  -     (5,805 )   (12,003 )
Payment of debt
  (416,040 )   (13,588 )   (44,359 )
Equity unit conversion
  -     -     402,448  
Repurchase of common stock
  (29 )   (390,213 )   (281,444 )
Issuance of common stock
  16,495     20,730     10,829  
Issuance of common units, net of discounts
  146,969     -     -  
Dividends paid
  (162,785 )   (150,188 )   (135,451 )
Distributions to minority interests
  (201,658 )   (182,891 )   (165,283 )
Other financing activities
  19,225     170     (48,841 )
Cash Provided by (Used in) Financing Activities
  1,469,577     72,961     (618,776 )
Change in Cash and Cash Equivalents
  490,953     (49,163 )   17,263  
Cash and Cash Equivalents at Beginning of Period
  19,105     68,268     7,915  
Effect of Accounting Change on Cash and Cash Equivalents
  -     -     43,090  
Cash and Cash Equivalents at End of Period
$ 510,058   $ 19,105   $ 68,268  
Supplemental Cash Flow Information:
                 
Cash Paid for Interest
$ 237,577   $ 253,678   $ 225,998  
Cash Paid for Taxes
$ 82,965   $ 57,281   $ 262,504  
See accompanying Notes to Consolidated Financial Statements.
                 


ONEOK, Inc. and Subsidiaries
                       
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY AND COMPREHENSIVE INCOME
 
                         
                         
   
Common
                   
   
Stock
   
Common
   
Paid-in
   
Unearned
 
   
Issued
   
Stock
   
Capital
   
Compensation
 
   
(Shares)
   
(Thousands of dollars)
 
                         
December 31, 2005
    107,973,436     $ 1,080     $ 1,044,283     $ (105 )
Net income
    -       -       -       -  
Other comprehensive income (loss)
    -       -       -       -  
Total comprehensive income
                               
Adoption of Statement 158
    -       -       -       -  
Equity unit conversion
    11,208,998       112       177,572       -  
Repurchase of common stock
    -       -       -       -  
Common stock issued
    1,151,474       11       36,862       158  
Common stock dividends -
                               
$1.22 per share
    -       -       -       (53 )
December 31, 2006
    120,333,908       1,203       1,258,717       -  
Net income
    -       -       -       -  
Other comprehensive income (loss)
    -       -       -       -  
Total comprehensive income
                               
Repurchase of common stock
    -       -       (11,103 )     -  
Common stock issued
    781,309       8       26,186       -  
Common stock dividends -
                               
$1.40 per share
    -       -       -       -  
December 31, 2007
    121,115,217       1,211       1,273,800       -  
Net income
    -       -       -       -  
Other comprehensive income (loss)
    -       -       -       -  
Total comprehensive income
                               
Repurchase of common stock
    -       -       -       -  
Common stock issued
    531,790       5       27,353       -  
Common stock dividends -
                               
$1.56 per share
    -       -       -       -  
Change in measurement date for
                               
employee benefit plans
    -       -       -       -  
December 31, 2008
    121,647,007     $ 1,216     $ 1,301,153     $ -  
See accompanying Notes to Consolidated Financial Statements.
                 

 

 
ONEOK, Inc. and Subsidiaries
                       
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY AND COMPREHENSIVE INCOME
 
(Continued)
                       
   
Accumulated
                   
   
Other
                   
   
Comprehensive
   
Retained
   
Treasury
       
   
Income (Loss)
   
Earnings
   
Stock
   
Total
 
   
(Thousands of dollars)
 
                         
December 31, 2005
  $ (56,991 )   $ 1,085,845     $ (279,355 )   $ 1,794,757  
Net income
    -       306,312       -       306,312  
Other comprehensive income (loss)
    63,878       -       -       63,878  
Total comprehensive income
                            370,190  
Adoption of Statement 158
    32,645       -       -       32,645  
Equity unit conversion
    -       -       224,764       402,448  
Repurchase of common stock
    -       -       (285,662 )     (285,662 )
Common Stock issued
    -       -       -       37,031  
Common stock dividends -
                               
$1.22 per share
    -       (135,398 )     -       (135,451 )
December 31, 2006
    39,532       1,256,759       (340,253 )     2,215,958  
Net income
    -       304,921       -       304,921  
Other comprehensive income (loss)
    (46,601 )     -       -       (46,601 )
Total comprehensive income
                            258,320  
Repurchase of common stock
    -       -       (379,110 )     (390,213 )
Common stock issued
    -       -       9,237       35,431  
Common stock dividends -
                               
$1.40 per share
    -       (150,188 )     -       (150,188 )
December 31, 2007
    (7,069 )     1,411,492       (710,126 )     1,969,308  
Net income
    -       311,909       -       311,909  
Other comprehensive income (loss)
    (63,547 )     -       -       (63,547 )
Total comprehensive income
                            248,362  
Repurchase of common stock
    -       -       (29 )     (29 )
Common stock issued
    -       -       13,539       40,897  
Common stock dividends -
                               
$1.56 per share
    -       (162,785 )     -       (162,785 )
Change in measurement date for
                               
employee benefit plans
    -       (7,583 )             (7,583 )
December 31, 2008
  $ (70,616 )   $ 1,553,033     $ (696,616 )   $ 2,088,170  

 

ONEOK, INC. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

A.           SUMMARY OF ACCOUNTING POLICIES

Organization and Nature of Operations   - We are a diversified energy company and successor to the company founded in 1906 known as Oklahoma Natural Gas Company.  Our common stock is listed on the NYSE under the trading symbol “OKE.”  We are the sole general partner and own 47.7 percent of ONEOK Partners, L.P. (NYSE: OKS), one of the largest publicly traded master limited partnerships.

We have divided our operations into four reportable business segments based on similarities in economic characteristics, products and services, types of customers, methods of distribution and regulatory environment.  These segments are as follows:
·  
ONEOK Partners
·  
Distribution
·  
Energy Services
·  
Other

Our ONEOK Partners segment is engaged in the gathering and processing of unprocessed natural gas and fractionation of NGLs, primarily in the Mid-Continent and Rocky Mountain regions covering Oklahoma, Kansas, Montana, North Dakota and Wyoming.  These operations include the gathering of unprocessed natural gas produced from crude oil and natural gas wells.  Through gathering systems, unprocessed natural gas is aggregated and treated or processed for removal of water vapor, solids and other contaminants, and to extract NGLs in order to provide marketable natural gas, commonly referred to as residue gas.  When the NGLs are separated from the unprocessed natural gas at the processing plants, the NGLs are generally in the form of a mixed, unfractionated NGL stream.  This stream is then separated by a distillation process, referred to as fractionation, into marketable product components such as ethane, ethane/propane (E/P), propane, iso-butane, normal butane and natural gasoline (collectively, NGL products).  These NGL products can then be stored, transported and marketed to a diverse customer base of end-users.

ONEOK Partners also gathers, treats, fractionates, transports and stores NGLs.  ONEOK Partners’ natural gas liquids gathering pipelines deliver unfractionated NGLs gathered from natural gas processing plants located in Oklahoma, Kansas, the Texas panhandle and the Rocky Mountain region to fractionators it owns in Oklahoma, Kansas and Texas.  The NGLs are then separated through the fractionation process into the individual NGL products that realize the greater economic value of the NGL components.  The individual NGL products are then stored or distributed to petrochemical manufacturers, heating fuel users, refineries and propane distributors through ONEOK Partners’ distribution pipelines that move NGL products from Oklahoma and Kansas to the market centers in Conway, Kansas, and Mont Belvieu, Texas, as well as the Midwest markets near Chicago, Illinois.

ONEOK Partners operates interstate and intrastate natural gas transmission pipelines, natural gas storage facilities and non-processable natural gas gathering facilities.  ONEOK Partners’ interstate assets transport natural gas through FERC-regulated interstate natural gas pipelines that access supply from Canada, and the Mid-Continent, Rocky Mountain and Gulf Coast regions.

ONEOK Partners’ intrastate natural gas pipeline assets in Oklahoma have access to the major natural gas producing areas and transport natural gas throughout the state.  ONEOK Partners also has access to the major natural gas producing area in south central Kansas.  In Texas, its intrastate natural gas pipelines are connected to the major natural gas producing areas in the Texas panhandle and the Permian Basin and transport natural gas to the Waha Hub, where other pipelines may be accessed for transportation east to the Houston Ship Channel market, north into the Mid-Continent market and west to the California market.  ONEOK Partners owns or leases storage capacity in underground natural gas storage facilities in Oklahoma, Kansas and Texas.  ONEOK Partners’ natural gas pipelines primarily serve LDCs, large industrial companies, municipalities, irrigation customers, power generation facilities and marketing companies.

Our Distribution segment provides natural gas distribution services to more than two million customers in Oklahoma, Kansas and Texas through Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively, each a division of ONEOK.  We serve residential, commercial, industrial and transportation customers in all three states.  In addition, our distribution companies in Oklahoma and Kansas serve wholesale customers, and in Texas we serve public authority customers, such as cities, governmental agencies and schools.


Our Energy Services segment’s primary focus is to create value for our customers by delivering physical natural gas products and risk management services through our network of contracted transportation and storage capacity and natural gas supply.  These services include meeting our customers’ baseload, swing and peaking natural gas commodity requirements on a year-round basis.  To provide these bundled services, we lease storage and transportation capacity.  Our contracted storage and transportation capacity connects major supply and demand centers throughout the United States and into Canada.  With these contracted assets, our business strategies include identifying, developing and delivering specialized services and products valued by our customers, which are primarily LDCs, electric utilities, and commercial and industrial end users.  Our storage and transportation capacity allows us opportunities to optimize value through our application of market knowledge and risk management skills.

Critical Accounting Policies

The following is a summary of our most critical accounting policies, which are defined as those policies most important to the portrayal of our financial condition and results of operations and requiring our management’s most difficult, subjective or complex judgment, particularly because of the need to make estimates concerning the impact of inherently uncertain matters.  We have discussed the development and selection of our critical accounting policies and estimates with the Audit Committee of our Board of Directors.

Fair Value Measurements -   General - In September 2006, the FASB issued Statement 157, “Fair Value Measurements” that establishes a framework for measuring fair value and requires additional disclosures about fair value measurements.  Beginning January 1, 2008, we partially applied Statement 157 as allowed by FASB Staff Position (FSP) 157-2, “Effective Date of FASB Statement No. 157” that delayed the effective date of Statement 157 for nonrecurring fair value measurements associated with our nonfinancial assets and liabilities.  As of January 1, 2008, we applied the provisions of Statement 157 to our recurring fair value measurements, and the impact was not material upon adoption.  As of January 1, 2009, we have applied the provisions of Statement 157 to our nonrecurring fair value measurements associated with our nonfinancial assets and liabilities, and the impact was not material.  FSP 157-3, “Determining the Fair Value of a Financial Asset When the Market for That Asset Is Not Active,” which clarified the application of Statement 157 in inactive markets, was issued in October 2008 and was effective for our September 30, 2008, unaudited consolidated financial statements.  FSP 157-3 did not have a material impact on our consolidated financial statements.

In February 2007, the FASB issued Statement 159, “The Fair Value Option for Financial Assets and Financial Liabilities” that allows companies to elect to measure specified financial assets and liabilities, firm commitments, and nonfinancial warranty and insurance contracts at fair value on a contract-by-contract basis, with changes in fair value recognized in earnings each reporting period.  At January 1, 2008, we did not elect the fair value option under Statement 159, and therefore there was no impact on our consolidated financial statements.

Determining Fair Value - Statement 157 defines fair value as the price that would be received to sell an asset or transfer a liability in an orderly transaction between market participants at the measurement date.  We use the market and income approaches to determine the fair value of our assets and liabilities and consider the markets in which the transactions are executed.  While many of the contracts in our portfolio are executed in liquid markets where price transparency exists, some contracts are executed in markets for which market prices may exist but the market may be relatively inactive.  This results in limited price transparency that requires management’s judgment and assumptions to estimate fair values.  Inputs into our fair value estimates include commodity exchange prices, over-the-counter quotes, volatility, historical correlations of pricing data and LIBOR and other liquid money market instrument rates.  We also utilize internally developed basis curves that incorporate observable and unobservable market data.  We validate our valuation inputs with third-party information and settlement prices from other sources, where available.  In addition, as prescribed by the income approach, we compute the fair value of our derivative portfolio by discounting the projected future cash flows from our derivative assets and liabilities to present value.  The interest rate yields used to calculate the present value discount factors are derived from LIBOR, Eurodollar futures and Treasury swaps.  The projected cash flows are then multiplied by the appropriate discount factors to determine the present value or fair value of our derivative instruments.  We also take into consideration the potential impact on market prices of liquidating positions in an orderly manner over a reasonable period of time under current market conditions.  Finally, we consider credit risk of our counterparties on the fair value of our derivative assets, as well as our own credit risk for derivative liabilities, using default probabilities and recovery rates, net of collateral.  We also take into consideration current market data in our evaluation when available, such as bond prices and yields and credit default swaps.  Although we use our best estimates to determine the fair value of the derivative contracts we have executed, the ultimate market prices realized could differ from our estimates, and the differences could be material.
 
 
Fair Value Hierarchy - Statement 157 establishes the fair value hierarchy that prioritizes inputs to valuation techniques based on observable and unobservable data and categorizes the inputs into three levels, with the highest priority given to Level 1 and the lowest priority given to Level 3.  The levels are described below.
·  
Level 1 - Unadjusted quoted prices in active markets for identical assets or liabilities.
·  
Level 2 - Significant observable pricing inputs other than quoted prices included within Level 1 that are either directly or indirectly observable as of the reporting date.  Essentially, this represents inputs that are derived principally from or corroborated by observable market data.
·  
Level 3 - Generally unobservable inputs, which are developed based on the best information available and may include our own internal data.

Determining the appropriate classification of our fair value measurements within the fair value hierarchy requires management’s judgment regarding the degree to which market data is observable or corroborated by observable market data. 

See Note C for more discussion of our fair value measurements.

Derivatives, Accounting for Financially Settled Transactions and Risk Management Activities - We engage in wholesale energy marketing, retail marketing, trading and risk management activities.  We account for derivative instruments utilized in connection with these activities and services in accordance with Statement 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended.

Under Statement 133, entities are required to record all derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery.  See previous discussion in “Fair Value Measurements” for additional information.  Market value changes result in a change in the fair value of our derivative instruments.  The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the nature of the risk being hedged and how we will determine if the hedging instrument is effective.  If the derivative instrument does not qualify or is not designated as part of a hedging relationship, then we account for changes in fair value of the derivative in earnings as they occur.  Commodity price volatility may have a significant impact on the gain or loss in a given period.

To reduce our exposure to fluctuations in natural gas, NGLs and condensate prices, we periodically enter into futures, forwards, options or swap transactions in order to hedge anticipated purchases and sales of natural gas, NGLs, condensate and fuel requirements.  Interest-rate swaps are also used to manage interest-rate risk.  Under certain conditions, we designate these derivative instruments as a hedge of exposure to changes in fair values or cash flows.  For hedges of exposure to changes in cash flow, the effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) and is subsequently recorded to earnings when the forecasted transaction affects earnings.  Any ineffectiveness of designated hedges is reported in earnings during the period the ineffectiveness occurs.  For hedges of exposure to changes in fair value, the gain or loss on the derivative instrument is recognized in earnings during the period of change, together with the offsetting gain or loss on the hedged item attributable to the risk being hedged.

Upon election, many of our purchase and sale agreements that otherwise would be required to follow derivative accounting qualify as normal purchases and normal sales under Statement 133 and are therefore exempt from fair value accounting treatment.

The presentation of settled derivative instruments on either a gross or net basis in our Consolidated Statements of Income is dependent on a number of factors, including whether the derivative instrument (i) is held for trading purposes; (ii) is financially settled; (iii) results in physical delivery or services rendered; and (iv) qualifies for the normal purchase or sale exception as defined in Statement 133.  In accordance with EITF 03-11, “Reporting Realized Gains and Losses on Derivative Instruments That Are Subject to FASB Statement No. 133 and not ‘Held for Trading’ as Defined in EITF Issue No. 02-3,” EITF 99-19, “Reporting Revenue Gross as a Principal versus Net as an Agent,” and Statement 133, we report settled derivative instruments as follows:
·  
all financially settled derivative contracts are reported on a net basis;
·  
derivative instruments considered held for trading purposes that result in physical delivery are reported on a net basis;
·  
derivative instruments not considered held for trading purposes that result in physical delivery or services rendered are reported on a gross basis; and
·  
derivatives that qualify for the normal purchase or sale exception as defined in Statement 133 are reported on a gross basis.


We apply the indicators in EITF 99-19 to determine the appropriate accounting treatment for non-derivative contracts that result in physical delivery.

See Note D for more discussion of derivatives and risk management activities.

Impairment of Long-Lived Assets, Goodwill and Intangible Assets - We assess our long-lived assets for impairment based on Statement 144, “Accounting for the Impairment or Disposal of Long-Lived Assets.”  A long-lived asset is tested for impairment whenever events or changes in circumstances indicate that its carrying amount may exceed its fair value.  Fair values are based on the sum of the undiscounted future cash flows expected to result from the use and eventual disposition of the assets.

We assess our goodwill and indefinite-lived intangible assets for impairment at least annually based on Statement 142, “Goodwill and Other Intangible Assets.”  There were no impairment charges resulting from our July 1, 2008, impairment test.  As a result of recent events in the financial markets and current economic conditions, we performed a review and determined that interim testing of goodwill as of December 31, 2008, was not necessary.  As a part of our impairment test, an initial assessment is made by comparing the fair value of a reporting unit with its book value, including goodwill.  If the fair value is less than the book value, an impairment is indicated, and we must perform a second test to measure the amount of the impairment.  In the second test, we calculate the implied fair value of the goodwill by deducting the fair value of all tangible and intangible net assets of the reporting unit from the fair value determined in step one of the assessment.  If the carrying value of the goodwill exceeds the implied fair value of the goodwill, we will record an impairment charge.

We use two generally accepted valuation approaches, an income approach and a market approach, to estimate the fair value of a reporting unit.  Under the income approach, we use anticipated cash flows over a three-year period plus a terminal value and discount these amounts to their present value using appropriate rates of return.  Under the market approach, we apply multiples to forecasted EBITDA amounts.  The multiples used are consistent with historical asset transactions, and the EBITDA amounts are based on average EBITDA for a reporting unit over a three-year forecasted period.  See Note E for more discussion of goodwill.

Intangible assets with a finite useful life are amortized over their estimated useful life, while intangible assets with an indefinite useful life are not amortized.  All intangible assets are subject to impairment testing.  We had $435.4 million of intangible assets recorded on our Consolidated Balance Sheet as of December 31, 2008, of which $279.8 million in our ONEOK Partners segment is being amortized over an aggregate weighted-average period of 40 years, while the remaining balance has an indefinite life.

Our impairment tests require the use of assumptions and estimates.  If actual results are not consistent with our assumptions and estimates or our assumptions and estimates change due to new information, we may be exposed to an impairment charge.

For the investments we account for under the equity method, the premium or excess cost over underlying fair value of net assets is referred to as equity method goodwill and under Statement 142, is not subject to amortization but rather to impairment testing pursuant to APB Opinion No. 18, “The Equity Method of Accounting for Investments in Common Stock.”  The impairment test under APB Opinion No. 18 considers whether the fair value of the equity investment as a whole, not the underlying net assets, has declined and whether that decline is other than temporary.  Therefore, we periodically reevaluate the amount at which we carry the excess of cost over fair value of net assets accounted for under the equity method to determine whether current events or circumstances warrant adjustments to our carrying value in accordance with APB Opinion No. 18.  

Pension and Postretirement Employee Benefits - We have defined benefit retirement plans covering certain full-time employees.  We sponsor welfare plans that provide postretirement medical and life insurance benefits to certain employees who retire with at least five years of service.  Our actuarial consultant calculates the expense and liability related to these plans and uses statistical and other factors that attempt to anticipate future events.  These factors include assumptions about the discount rate, expected return on plan assets, rate of future compensation increases, age and employment periods.  In determining the projected benefit obligations and costs, assumptions can change from period to period and result in material changes in the costs and liabilities we recognize.  See Note J for more discussion of pension and postretirement employee benefits.



In September 2006, the FASB issued Statement 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans,” which required us to record a balance sheet liability equal to the difference between our benefit obligations and plan assets.  Statement 158 also required us to change our measurement date from September 30 to December 31.  Statement 158 was effective for our year ended December 31, 2006, except for the measurement date change, which was effective for our year ending December 31, 2008.  We determined our net periodic benefit cost for the period October 1, 2007, through December 31, 2008, based on a measurement date of September 30, 2007.  The net periodic benefit cost for the period of October 1, 2007, through December 31, 2007, was reflected as an adjustment to retained earnings as of December 31, 2008.  The impact of this adjustment was a $7.6 million reduction to retained earnings, net of taxes.

Contingencies - Our accounting for contingencies covers a variety of business activities, including contingencies for legal and environmental exposures.  We accrue these contingencies when our assessments indicate that it is probable that a liability has been incurred or an asset will not be recovered and an amount can be reasonably estimated in accordance with Statement 5, “Accounting for Contingencies.”  We base our estimates on currently available facts and our estimates of the ultimate outcome or resolution.  Accruals for estimated losses from environmental remediation obligations generally are recognized no later than completion of the remediation feasibility study.  Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is deemed probable.  Actual results may differ from our estimates resulting in an impact, positive or negative, on earnings.  See Note K for additional discussion of contingencies.

Significant Accounting Policies

Consolidation - Our consolidated financial statements include the accounts of ONEOK and our subsidiaries over which we have control.  We have recorded minority interests in consolidated subsidiaries on our Consolidated Balance Sheets to recognize the percent of ONEOK Partners that we do not own.  We reflected our percent share of ONEOK Partners’ accumulated other comprehensive income (loss) in our consolidated accumulated other comprehensive income (loss).  The remaining percent is reflected as an adjustment to minority interests in consolidated subsidiaries.  All significant intercompany balances and transactions have been eliminated in consolidation.  Investments in affiliates are accounted for using the equity method if we have the ability to exercise significant influence over operating and financial policies of our investee; conversely, if we do not have the ability to exercise significant influence, then we use the cost method.  Impairment of equity and cost method investments is recorded when the impairments are other than temporary.

Use of Estimates - The preparation of our consolidated financial statements and related disclosures in accordance with GAAP requires us to make estimates and assumptions with respect to values or conditions that cannot be known with certainty that affect the reported amount of assets and liabilities, and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements.  These estimates and assumptions also affect the reported amounts of revenue and expenses during the reporting period.  Items that may be estimated include, but are not limited to, the economic useful life of assets, fair value of assets and liabilities, obligations under employee benefit plans, provisions for uncollectible accounts receivable, unbilled revenues for natural gas delivered but for which meters have not been read, gas purchased expense for natural gas purchased but for which no invoice has been received, provision for income taxes, including any deferred tax valuation allowances, the results of litigation and various other recorded or disclosed amounts.

We evaluate these estimates on an ongoing basis using historical experience, consultation with experts and other methods we consider reasonable based on the particular circumstances.  Nevertheless, actual results may differ significantly from the estimates.  Any effects on our financial position or results of operations from revisions to these estimates are recorded in the period when the facts that give rise to the revision become known.

Cash and Cash Equivalents - Cash equivalents consist of highly liquid investments, which are readily convertible into cash and have original maturities of three months or less.

Accounts Receivable, net - Accounts receivable represent valid claims against non-affiliated customers for products sold or services rendered, net of allowances for doubtful accounts.  We assess the credit worthiness of our counterparties on an ongoing basis and require security, including prepayments and other forms of cash collateral, when appropriate.  Outstanding customer receivables are regularly reviewed for possible non-payment indicators and allowances for doubtful accounts are recorded based upon management’s estimate of collectibility at each balance sheet date.

Inventories - Our current natural gas and NGLs in storage are determined using the lower of weighted-average cost or market method.  Noncurrent natural gas and NGLs are classified as property and valued at cost.  Materials and supplies are valued at average cost.


Through December 31, 2007, the cost of current natural gas in storage for Oklahoma Natural Gas was determined under the last-in, first-out (LIFO) methodology.  The estimated replacement cost of current natural gas in storage was $72.4 million at December 31, 2007, compared with its value under the LIFO method of $85.4 million at December 31, 2007.  As of January 1, 2008, Oklahoma Natural Gas was required to change from LIFO to the weighted-average cost methodology based on a change in state law.  The impact of this change on our consolidated financial statements was immaterial, as the actual cost of gas is recovered from our rate payers through our purchased gas recovery mechanism.

Natural Gas Imbalances and Commodity Exchanges -   Natural gas imbalances and NGL exchanges are valued at market or their contractually stipulated rate.  Imbalances and NGL exchanges are settled in cash or made up in-kind, subject to the terms of the pipelines’ tariffs or by agreement.

EITF Issue No. 04-13, “Accounting for Purchases and Sales of Inventory with the Same Counterparty” defines when a purchase and a sale of inventory with the same party that operates in the same line of business should be considered a single nonmonetary transaction.  EITF 04-13 was effective for new arrangements that a company enters into in periods beginning after March 15, 2006.  We reviewed the applicability of EITF 04-13 to our operations and determined that it did not have a material impact on our financial position or results of operations.

Property, Plant and Equipment - The following table sets forth our property, plant and equipment by segment, for the periods presented.
 
   
December 31,
   
December 31,
 
   
2008
   
2007
 
   
(Thousands of dollars)
 
Non-Regulated
           
ONEOK Partners
  $ 2,465,369     $ 2,112,394  
Energy Services
    7,907       7,845  
Other
    225,479       177,356  
Regulated
               
ONEOK Partners
    3,343,310       2,323,977  
Distribution
    3,434,554       3,271,920  
Property, plant and equipment
    9,476,619       7,893,492  
Accumulated depreciation and amortization
    2,212,850       2,048,311  
Net property, plant and equipment
  $ 7,263,769     $ 5,845,181  

Our properties are stated at cost which includes AFUDC.  Generally, the cost of regulated property retired or sold, plus removal costs, less salvage, is charged to accumulated depreciation.  Gains and losses from sales or transfers of non-regulated properties or an entire operating unit or system of our regulated properties are recognized in income.  Maintenance and repairs are charged directly to expense.

The interest portion of AFUDC represents the cost of borrowed funds used to finance construction activities.  We capitalize interest expense during the construction or upgrade of qualifying assets.  Interest expense capitalized in 2008, 2007 and 2006 was $39.9 million, $15.4 million and $2.0 million, respectively.  Capitalized interest is recorded as a reduction to interest expense.  The equity portion of AFUDC represents the capitalization of the estimated average cost of equity used during the construction of major projects and is recorded in the cost of our regulated properties and as a credit to the allowance for equity funds used during construction.

Our properties are depreciated using the straight-line method over their estimated useful lives.  Generally, we apply composite depreciation rates to functional groups of property having similar economic circumstances.  We periodically conduct depreciation studies to assess the economic lives of our assets.  For our regulated assets, these deprecation studies are completed as a part of our rate proceedings, and the changes in economic lives, if applicable, are implemented prospectively when the new rates are billed.  For our non-regulated assets, if it is determined that the estimated economic life changes, then the changes are made prospectively.  Changes in the estimated economic lives of our property, plant and equipment could have a material effect on our financial position or result of operations.



The average depreciation rates for our regulated property are set forth in the following table for the periods indicated.
 
   
Years Ended December 31,
 
Regulated Property
 
2008
   
2007
   
2006
 
ONEOK Partners
    2.0% - 2.4 %     2.4% - 2.5 %     2.4% - 2.6 %
Distribution
    2.7% - 3.0 %     2.7% - 3.0 %     2.7% - 3.3 %

ONEOK Partners’ average depreciation rates for its regulated property decreased in 2008, compared with 2007, due to placing newly constructed natural gas liquids pipeline assets with longer economic lives in service.

Property, plant and equipment on our Consolidated Balance Sheets includes construction work in process for capital projects that have not yet been put in service and therefore are not being depreciated.  The following table sets forth our construction work in process, by segment, for the periods presented.

   
December 31,
   
December 31,
 
   
2008
   
2007
 
 
(Millions of dollars)
ONEOK Partners
  $ 810.0     $ 859.8  
Distribution
    57.0       51.3  
Other
    11.0       7.1  
Total construction work in process
  $ 878.0     $ 918.2  

Assets are transferred out of construction work in process when they are substantially complete and ready for their intended use, in accordance with Statement 34, “Capitalization of Interest Cost.”

Revenue Recognition   - Our ONEOK Partners segment includes natural gas gathering and processing, natural gas liquids gathering and fractionation, natural gas pipelines, and natural gas liquids pipelines operations.  ONEOK Partners’ natural gas gathering and processing operations record revenue when gas is processed in or transported through company facilities.  ONEOK Partners’ natural gas liquids gathering and fractionation operations record revenues based upon contracted services and actual volumes exchanged or stored under service agreements in the month services are provided.  Revenue for ONEOK Partners’ natural gas pipelines and natural gas liquids pipelines operations is recognized based upon contracted capacity and contracted volumes transported and stored under service agreements in the period services are provided.

Our Distribution segment’s major industrial and commercial natural gas distribution customers are invoiced as of the end of each month.  All natural gas residential distribution customers and some commercial customers are invoiced on a cyclical basis throughout the month, and we accrue unbilled revenues at the end of each month.

Our Energy Services segment’s wholesale customers are invoiced as of the end of each month based on physical sales.  Retail customers are invoiced on a cyclical basis throughout the month, and we accrue unbilled revenues at the end of each month.  Demand payments received for requirements contracts are recognized in the period in which the service is provided.  Our fixed-price physical sales are accounted for as derivatives and are recorded at fair value.  See Note D “Accounting Treatment” for additional information.

Income Taxes - Income taxes are accounted for using the provisions of Statement 109, “Accounting for Income Taxes.”  Deferred income taxes are provided for the difference between the financial statement and income tax basis of assets and liabilities and carry forward items, based on income tax laws and rates existing at the time the temporary differences are expected to reverse.  The effect on deferred taxes of a change in tax rates is deferred and amortized for operations regulated by the OCC, KCC, RRC and various municipalities in Texas.  For all other operations, the effect is recognized in income in the period that includes the enactment date.  We continue to amortize previously deferred investment tax credits for ratemaking purposes over the period prescribed by the OCC, KCC, RRC and various municipalities in Texas.

In June 2006, the FASB issued FIN 48, “Accounting for Uncertainty in Income Taxes - An Interpretation of FASB Statement No. 109,” which was effective for our year beginning January 1, 2007.  This interpretation was issued to clarify the accounting for uncertainty in income taxes recognized in the financial statements by prescribing a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return.  FIN 48 requires the recognition of penalties and interest on any unrecognized tax benefits.  Our policy is to
 
 
reflect penalties and interest as part of income tax expense as they become applicable.  The adoption of FIN 48 had an immaterial impact on our consolidated financial statements, and the impact for 2008 and 2007 was not material.

We file numerous consolidated and separate income tax returns in the United States federal jurisdiction and in many state jurisdictions.  We also file returns in Canada.  No extensions of statute of limitations have been requested or granted.  Our 2007 and 2006 United States federal income tax returns are currently under audit.

Regulation - Our distribution operations and ONEOK Partners’ intrastate natural gas transmission pipelines are subject to the rate regulation and accounting requirements of the OCC, KCC, RRC and various municipalities in Texas.  ONEOK Partners’ interstate natural gas and natural gas liquids pipelines are subject to regulation by the FERC.  In Kansas and Texas, natural gas storage may be regulated by the state and the FERC for certain types of services.  Oklahoma Natural Gas, Kansas Gas Service, Texas Gas Service and portions of our ONEOK Partners segment follow the accounting and reporting guidance contained in Statement 71, “Accounting for the Effects of Certain Types of Regulation.”  During the rate-making process, regulatory authorities set the framework for what we can charge customers for our services and establish the manner that our costs are accounted for, including allowing us to defer recognition of certain costs and permitting recovery of the amounts through rates over time as opposed to expensing such costs as incurred.  Certain examples of types of regulatory guidance include costs for fuel and losses, acquisition costs, contributions in aid of construction, charges for depreciation, and gains or losses on disposition of assets.  This allows us to stabilize rates over time rather than passing such costs on to the customer for immediate recovery.  Actions by regulatory authorities could have an affect on the amount recovered from rate payers.  Any difference in the amount recoverable and the amount deferred is recorded as income or expense at the time of the regulatory action.  If all or a portion of the regulated operations are no longer subject to the provisions of Statement 71, a write-off of regulatory assets and costs not recovered may be required.

At December 31, 2008 and 2007, we recorded regulatory assets of approximately $523.3 million and $309.4 million, respectively, which are being recovered through various rate cases or are expected to be recovered.  Regulatory assets are being recovered as a result of approved rate proceedings over varying time periods up to 40 years.  These assets are reflected in other assets on our Consolidated Balance Sheets.

Asset Retirement Obligations - Statement 143, “Accounting for Asset Retirement Obligations,” applies to legal obligations associated with the retirement of long-lived assets that result from the acquisition, construction, development and/or normal use of the asset.  Statement 143 requires that we recognize the fair value of a liability for an asset retirement obligation in the period when it is incurred if a reasonable estimate of the fair value can be made.  The fair value of the liability is added to the carrying amount of the associated asset, and this additional carrying amount is depreciated over the life of the asset.  The liability is accreted at the end of each period through charges to operating expense.  If the obligation is settled for an amount other than the carrying amount of the liability, we will recognize a gain or loss on settlement.  The depreciation and amortization expense is immaterial to our consolidated financial statements.

In accordance with long-standing regulatory treatment, we collect through rates the estimated costs of removal on certain regulated properties through depreciation expense, with a corresponding credit to accumulated depreciation and amortization.  These removal costs are non-legal obligations as defined by Statement 143.  However, these non-legal asset-removal obligations are accounted for as a regulatory liability under Statement 71.  Historically, the regulatory authorities that have jurisdiction over our regulated operations have not required us to track this amount; rather, these costs are addressed prospectively as depreciation rates and are set in each general rate order.  We have made an estimate of our removal cost liability using current rates since the last general rate order in each of our jurisdictions.  However, significant uncertainty exists regarding the ultimate determination of this liability, pending, among other issues, clarification of regulatory intent.  We continue to monitor the regulatory authorities and the liability may be adjusted as more information is obtained.  We have reclassified the estimated non-legal asset removal obligation from accumulated deprecation and amortization to non-current liabilities in other deferred credits on our Consolidated Balance Sheets.  To the extent this estimated liability is adjusted, such amounts will be reclassified between accumulated depreciation and amortization and other deferred credits and therefore will not have an impact on earnings.

Share-Based Payment - Statement 123R, “Share-Based Payment,” requires companies to expense the fair value of share-based payments net of estimated forfeitures.  We adopted Statement 123R as of January 1, 2006, and elected to use the modified prospective method.  Statement 123R did not have a material impact on our consolidated financial statements as we have been expensing share-based payments since our adoption of Statement 148, “Accounting for Stock-Based Compensation - Transition and Disclosure,” on January 1, 2003.  Awards granted after the adoption of Statement 123R are expensed under the requirements of Statement 123R, while equity awards granted prior to the adoption of Statement 123R will continue to be expensed under Statement 148.


Earnings per Common Share - Basic EPS is calculated based on the daily weighted-average number of shares of common stock outstanding during the period.  Diluted EPS is calculated based on the daily weighted-average number of shares of common stock outstanding during the period plus potentially dilutive components.  The dilutive components are calculated based on the dilutive effect for each quarter.  For fiscal year periods, the dilutive components for each quarter are averaged to arrive at the fiscal year-to-date dilutive component.

Other

Master Netting Arrangements - In April 2007, the FASB issued FSP FIN 39-1, “Amendment of FASB Interpretation No. 39,” which requires entities that offset the fair value amounts recognized for derivative receivables and payables to also offset the fair value amounts recognized for the right to reclaim cash collateral with the same counterparty under a master netting arrangement.  We applied the provisions of FSP FIN 39-1 to our consolidated financial statements beginning January 1, 2008, and the impact was not material.  See Note C for applicable disclosures.

Business Combinations - In December 2007, the FASB issued Statement 141R, “Business Combinations,” which will require most identifiable assets, liabilities, noncontrolling interest (previously referred to as minority interest) and goodwill acquired in a business combination to be recorded at fair value.  Statement 141R was effective for our year beginning January 1, 2009.  Because the provisions of Statement 141R are applied prospectively, our 2009 and subsequent consolidated financial statements will not be impacted unless we complete a business combination.

Noncontrolling Interests - In December 2007, the FASB issued Statement 160, “Noncontrolling Interest in Consolidated Financial Statements - an amendment to ARB No. 51,” which requires a noncontrolling interest (previously referred to as minority interest) to be reported as a component of equity.  Statement 160 was effective for our year beginning January 1, 2009, and requires retroactive adoption of the presentation and disclosure requirements for existing minority interests beginning with our March 31, 2009, Quarterly Report on Form 10-Q.  Statement 160 is not expected to have a material impact on our consolidated financial statements; however, certain financial statement presentation changes and additional required disclosures will be made.

Derivative Instruments and Hedging Activities Disclosure - In March 2008, the FASB issued Statement 161, “Disclosures about Derivative Instruments and Hedging Activities - an amendment to FASB Statement No. 133,” which requires enhanced disclosures about how derivative and hedging activities affect our financial position, financial performance and cash flows.  Statement 161 was effective for our year beginning January 1, 2009, and will be applied prospectively beginning with our March 31, 2009, Quarterly Report on Form 10-Q.

Equity Method Investments - In November 2008, the FASB ratified EITF 08-6, “Equity Method Investment Accounting Considerations,” which clarified certain issues that arose following the issuance of Statements 141R and 160 related to the accounting for equity method investments.  EITF 08-6 was effective for our year beginning January 1, 2009, and is not expected to have a material impact on our consolidated financial statements.

Postretirement Benefit Plan Assets - In December 2008, the FASB issued FSP FAS 132R-1, “Employers’ Disclosures about Postretirement Benefit Plan Assets,” which amends Statement 132R, “Employers’ Disclosures about Pensions and Other Postretirement Benefits,” to require enhanced disclosures about our plan assets, including our investment policies, major categories of plan assets, significant concentrations of risk within plan assets, and inputs and valuation techniques used to measure the fair value of plan assets.  FSP FAS 132R-1 is effective for our fiscal year ending December 31, 2009, and will be applied prospectively.

Reclassifications - Certain amounts in our consolidated financial statements have been reclassified to conform to the 2008 presentation.  These reclassifications did not impact previously reported net income or shareholders’ equity.

B.           ACQUISITIONS AND DIVESTITURES

Acquisition of NGL Pipeline - In October 2007, ONEOK Partners completed the acquisition of an interstate natural gas liquids and refined petroleum products pipeline system and related assets from a subsidiary of Kinder Morgan Energy Partners, L.P. (Kinder Morgan) for approximately $300 million, before working capital adjustments.  The system extends from Bushton and Conway, Kansas, to Chicago, Illinois, and transports, stores and delivers a full range of NGL and refined petroleum products.  The FERC-regulated system spans 1,624 miles and has a capacity to transport up to 134 MBbl/d.  The transaction also included approximately 978 MBbl of owned storage capacity, eight NGL terminals and a 50 percent
 
 
ownership of Heartland.  ConocoPhillips owns the other 50 percent of Heartland and is the managing partner of the Heartland joint venture, which consists primarily of a refined petroleum products terminal and pipelines with access to two other refined petroleum products terminals.  ONEOK Partners’ investment in Heartland is accounted for under the equity method of accounting.  Financing for this transaction came from a portion of the proceeds of ONEOK Partners’ September 2007 issuance of $600 million 6.85 percent Senior Notes due 2037 (the 2037 Notes).  See Note I for a discussion of the 2037 Notes.  The working capital settlement was finalized in April 2008, with no material adjustments.

Overland Pass Pipeline Company - In May 2006, a subsidiary of ONEOK Partners entered into an agreement with a subsidiary of The Williams Companies, Inc. (Williams) to form a joint venture called Overland Pass Pipeline Company.  In November 2008, Overland Pass Pipeline Company completed construction of a 760-mile natural gas liquids pipeline from Opal, Wyoming, to the Mid-Continent natural gas liquids market center in Conway, Kansas.  The Overland Pass Pipeline is designed to transport approximately 110 MBbl/d of unfractionated NGLs and can be increased to approximately 255 MBbl/d with additional pump facilities.  During 2006, ONEOK Partners paid $11.6 million to Williams for the acquisition of its interest in the joint venture and for reimbursement of initial capital expenditures.  A subsidiary of ONEOK Partners owns 99 percent of the joint venture, managed the construction project, advanced all costs associated with construction and is currently operating the pipeline.  On or before November 17, 2010, Williams will have the option to increase its ownership up to 50 percent, with the purchase price being determined in accordance with the joint venture’s operating agreement.  If Williams exercises its option to increase its ownership to the full 50 percent, Williams would have the option to become operator.  The pipeline project cost was approximately $575 million, excluding AFUDC.

As part of a long-term agreement, Williams dedicated its NGL production from two of its natural gas processing plants in Wyoming to the Overland Pass Pipeline.  Subsidiaries of ONEOK Partners will provide downstream fractionation, storage and transportation services to Williams.

ONEOK Partners - In April 2006, we sold certain assets comprising our former gathering and processing, natural gas liquids, and pipelines and storage segments to ONEOK Partners for approximately $3 billion, including $1.35 billion in cash, before adjustments, and approximately 36.5 million Class B limited partner units in ONEOK Partners.  The Class B limited partner units and the related general partner interest contribution were valued at approximately $1.65 billion.  We also purchased, through ONEOK Partners GP, from an affiliate of TransCanada, 17.5 percent of the general partner interest in ONEOK Partners for $40 million.  This purchase resulted in our ownership of the entire 2 percent general partner interest in ONEOK Partners.  Following the completion of the transactions, we owned a total of approximately 37.0 million common and Class B limited partner units and the entire 2 percent general partner interest and control the partnership.  Our overall interest in ONEOK Partners, including the 2 percent general partner interest, was 45.7 percent at the date of acquisition.

Disposition of 20 percent interest in Northern Border Pipeline - In April 2006, in connection with the transactions described immediately above, our ONEOK Partners segment completed the sale of a 20 percent partnership interest in Northern Border Pipeline to TC PipeLines for approximately $297 million.  Our ONEOK Partners segment recorded a gain on the sale of approximately $113.9 million in the second quarter of 2006.  ONEOK Partners and TC PipeLines each now own a 50 percent interest in Northern Border Pipeline, and an affiliate of TransCanada became operator of the pipeline in April 2007.  Neither ONEOK Partners nor TC PipeLines has control of Northern Border Pipeline, as control is shared equally through Northern Border Pipeline’s Management Committee.  As a result of this transaction, ONEOK Partners’ interest in Northern Border Pipeline has been accounted for as an investment under the equity method, applied on a retroactive basis to January 1, 2006.

Acquisition of Guardian Pipeline Interests - In April 2006, our ONEOK Partners segment acquired the 66-2/3 percent interest in Guardian Pipeline not previously owned by ONEOK Partners for approximately $77 million, increasing its ownership interest to 100 percent.  ONEOK Partners used borrowings from its credit facility to fund the acquisition of the additional interest in Guardian Pipeline.  Following the completion of the transaction, we consolidated Guardian Pipeline in our consolidated financial statements.  This change was accounted for on a retroactive basis to January 1, 2006.



C.           FAIR VALUE MEASUREMENTS

See Note A for a discussion of our fair value measurements and the fair value hierarchy.

Recurring Fair Value Measurements - The following table sets forth our recurring fair value measurements for the period indicated.

   
December 31, 2008
 
   
Level 1
   
Level 2
   
Level 3
   
Netting (a)
   
Total
 
   
(Thousands of dollars)
 
Assets
                             
Derivatives
  $ 580,029     $ 215,116     $ 454,377     $ (840,814 )   $ 408,708  
Trading securities
    4,910       -       -       -       4,910  
Available-for-sale investment securities
    1,665       -       -       -       1,665  
Fair value of firm commitments
    -       -       42,179       -       42,179  
Total assets
  $ 586,604     $ 215,116     $ 496,556     $ (840,814 )   $ 457,462  
                                         
Liabilities
                                       
Derivatives
  $ (501,726 )   $ (55,705 )   $ (412,022 )   $ 748,136     $ (221,317 )
Long-term debt swapped to floating
    -       -       (171,455 )     -       (171,455 )
Total liabilities
  $ (501,726 )   $ (55,705 )   $ (583,477 )   $ 748,136     $ (392,772 )
 
(a) - Our derivative assets and liabilities are presented in our Consolidated Balance Sheets on a net basis. We net derivative assets and liabilities, including cash collateral in accordance with FSP FIN 39-1, when a legally enforceable master netting arrangement exists between us and the counterparty to a derivative contract. At December 31, 2008, we held $92.7 million of cash collateral.
 

For derivatives for which fair value is determined based on multiple inputs, Statement 157 requires that the measurement for an individual derivative be categorized within a single level based on the lowest-level input that is significant to the fair value measurement in its entirety.

Our Level 1 fair value measurements are based on NYMEX-settled prices, actively quoted prices for equity securities and foreign currency forward exchange rates.  These balances are predominantly comprised of exchange-traded derivative contracts, including futures and certain options for natural gas and crude oil, that are valued based on unadjusted quoted prices in active markets.  Also included in Level 1 are available-for-sale and trading securities and foreign currency forwards.

Our Level 2 fair value inputs are based on NYMEX-settled prices that are utilized to determine the fair value of certain non-exchange-traded financial instruments, including natural gas and crude oil swaps.

Our Level 3 inputs are based on over-the-counter quotes, market volatilities derived from NYMEX-settled prices, internally developed basis curves incorporating observable and unobservable market data, modeling techniques using observable market data and historical correlations of NGL product prices to crude oil, and spot and forward LIBOR curves.  The derivatives categorized as Level 3 include over-the-counter swaps and options for natural gas and crude oil, NGL swaps and forwards, natural gas basis and swing swaps and physical forward contracts, and interest-rate swaps.  Also included in Level 3 are the fair values of firm commitments and long-term debt that have been hedged.

Transfers in and out of Level 3 typically result from derivatives for which fair value is determined based on multiple inputs.  Since we categorize our derivatives based on the lowest level input that is significant, a derivative can move between Level 2 and Level 3 as the value of the various inputs changes.



The following table sets forth the reconciliation of our Level 3 fair value measurements for the period indicated.

   
Derivative
Assets (Liabilities)
   
Fair Value of
Firm Commitments
   
Long-Term
Debt
   
Total
 
   
(Thousands of dollars)
 
January 1, 2008
  $ (54,582 )   $ 42,684     $ (338,538 )   $ (350,436 )
   Total realized/unrealized gains (losses):
                               
       Included in earnings (a)
    6,080       (505 )     (2,917 )     2,658  
       Included in other comprehensive
            income (loss)
    84,592       -       -       84,592  
   Terminations prior to maturity
    (5,074 )     -       170,000       164,926  
   Transfers in and/or out of Level 3
    11,339       -       -       11,339  
December 31, 2008
  $ 42,355     $ 42,179     $ (171,455 )   $ (86,921 )
                                 
Total gains (losses) for the period included in
   earnings attributable to the change in unrealized
   gains (losses) relating to assets and liabilities
   still held as of December 31, 2008 (a)
  $ (116,127 )   $ 153,221     $ (2,917 )   $ 34,177  
(a) - Reported in revenues in our Consolidated Statements of Income.
                         

Realized/unrealized gains (losses) include the realization of our fair value derivative contracts through maturity, changes in fair value of our hedged firm commitments and fixed-rate debt swapped to floating.  Terminations prior to maturity represents swap contracts terminated prior to maturity that will remain in accumulated other comprehensive income (loss) until the underlying forecasted transaction occurs; and the long-term debt associated with the interest rate swaps that were terminated during the period.  Transfers into Level 3 represent existing assets or liabilities that were previously categorized at a higher level for which the inputs to our models became unobservable.  Transfers out of Level 3 represent existing assets and liabilities that were previously classified as Level 3 for which the inputs became observable in accordance with our hierarchy policy discussed on page 78.

Fair Value - The following table represents the fair value of our energy marketing and risk management assets and liabilities for the periods indicated.

   
December 31, 2008
   
December 31, 2007
 
   
Assets
   
Liabilities
   
Assets
   
Liabilities
 
   
(Thousands of dollars)
 
Energy Services - financial non-trading instruments:
                       
Natural gas
                       
Exchange-traded instruments
  $ 31,509     $ 640     $ 4,739     $ 14,853  
Over-the-counter swaps
    73,095       1,624       41,633       19,160  
Options
    186       -       1,887       2,467  
Other (a)
    39,453       2,515       7,469       2,741  
      144,243       4,779       55,728       39,221  
Energy Services - financial trading instruments:
                               
Natural gas
                               
Exchange-traded instruments
    6,158       144       1,641       888  
Over-the-counter swaps
    14,002       321       11,258       8,013  
Options
    7,043       191       14,173       18,654  
Other (a)
    358       249       420       287  
      27,561       905       27,492       27,842  
ONEOK Partners - cash flow hedges
    63,780       -       -       21,304  
Distribution - natural gas swaps
    -       23,003       -       9,752  
Energy Services - cash flow hedges
    62,250       44,248       57,966       8,344  
Energy Services - fair value hedges
    109,419       148,382       5,237       51,343  
Interest rate swaps - fair value hedges
    1,455       -       1,496       2,958  
                                 
Total fair value
  $ 408,708     $ 221,317     $ 147,919     $ 160,764  
(a) - Other includes physical natural gas.
                               



Financial Instruments -   The following information represents the carrying amounts and estimated fair values of our financial instruments for the periods indicated, excluding energy marketing and risk management assets and liabilities, which are listed in the table above.

The approximate fair value of cash and cash equivalents, short-term investments, accounts and notes receivable and accounts and notes payable is equal to book value, due to their short-term nature.  The estimated fair value of long-term debt has been determined using quoted market prices of the same or similar issues, discounted cash flows, and/or rates currently available to us for debt with similar terms and remaining maturities.  The book value of our long-term debt was $4.23 billion and $4.64 billion at December 31, 2008 and 2007, respectively.  The approximate fair value of our long-term debt was $3.95 billion and $4.75 billion at December 31, 2008 and 2007, respectively.

The tables below show information about our investment securities classified as available-for-sale.

   
December 31,
 
   
2008
   
2007
   
2006
 
 
(Thousands of dollars)
 
Available-for-sale securities held
                 
Aggregate fair value
  $ 1,665     $ 24,151     $ 22,416  
Reported in accumulated other
   comprehensive income (loss) for net
   unrealized holding gains
  $ 815     $ 13,678     $ 12,614  
 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
   
(Thousands of dollars)
 
Available-for-sale securities held
                 
Gains reclassified to earnings
   from accumulated other
   comprehensive income (loss)
  $ 11,142     $ -     $ -  
                         
Available-for-sale securities sold
                       
Proceeds from sale (a)
  $ 3,886     $ -     $ -  
Gain from sale (a)
  $ 3,369     $ -     $ -  
(a) - We sold a portion of our available-for-sale securities and used specific identification
 to determine the cost of the securities sold.
 

We transferred securities from available-for-sale to trading during the year ended December 31, 2008, and recognized a $7.7 million gain, due to a reconsideration event in August 2008 when our NYMEX Holding, Inc. Class A shares held were converted to CME Group, Inc. (CME) Class A shares due to the NYMEX Holding, Inc. and CME merger.  A modification was made to the number of shares required to be maintained by NYMEX Holding, Inc. Class A Members which resulted in our sale of certain shares and the reclassification of the remaining shares to trading.  These trading securities were still held as of December 31, 2008.

The gains reclassified into earnings from accumulated other comprehensive income (loss) for the year ended December 31, 2008, of $11.1 million include the $7.7 million gain discussed in the previous paragraph, as well as a $3.4 million realized gain on the sale of available-for-sale securities.

D.           ENERGY MARKETING AND RISK MANAGEMENT ACTIVITIES

Risk Policy and Oversight - Market risks are monitored by our risk control group that is responsible for ensuring compliance with our risk management policies.

We control the scope of risk management, marketing and trading operations through a comprehensive set of policies and procedures involving senior levels of management.  The Audit Committee of our Board of Directors has oversight responsibilities for our risk management limits and policies.  Our risk oversight committee, comprised of corporate and business segment officers, oversees all activities related to commodity price and credit risk management, and marketing and
 
 
trading activities.  The committee also monitors risk metrics including value-at-risk (VAR) and mark-to-market losses.  We have a corporate risk control organization that is assigned responsibility for establishing and enforcing the policies and procedures and monitoring certain risk metrics.  Key risk control activities include credit review and approval, credit and performance risk measurement and monitoring, validation of transactions, portfolio valuation, VAR and other risk metrics.

Commodity and Interest Rate Risk Management Activities - Our operating results are affected by commodity price fluctuations.  We routinely enter into derivative financial instruments to minimize the risk of commodity price fluctuations related to anticipated sales of natural gas and condensate, NGLs, purchase and sale commitments, fuel requirements, currency exposure, transportation and storage contracts, and natural gas inventories.  We are also subject to the risk of interest-rate fluctuations in the normal course of business.  We manage interest-rate risk through the use of fixed-rate debt, floating-rate debt and, at times, interest-rate swaps.

Our Energy Services segment includes our wholesale and retail natural gas marketing and financial trading operations.  Our Energy Services segment mitigates the commodity risk associated with our fixed-price physical purchase and sale commitments through the use of derivative instruments.  With respect to the net open positions that exist within our marketing and financial trading operations, fluctuating commodity market prices can impact our financial position and results of operations, either favorably or unfavorably.  The net open positions are actively managed, and the impact of the changing prices on our financial condition at a point in time is not necessarily indicative of the impact of price movements throughout the year.

Operating margins associated with ONEOK Partners’ natural gas gathering and processing and natural gas liquids gathering and fractionation businesses are sensitive to changes in natural gas, condensate and NGL prices, principally as a result of contractual terms under which natural gas is processed and products are sold.  ONEOK Partners uses physical forward sales and derivative instruments to secure a certain price for natural gas, condensate and NGL products.

Our Distribution segment also uses derivative instruments to hedge the cost of anticipated natural gas purchases during the winter heating months to protect their customers from upward volatility in the market price of natural gas.  Gains or losses associated with these derivative instruments are included in, and recoverable through, the monthly purchased gas cost mechanism.

Accounting Treatment - We account for derivative instruments and hedging activities in accordance with Statement 133. Under Statement 133, entities are required to record derivative instruments at fair value, with the exception of normal purchases and normal sales that are expected to result in physical delivery.  The accounting for changes in the fair value of a derivative instrument depends on whether it has been designated and qualifies as part of a hedging relationship and, if so, the reason for holding it.  If the derivative instrument does not qualify or is not designated as part of a hedging relationship, we account for changes in fair value of the derivative instrument in earnings as they occur.  We record changes in the fair value of derivative instruments that are considered held for trading purposes as revenues and derivative instruments considered not held for trading purposes as cost of sales and fuel in our Consolidated Statements of Income.  If certain conditions are met, entities may elect to designate a derivative instrument as a hedge of exposure to changes in fair values, cash flows or foreign currencies.  For hedges of exposure to changes in fair value, the gain or loss on the derivative instrument is recognized in earnings during the period of change together with the offsetting loss or gain on the hedged item attributable to the risk being hedged.  The difference between the change in fair value of the derivative instrument and the change in fair value of the hedged item represents hedge ineffectiveness, which is reported in earnings during the period the ineffectiveness occurs.  For hedges of exposure to changes in cash flow, the effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) and is subsequently recorded in earnings when the forecasted transaction affects earnings.

As required by Statement 133, we formally document all relationships between hedging instruments and hedged items, as well as risk management objectives, strategies for undertaking various hedge transactions and methods for assessing and testing correlation and hedge ineffectiveness.  We specifically identify the asset, liability, firm commitment or forecasted transaction that has been designated as the hedged item.  We assess the effectiveness of hedging relationships by performing a regression analysis on our cash flow and fair value hedging relationships quarterly to ensure the hedge relationships are highly effective on a retrospective and prospective basis, as required by Statement 133.  We also document our normal physical purchases and physical sales transactions that we elect to exempt from fair value accounting treatment.  Although we believe we have appropriate internal controls over our accounting for derivatives, interpreting Statement 133 and the related documentation requirements is very complex.  In addition, future interpretations may impact our application of Statement 133.


EITF 03-11, “Reporting Realized Gains and Losses on Derivative Instruments That Are Subject to FASB Statement No. 133 and Not ‘Held for Trading Purposes’ as Defined in EITF Issue No. 02-3,” provides that the determination of whether realized gains and losses on physically settled derivative contracts not held for trading purposes should be reported in the Consolidated Statements of Income on a gross or net basis is a matter of judgment that depends on the relevant facts and circumstances.  Consideration of the facts and circumstances should be made in the context of the various activities of the entity rather than based solely on the terms of the individual contracts.

We evaluate the accounting treatment related to the presentation of revenues from the different types of activities to determine which amounts should be reported on a gross or net basis under the guidance in EITF 03-11.  For derivative instruments considered held for trading purposes that result in physical delivery, the indicators in EITF 02-3, “Issues Involved in Accounting for Derivative Contracts Held for Trading Purposes and Contracts Involved in Energy Trading and Risk Management Activities” are used to determine the proper treatment.  These activities and all financially settled derivative contracts are reported on a net basis.

For derivative instruments that are not considered held for trading purposes and that result in physical delivery, the indicators in EITF 03-11 and EITF Issue No. 99-19, “Reporting Revenue Gross as a Principal versus Net as an Agent,” are used to determine the proper treatment.  We account for the realized revenues and purchase costs of these contracts that result in physical delivery on a gross basis.  We apply the indicators in EITF 99-19 to determine the appropriate accounting treatment for non-derivative contracts that result in physical delivery.  Derivatives that qualify for the normal purchase or sale exception as defined in Statement 133 are also reported on a gross basis.

Cash flows from futures, forwards, options and swaps that are accounted for as hedges are included in the same cash flow statement category as the cash flows from the related hedged items.

Fair Value Hedges - In 2008 and prior years, we and ONEOK Partners terminated various interest-rate swap agreements.  The net savings from the termination of these swaps is being recognized in interest expense over the terms of the debt instruments originally hedged.  Net interest expense savings for 2008 from amortization of terminated swaps was $10.5 million, and the remaining net savings for all terminated swaps will be recognized over the following periods.

         
ONEOK
       
   
ONEOK
   
Partners
   
Total
 
   
(Millions of dollars)
 
2009
  $ 6.5     $ 3.7     $ 10.2  
2010
  $ 6.4     $ 3.7     $ 10.1  
2011
  $ 3.4     $ 0.9     $ 4.3  
2012
  $ 1.7     $ -     $ 1.7  
2013
  $ 1.7     $ -     $ 1.7  
Thereafter
  $ 25.3     $ -     $ 25.3  

At December 31, 2008, the interest on $170 million of our fixed-rate debt was swapped to floating using interest-rate swaps.  The floating rate was based on both the three- and six-month LIBOR, depending upon the swap.  Based on the actual performance for the year ended December 31, 2008, the weighted-average interest rate on the swapped debt decreased from 6.17 percent to 4.39 percent.  At December 31, 2008, we recorded a net asset of $1.5 million to recognize the interest-rate swaps at fair value.  Long-term debt includes an additional $1.5 million to recognize the change in the fair value of the related hedged debt.  ONEOK Partners had no interest-rate swap agreements at December 31, 2008.  See Note I for additional discussion of long-term debt.

Our Energy Services segment uses basis swaps to hedge the fair value of certain firm transportation commitments.  Net gains or losses from the fair value hedges and ineffectiveness are recorded to cost of sales and fuel.  The ineffectiveness related to these hedges included losses of $3.3 million, $5.3 million and $9.0 million for 2008, 2007 and 2006, respectively.

In September 2007, our Energy Services segment was notified that a portion of the volume contracted under our firm transportation agreement with Cheyenne Plains Gas Pipeline Company would be curtailed due to a fire at a Cheyenne Plains pipeline compressor station.  The fire damaged a significant amount of instrumentation and electrical wiring, causing Cheyenne Plains Gas Pipeline Company to declare a force majeure event on the pipeline.  This firm commitment was hedged in accordance with Statement 133.  The discontinuance of fair value hedge accounting on the portion of the firm commitment
 
 
that was impacted by the force majeure event resulted in a loss of approximately $5.5 million in the third quarter of 2007, of which $2.4 million of insurance proceeds were recovered and recognized in the first quarter of 2008.

Cash Flow Hedges -   Our Energy Services segment uses derivative instruments to hedge the cash flows associated with our anticipated purchases and sales of natural gas and the cost of fuel used in transportation of natural gas.  Accumulated other comprehensive income (loss) at December 31, 2008, includes gains of approximately $10.3 million, net of tax, related to these hedges that will be realized within the next 24 months as forecasted transactions affect earnings.  If prices remain at current levels, we will recognize $7.2 million in net gains over the next 12 months, and we will recognize net gains of $3.1 million thereafter.  In accordance with Statement 133, the actual gains or losses will be reclassified into earnings when the related physical transactions affect earnings.

During the third and fourth quarters of 2008, the carrying value of natural gas in storage was written down by $308.5 million in order to record inventory at the lower of cost or market.  As required by Statement 133, we reclassified $298.8 million of deferred gains, before income taxes, on associated cash flow hedges from accumulated other comprehensive income (loss) into earnings.

Through an affiliate, our ONEOK Partners segment periodically enters into derivative instruments to hedge the cash flows associated with its exposure to changes in the price of natural gas, NGLs and condensate.  At December 31, 2008, our ONEOK Partners’ segment reflected an unrealized gain of $20.1 million, net of tax, in accumulated other comprehensive income (loss), with a corresponding offset in energy marketing and risk management assets and liabilities, all of which will be recognized over the next 12 months.

Ineffectiveness related to our cash flow hedges resulted in gains of approximately $1.4 million, $0.2 million and $15.0 million in 2008, 2007 and 2006, respectively.  In the event that it becomes probable that a forecasted transaction will not occur, we would discontinue cash flow hedge treatment, which would affect earnings.  There were no material gains or losses in 2008, 2007 or 2006 due to the discontinuance of cash flow hedge treatment.

Credit Risk - We maintain credit policies with regard to our counterparties that we believe minimize overall credit risk.  These policies include an evaluation of potential counterparties’ financial condition (including credit ratings and credit default swap rates), collateral requirements under certain circumstances and the use of standardized agreements which allow for netting of positive and negative exposures associated with a single counterparty.

Our counterparties consist primarily of financial institutions, major energy companies, LDCs, electric utilities and commercial and industrial end-users.  This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions.  Based on our policies, exposures, credit and other reserves, we do not anticipate a material adverse effect on our financial position or results of operations as a result of counterparty nonperformance.

E.           GOODWILL AND INTANGIBLE ASSETS

Goodwill

Carrying Amount - The following table sets forth goodwill recorded on our Consolidated Balance Sheets for the periods indicated.

   
December 31,
 
   
2008
   
2007
 
   
(Thousands of dollars)
 
ONEOK Partners
  $ 433,537     $ 431,418  
Distribution
    157,953       157,953  
Energy Services
    10,255       10,255  
Other
    1,099       1,099  
Total Goodwill
  $ 602,844     $ 600,725  

Equity Method Goodwill - For the investments we account for under the equity method, the premium or excess cost over underlying fair value of net assets is referred to as equity method goodwill.  Investment in unconsolidated affiliates on our accompanying Consolidated Balance Sheets includes equity method goodwill of $185.6 million as of December 31, 2008 and 2007.


Impairment Test - We apply the provisions of Statement 142 and perform our annual impairment test on July 1.  There were no impairment charges resulting from our July 1, 2008, impairment test.  As a result of recent events in the financial markets and current economic conditions, we performed a review and determined that interim testing of goodwill as of December 31, 2008, was not necessary.

Black Mesa - During 2006, we recorded a goodwill and asset impairment related to ONEOK Partners’ Black Mesa Pipeline of $8.4 million and $3.6 million, respectively, which was recorded as depreciation and amortization.  The reduction to our net income, net of minority interests and income taxes, was $3.0 million.

Intangible Assets

Our ONEOK Partners segment had $279.8 million of intangible assets primarily related to acquired contracts, which are being amortized over an aggregate weighted-average period of 40 years.  The remaining intangible asset balance has an indefinite life.  Amortization expense for intangible assets for both 2008 and 2007 was $7.7 million, and the aggregate amortization expense for each of the next five years is estimated to be approximately $7.7 million.  The following table reflects the gross carrying amount and accumulated amortization of intangible assets for the periods presented.

   
Gross
   
Accumulated
   
Net
 
   
Intangible Assets
   
Amortization
   
Intangible Assets
 
 
(Thousands of dollars)
December 31, 2007
  $ 462,214     $ (19,166 )   $ 443,048  
December 31, 2008
  $ 462,214     $ (26,832 )   $ 435,382  

F.           OTHER COMPREHENSIVE INCOME (LOSS)

The table below shows the gross amount of other comprehensive income (loss) and related tax (expense) benefit for the periods indicated.

       
Year Ended
         
Year Ended
     
   
December 31, 2008
 
December 31, 2007
 
   
Gross
 
Tax (Expense) or Benefit
 
Net
 
Gross
 
Tax (Expense)
or Benefit
 
Net
 
   
(Thousands of dollars)
 
Unrealized gains on energy
   marketing and risk
   management assets/liabilities
  $ 276,400     (103,705 ) $ 172,695   $ 48,888   $ (21,836 ) $ 27,052  
Less:  Gains on energy marketing and
   risk management assets/liabilities
   recognized in net income
    277,413     (107,303 )   170,110     149,535     (57,840 )   91,695  
Unrealized holding gains (losses) on
   investment securities arising
   during the period
    (9,837 )   3,805     (6,032 )   1,735     (671 )   1,064  
Less:  Gains on investment securities
   recognized in net income
    11,142     (4,310 )   6,832     -     -     -  
Change in pension and postretirement
   benefit plan liability
    (86,869 )   33,601     (53,268 )   27,687     (10,709 )   16,978  
Other comprehensive income (loss)
  $ (108,861 ) $ 45,314   $ (63,547 ) $ (71,225 ) $ 24,624   $ (46,601 )

The gains on energy marketing and risk management assets/liabilities recognized in net income presented in the table above include the reclassification of gains on our cash flow hedges from accumulated other comprehensive income (loss) into earnings as discussed in Note D.



The table below shows the balance in accumulated other comprehensive income (loss) for the periods indicated.

   
Unrealized Gains (Losses) on Energy Marketing and Risk Management Assets/Liabilities
 
Unrealized
Holding
Gains (Losses) on
Investment
Securities
 
Pension and Postretirement Benefit Plan Obligations
 
Accumulated Other Comprehensive Income (Loss)
     
(Thousands of dollars)
 
December 31, 2006
  $
89,971
    $
12,614
    $
(63,053)
    $
39,532
 
Other comprehensive income (loss)
   
 (64,643)
     
 1,064
     
 16,978
     
 (46,601)
 
December 31, 2007
  $
25,328
    $
13,678
    $
(46,075)
    $
(7,069)
 
Other comprehensive income (loss)
   
 2,585
     
 (12,864)
     
 (53,268)
     
 (63,547)
 
December 31, 2008
  $
27,913
    $
814
    $
(99,343)
    $
(70,616)
 

G.           CAPITAL STOCK

Series A and B Convertible Preferred Stock - There are no shares of Series A or Series B currently outstanding.

Series C Preferred Stock -   Series C Preferred Stock (Series C) is designed to protect our shareholders from coercive or unfair takeover tactics.  If issued, holders of shares of Series C are entitled to receive, in preference to the holders of ONEOK Common Stock, quarterly dividends in an amount per share equal to the greater of $0.50 or, subject to adjustment, 100 times the aggregate per share amount of all cash dividends, and 100 times the aggregate per share amount (payable in kind) of all non-cash dividends.  No shares of Series C have been issued.

Common Stock - At December 31, 2008, we had approximately 175 million shares of authorized and unreserved common stock available for issuance.

Stock Repurchase Plan - On May 17, 2007, our Board of Directors authorized a stock buy back program to repurchase up to 7.5 million shares of our currently issued and outstanding common stock.  On June 28, 2007, we repurchased 7.5 million shares of our outstanding common stock under an accelerated share repurchase agreement with Bank of America, N.A. (Bank of America) at an initial price of $49.33 per share for a total of $370 million.  Bank of America borrowed 7.5 million of our shares from third parties and purchased shares in the open market to settle its short position.  Our repurchase was subject to a financial adjustment based on the volume-weighted average price, less a discount, of the shares subsequently repurchased by Bank of America over the course of the repurchase period.  The price adjustment could have been settled, at our option, in cash or in shares of our common stock.  In September 2007, the accelerated share repurchase agreement with Bank of America was settled, which resulted in Bank of America delivering an additional 186,402 shares of our common stock to us at no additional cost.  All shares under this accelerated repurchase agreement were recorded as treasury shares in our Consolidated Balance Sheets.  These transactions completed the plan approved by our Board of Directors and we have no remaining shares available for repurchase under our stock repurchase plan.

On August 7, 2006, under a previously authorized stock repurchase plan, we repurchased 7.5 million shares of our outstanding common stock under an accelerated share repurchase agreement with UBS Securities LLC (UBS) at an initial price of $37.52 per share for a total of $281.4 million.  These shares were recorded as treasury shares in our Consolidated Balance Sheets.  UBS borrowed 7.5 million of our shares from third parties and purchased shares in the open market to settle its short position.  Our repurchase was subject to a financial adjustment based on the volume-weighted average price, less a discount, of the shares subsequently repurchased by UBS over the course of the repurchase period.  The price adjustment could have been settled, at our option, in cash or in shares of our common stock.  In February 2007, the forward purchase contract with UBS was settled for a cash payment of $20.1 million, which was recorded in equity.

In accordance with EITF Issue No. 99-7, “Accounting for an Accelerated Share Repurchase Program,” the repurchases were accounted for as two separate transactions: (i) as shares of common stock acquired in a treasury stock transaction recorded on the acquisition date; and (ii) as a forward contract indexed to our common stock.  Additionally, we classified the forward contracts as equity under EITF Issue No. 00-19, “Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in, a Company’s Own Stock.”



Dividends - Quarterly dividends paid on our common stock for shareholders of record as of the close of business on January 31, 2008, April 30, 2008, July 31, 2008, and October 31, 2008, were $0.38 per share, $0.38 per share, $0.40 per share and $0.40 per share, respectively.  Additionally, a quarterly dividend of $0.40 per share was declared in January 2009, payable in the first quarter of 2009.

Equity Units - On February 16, 2006, we successfully settled our 16.1 million equity units to 19.5 million shares of our common stock.  Of this amount, 8.3 million shares were issued from treasury stock and approximately 11.2 million shares were newly issued.  Holders of the equity units received 1.2119 shares of our common stock for each equity unit they owned.  The number of shares that we issued for each stock purchase contract was determined based on our average closing price over the 20 trading day period ending on the third trading day prior to February 16, 2006.  With the settlement, we received $402.4 million in cash, which was used to pay down our short-term bridge financing agreement.

H.           CREDIT FACILITIES AND SHORT-TERM NOTES PAYABLE

ONEOK Credit Agreement -   In July 2006 and September 2008, ONEOK amended and restated its $1.2 billion credit agreement (ONEOK Credit Agreement).  The amended agreement includes revised pricing, an extension of the maturity date from 2009 to 2011, an option for additional extensions of the maturity date with the consent of the lenders, an option to request an increase in the commitments of the lenders of up to an additional $500 million and a change in certain sublimits.  The interest rates applicable to extensions of credit under this agreement are based, at ONEOK’s election, on either (i) the higher of prime or one-half of one percent above the Federal Funds Rate, which is the rate that banks charge each other for the overnight borrowing of funds; or (ii) the Eurodollar rate plus a set number of basis points based on ONEOK’s current long-term unsecured debt ratings.

Under the ONEOK Credit Agreement, ONEOK is required to comply with certain financial, operational and legal covenants.  Among other things, these requirements include:
·  
a $400 million sublimit for the issuance of standby letters of credit;
·  
a limitation on ONEOK’s stand-alone debt-to-capital ratio, which may not exceed 67.5 percent at the end of any calendar quarter;
·  
a requirement that ONEOK maintains the power to control the management and policies of ONEOK Partners; and
·  
a limit on new investments in master limited partnerships.

The ONEOK Credit Agreement also contains customary affirmative and negative covenants, including covenants relating to liens, investments, fundamental changes in our businesses, changes in the nature of ONEOK’s businesses, transactions with affiliates, the use of proceeds and a covenant that prevents ONEOK from restricting its subsidiaries’ ability to pay dividends.

ONEOK 364-Day Facility - In August 2008, ONEOK entered into a $400 million 364-day credit agreement (364-Day Facility).  The interest rate is based, at ONEOK’s election, on either (i) the higher of prime or one-half of one percent above the Federal Funds Rate; or (ii) the Eurodollar rate plus a set number of basis points based on ONEOK’s current long-term unsecured debt ratings by Moody’s and S&P.  The 364-Day Facility is being used as an additional back-up to ONEOK’s commercial paper program and for working capital, capital expenditures and other general corporate purposes.  The 364-Day Facility contains substantially similar affirmative and negative covenants as the ONEOK Credit Agreement.

The debt covenant calculations in the ONEOK Credit Agreement and the 364-Day Facility exclude the debt of ONEOK Partners.  Upon breach of any covenant by ONEOK, amounts outstanding under the ONEOK Credit Agreement or the 364-Day Facility may become immediately due and payable.  At December 31, 2008, ONEOK’s stand-alone debt-to-capital ratio was 58.2 percent and ONEOK was in compliance with all covenants under the ONEOK Credit Agreement and the ONEOK 364-Day Facility.

At December 31, 2008, ONEOK had no commercial paper outstanding, $1.4 billion in borrowings outstanding and $64.6 million in letters of credit issued under the ONEOK Credit Agreement, leaving $135.4 million of credit available under the ONEOK Credit Agreement and 364-Day Facility.  The ONEOK Credit Agreement and the 364-Day Facility also serve as a back-up to ONEOK’s commercial paper program.

The average interest rate on ONEOK’s short-term debt outstanding was 4.51 percent and 5.00 percent at December 31, 2008 and 2007, respectively.
 
 
At December 31, 2007, ONEOK had $102.6 million in commercial paper outstanding, no borrowings outstanding and $38.1 million in letters of credit issued under the ONEOK Credit Agreement, leaving $1.1 billion of credit available under the ONEOK Credit Agreement.  In addition, ONEOK had $20.6 million in other letters of credit issued at December 31, 2007.

ONEOK Partners Credit Agreement - In March 2007, ONEOK Partners amended and restated its revolving credit facility agreement (ONEOK Partners Credit Agreement), with several banks and other financial institutions and lenders in the following principal ways: (i) revised the pricing; (ii) extended the maturity by one year to March 2012; (iii) eliminated the interest coverage ratio covenant; (iv) increased the permitted ratio of indebtedness to EBITDA to 5 to 1 (from 4.75 to 1); (v) increased the swingline sub-facility commitments from $15 million to $50 million; and (vi) changed the permitted amount of subsidiary indebtedness from $35 million to 10 percent of ONEOK Partners’ consolidated indebtedness.  The interest rates applicable to extensions of credit under this agreement are based, at ONEOK Partners’ election, on either (i) the higher of prime or one-half of one percent above the Federal Funds Rate, which is the rate that banks charge each other for the overnight borrowing of funds; or (ii) the Eurodollar rate plus a set number of basis points, depending on ONEOK Partners’ current long-term unsecured debt ratings.

In July 2007, ONEOK Partners exercised the accordion feature in the ONEOK Partners Credit Agreement to increase the commitment amounts by $250 million to a total of $1.0 billion.

Under the ONEOK Partners Credit Agreement, ONEOK Partners is required to comply with certain financial, operational and legal covenants.  Among other things, these requirements include maintaining a ratio of indebtedness to adjusted EBITDA (EBITDA plus minority interest in income of consolidated subsidiaries, distributions received from investments and EBITDA related to any approved capital projects less equity earnings from investments and the equity portion of AFUDC) of no more than 5 to 1.  If ONEOK Partners consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of indebtedness to adjusted EBITDA will be increased to 5.5 to 1 for the three calendar quarters following the acquisition.  Upon breach of any covenant, discussed above, amounts outstanding under the ONEOK Partners Credit Agreement may become immediately due and payable.  At December 31, 2008, ONEOK Partners’ ratio of indebtedness to adjusted EBITDA was 4.1 to 1, and ONEOK Partners was in compliance with all covenants under the ONEOK Partners Credit Agreement.

The average interest rate of borrowings under the ONEOK Partners Credit Agreement was 4.22 percent and 5.40 percent at December 31, 2008 and 2007, respectively.  ONEOK Partners had $870 million and $100 million of borrowings outstanding and $130 million and $900 million available under the ONEOK Partners Credit Agreement at December 31, 2008 and 2007, respectively.

ONEOK Partners has an outstanding $25 million letter of credit issued by Royal Bank of Canada, which is used for counterparty credit support.

ONEOK Partners also has a $15 million Senior Unsecured Letter of Credit Facility and Reimbursement Agreement with Wells Fargo Bank, N.A., of which $12 million is being used, and an agreement with Royal Bank of Canada, pursuant to which a $12 million letter of credit was issued.  Both agreements are used to support various permits required by the KDHE for ONEOK Partners’ ongoing business in Kansas.



I.           LONG-TERM DEBT

The following table sets forth our long-term debt for the periods indicated.  All notes are senior unsecured obligations, ranking equally in right of payment with all of our existing and future unsecured senior indebtedness.


   
December 31,
   
December 31,
 
   
2008
   
2007
 
   
(Thousands of dollars)
 
ONEOK
           
        $402,500 at 5.51% due 2008
  $ -     $ 402,303  
$100,000 at 6.0% due 2009
    100,000       100,000  
$400,000 at 7.125% due 2011
    400,000       400,000  
$400,000 at 5.2% due 2015
    400,000       400,000  
$100,000 at 6.4% due 2019
    91,371       92,000  
$100,000 at 6.5% due 2028
    89,970       90,902  
$100,000 at 6.875% due 2028
    100,000       100,000  
$400,000 at 6.0% due 2035
    400,000       400,000  
Other
    2,712       2,958  
      1,584,053       1,988,163  
ONEOK Partners
               
$250,000 at 8.875% due 2010
    250,000       250,000  
$225,000 at 7.10% due 2011
    225,000       225,000  
$350,000 at 5.90% due 2012
    350,000       350,000  
$450,000 at 6.15% due 2016
    450,000       450,000  
$600,000 at 6.65% due 2036
    600,000       600,000  
$600,000 at 6.85% due 2037
    600,000       600,000  
      2,475,000       2,475,000  
                 
Guardian Pipeline
               
Average 7.85%, due 2022
    121,711       133,641  
                 
Total long-term notes payable
    4,180,764       4,596,804  
Unamortized portion of terminated
     swaps and fair value of hedged debt
    55,035       43,682  
Unamortized debt premium
    (5,023 )     (4,961 )
Current maturities
    (118,195 )     (420,479 )
Long-term debt
  $ 4,112,581     $ 4,215,046  

The aggregate maturities of long-term debt outstanding for the years 2009 through 2013 are shown below.
 
         
ONEOK
Guardian
   
   
ONEOK
 
  Partners  
Pipeline
 
Total
   
(Millions of dollars)
2009
  $
106.3
 
$            -
  $
11.9
 
 $   118.2
2010
  $
6.3
 
 $     250.0
  $
11.9
 
 $   268.2
2011
  $
406.3
 
 $     225.0
  $
11.9
 
 $   643.2
2012
  $
6.3
 
 $     350.0
  $
11.1
 
 $   367.4
2013
  $
6.2
 
$            -
  $
7.7
 
 $     13.9
                     

Additionally, $181.4 million of our debt is callable at par at our option from now until maturity, which is 2019 for $91.4 million and 2028 for $90.0 million.  Certain debt agreements have negative covenants that relate to liens and sale/leaseback transactions.


ONEOK Partners’ Debt Issuance -   In September 2007, ONEOK Partners completed an underwritten public offering of $600 million aggregate principal amount of 6.85 percent Senior Notes due 2037 (the 2037 Notes).  The 2037 Notes were issued under ONEOK Partners’ existing shelf registration statement filed with the SEC.

ONEOK Partners may redeem the 2037 Notes, in whole or in part, at any time prior to their maturity at a redemption price equal to the principal amount of the 2037 Notes, plus accrued and unpaid interest and a make-whole premium.  The redemption price will never be less than 100 percent of the principal amount of the 2037 Notes plus accrued and unpaid interest.  The 2037 Notes are senior unsecured obligations, ranking equally in right of payment with all of ONEOK Partners’ existing and future unsecured senior indebtedness, and effectively junior to all of the existing debt and other liabilities of its non-guarantor subsidiaries.  The 2037 Notes are non-recourse to ONEOK.

Debt Covenants - The terms of ONEOK’s long-term notes are governed by indentures containing covenants that include, among other provisions, limitations on ONEOK’s ability to place liens on its property or assets and its ability to sell and lease back its property.

We filed a new form of indenture in 2008.  The new indenture includes covenants that are similar to those contained in our prior indentures.  The new indenture does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series.

The indenture governing the 2037 Notes does not limit the aggregate principal amount of debt securities that may be issued and provides that debt securities may be issued from time to time in one or more additional series.  The indenture contains covenants including, among other provisions, limitations on ONEOK Partners’ ability to place liens on its property or assets and its ability to sell and lease back its property.

ONEOK Partners’ $250 million and $225 million senior notes, due 2010 and 2011, respectively, contain provisions that require ONEOK Partners to offer to repurchase the senior notes at par value if its Moody’s or S&P credit rating falls below investment grade (Baa3 for Moody’s or BBB- for S&P) and the investment grade rating is not reinstated within a period of 40 days.  Further, the indentures governing ONEOK Partners’ senior notes due 2010 and 2011 include an event of default upon acceleration of other indebtedness of $25 million or more and the indentures governing the senior notes due 2012, 2016, 2036 and 2037 include an event of default upon the acceleration of other indebtedness of $100 million or more that would be triggered by such an offer to repurchase.  Such an event of default would entitle the trustee or the holders of 25 percent in aggregate principal amount of the outstanding senior notes due 2010, 2011, 2012, 2016, 2036 and 2037 to declare those notes immediately due and payable in full.

Guardian Pipeline Senior Notes - These notes were issued under a master shelf agreement with certain financial institutions.  Principal payments are due quarterly through 2022.  Interest rates on the $121.7 million in notes outstanding at December 31, 2008, range from 7.61 percent to 8.27 percent, with an average rate of 7.85 percent.  Guardian Pipeline’s senior notes contain financial covenants that require the maintenance of a ratio of (i) EBITDAR (net income plus interest expense, income taxes, operating lease expense and depreciation and amortization) to fixed charges (interest expense plus operating lease expense) of not less than 1.5 to 1; and (ii) total indebtedness to EBITDAR of not greater than 5.75 to 1.  Upon any breach of these covenants, all amounts outstanding under the master shelf agreement may become due and payable immediately.  At December 31, 2008, Guardian Pipeline’s EBITDAR-to-fixed-charges ratio was 4.95 to 1, the ratio of total indebtedness to EBITDAR was 3.34 to 1, and Guardian Pipeline was in compliance with its financial covenants.

Other

We amortize premiums, discounts and expenses incurred in connection with the issuance of long-term debt consistent with the terms of the respective debt instrument.

J.           EMPLOYEE BENEFIT PLANS

Retirement and Other Postretirement Benefit Plans

Retirement Plans - We have defined benefit retirement plans covering certain full-time employees.  Nonbargaining unit employees hired after December 31, 2004, are not eligible for our defined benefit pension plan; however, they are covered by a defined contribution profit-sharing plan.  Certain officers and key employees are also eligible to participate in supplemental
 
 
retirement plans.  We generally fund pension costs at a level equal to the minimum amount required under the Employee Retirement Income Security Act of 1974.

Other Postretirement Benefit Plans - We sponsor welfare plans that provide postretirement medical and life insurance benefits to certain employees who retire with at least five years of service.  The postretirement medical plan is contributory based on hire date, age and years of service, with retiree contributions adjusted periodically, and contains other cost-sharing features such as deductibles and coinsurance.

Statement 158 - See Note A for a discussion of the impact of the adoption of Statement 158, including the change in our measurement date from September 30 to December 31.

Regulatory Treatment - The OCC, KCC, and regulatory authorities in Texas have approved the recovery of pension costs and other postretirement benefits costs through rates for Oklahoma Natural Gas, Kansas Gas Service and Texas Gas Service, respectively.  The costs recovered through rates are based on current funding requirements and the net periodic benefit cost for pension and postretirement costs.  Differences, if any, between the expense and the amount recovered through rates are reflected in earnings.

Our regulated entities have historically recovered pension and other postretirement benefit costs, as determined by Statement 87, “Employers’ Accounting for Pensions,” and Statement 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions,” respectively, through rates.  We believe it is probable that regulators will continue to include the net periodic pension and other postretirement benefit costs in our regulated entities’ cost of service.  Accordingly, we have recorded a regulatory asset for the minimum liability associated with our regulated entities’ pension and other postretirement benefit obligations that otherwise would have been recorded in accumulated other comprehensive income.

Obligations and Funded Status - The following tables set forth our pension and other postretirement benefit plans benefit obligations and fair value of plan assets for the periods indicated.  Due to the change in our measurement date as discussed in Note A, the changes in benefit obligation and plan assets shown in the following tables are for the 15-month period from October 1, 2007 through December 31, 2008.

   
Pension Benefits
   
Postretirement Benefits
 
   
December 31,
   
December 31,
 
   
2008
   
2007
   
2008
   
2007
 
Change in Benefit Obligation
(Thousands of dollars)
 
Benefit obligation, beginning of period
  $ 819,999     $ 832,980     $ 294,730     $ 271,510  
Service cost
    25,577       21,050       7,198       6,392  
Interest cost
    61,649       48,608       22,206       15,830  
Plan participants' contributions
    -       -       3,299       2,882  
Actuarial (gain) loss
    46,967       (32,697 )     (21,983 )     14,742  
Benefits paid
    (66,629 )     (49,942 )     (26,685 )     (16,626 )
Benefit obligation, end of period
  $ 887,563     $ 819,999     $ 278,765     $ 294,730  
                                 
Change in Plan Assets
                               
Fair value of plan assets, beginning of period
  $ 771,878     $ 710,377     $ 79,314     $ 68,440  
Actual return on plan assets
    (220,955 )     107,305       (17,644 )     5,214  
Employer contributions
    117,597       4,138       12,444       14,925  
Transfers in
    -       -       3,573       -  
Benefits paid
    (66,629 )     (49,942 )     -       -  
Fair value of assets, end of period
  $ 601,891     $ 771,878     $ 77,687     $ 88,579  
Balance at December 31
  $ (285,672 )   $ (48,121 )   $ (201,078 )   $ (206,151 )
                                 
Non-current assets
  $ -     $ 10,028     $ -     $ -  
Current liabilities
    (2,706 )     (2,497 )     -       -  
Non-current liabilities
    (282,966 )     (55,652 )     (201,078 )     (206,151 )
Balance at December 31
  $ (285,672 )   $ (48,121 )   $ (201,078 )   $ (206,151 )
 
 
The accumulated benefit obligation for our pension plans was $824.7 million and $759.2 million at December 31, 2008 and 2007, respectively.

There are no plan assets expected to be withdrawn and returned to us in 2009.

Components of Net Periodic Benefit Cost -   The following tables set forth the components of net periodic benefit cost for our pension and other postretirement benefit plans for the periods indicated.

   
Pension Benefits
 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
Components of Net Periodic Benefit Cost
(Thousands of dollars)
Service cost
  $ 20,165     $ 21,050     $ 20,980  
Interest cost
    49,801       48,608       43,425  
Expected return on plan assets
    (61,268 )     (58,154 )     (57,586 )
Amortization of unrecognized prior service cost
    1,551       1,486       1,511  
Amortization of net loss
    9,548       16,139       13,314  
Net periodic benefit cost
  $ 19,797     $ 29,129     $ 21,644  
 
   
Postretirement Benefits
 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
Components of Net Periodic Benefit Cost
 
(Thousands of dollars)
 
Service cost
  $ 5,675     $ 6,392     $ 6,332  
Interest cost
    17,899       15,830       14,156  
Expected return on plan assets
    (7,421 )     (6,389 )     (4,565 )
Amortization of unrecognized net asset at adoption
    3,189       3,189       3,189  
Amortization of unrecognized prior service cost
    (2,003 )     (2,277 )     (2,286 )
Amortization of net loss
    10,972       9,927       9,085  
Net periodic benefit cost
  $ 28,311     $ 26,672     $ 25,911  

Other Comprehensive Income (Loss) - The following table sets forth the amounts recognized in other comprehensive income (loss) for 2008 related to our pension benefits and postretirement benefits.

   
Pension Benefits
   
Postretirement Benefits
 
   
December 31, 2008
   
December 31, 2008
 
   
(Thousands of dollars)
 
Regulatory asset gain (loss)
  $ 252,747     $ 492  
Net gain (loss) arising during the period
    (343,274 )     (1,531 )
Amortization of regulatory asset
    (11,465 )     (12,911 )
Amortization of transition obligation
    -       3,986  
Amortization of prior service (cost) credit
    1,941       (2,504 )
Amortization of loss
    11,935       13,715  
Deferred income taxes
    34,417       (816 )
Total recognized in other comprehensive income (loss)
  $ (53,699 )   $ 431  



The table below sets forth the amounts in accumulated other comprehensive income (loss) that had not yet been recognized as components of net periodic benefit expense.

   
Pension Benefits
   
Postretirement Benefits
 
   
December 31,
   
December 31,
 
   
2008
   
2007
   
2008
   
2007
 
   
(Thousands of dollars)
 
Transition obligation
  $ -     $ -     $ (12,724 )   $ (16,711 )
Prior service credit (cost)
    (6,852 )     (8,791 )     8,384       10,888  
Accumulated gain (loss)
    (455,089 )     (123,750 )     (113,228 )     (125,412 )
Accumulated other comprehensive income (loss)
     before regulatory assets
    (461,941 )     (132,541 )     (117,568 )     (131,235 )
Regulatory asset for regulated entities
    331,882       90,600       85,619       98,038  
Accumulated other comprehensive income (loss)
     after regulatory assets
    (130,059 )     (41,941 )     (31,949 )     (33,197 )
Deferred income taxes
    50,307       16,222       12,358       12,841  
Accumulated other comprehensive income (loss),
     net of tax
  $ (79,752 )   $ (25,719 )   $ (19,591 )   $ (20,356 )

The following table sets forth the amounts recognized in either accumulated comprehensive income (loss) or regulatory assets expected to be recognized as components of net periodic benefit expense in the next fiscal year.

   
Pension
   
Postretirement
 
   
Benefits
   
Benefits
 
Amounts to be recognized in 2009
(Thousands of dollars)
Transition obligation
  $ -     $ 3,189  
Prior service credit (cost)
  $ 1,565     $ (2,003 )
Net loss
  $ 17,322     $ 9,660  

Actuarial Assumptions - The following table sets forth the weighted-average assumptions used to determine benefit obligations for the periods indicated.

   
Pension Benefits
 
Postretirement Benefits
   
December 31,
   
December 31,
 
   
2008
 
2007
   
2008
 
2007
 
Discount rate
 
6.25%
 
6.25%
   
6.25%
 
6.25%
 
Compensation increase rate
 
4.3% - 4.8%
 
3.5% - 4.5%
   
4.3% - 4.8%
 
3.5% - 4.0%
 

The following table sets forth the weighted-average assumptions used to determine net periodic benefit costs for the periods indicated.

   
Pension Benefits
 
Postretirement Benefits
   
December 31,
   
December 31,
 
   
2008
 
2007
   
2008
 
2007
 
Discount rate
 
6.25%
 
6.00%
   
6.25%
 
6.00%
 
Expected long-term return on plan assets
 
8.50%
 
8.75%
   
8.50%
 
8.75%
 
Compensation increase rate
 
3.5% - 4.5%
 
3.5% - 4.5%
   
3.5% - 4.0%
 
3.5% - 4.0%
 

We determine our overall expected long-term rate of return on plan assets assumption based on our review of historical returns and the economic growth models from our consultants.



Our discount rates for 2008 and 2007 are based on matching the amount and timing of the projected benefit payments to a spot-rate yield curve, which provides zero-coupon interest rates into the future.  The methodology for developing the yield curve includes selecting the bonds to be included (only bonds rated Aa by Moody’s but excluding callable bonds, bonds with less than a minimum issue size, yield “outliers” and various other filtering criteria to remove unsuitable bonds).  Once the bonds are selected, a best-fit regression curve to the bond data is determined, modeling yield to maturity as a function of years to maturity.  This coupon yield curve is converted to a spot-yield curve using the calculation technique that assumes the price of a coupon bond for a given maturity equals the present value of the underlying bond cash flows using zero-coupon spot rates.  Once the yield curve is developed, the projected cash flows for the plan for each year in the future are calculated.  These projected cash flows values are based on the most recent valuation.  Each annual cash flow of the plan obligations is discounted using the yield at the appropriate point on the curve, and then the single equivalent discount rate that would yield the same value for the cash flow is determined.

Health Care Cost Trend Rates -   The following table sets forth the assumed health care cost trend rates for the periods indicated.

     
2008
 
2007
Health care cost trend rate assumed for next year
 
5.0% - 9.0%
 
6.6% - 9.0%
Rate to which the cost trend rate is assumed
         
     to decline (the ultimate trend rate)
   
5.0%
 
5.0%
Year that the rate reaches the ultimate trend rate
   
2018
 
2012

Assumed health care cost trend rates have a significant effect on the amounts reported for our health care plans.  A one-percentage point change in assumed health care cost trend rates would have the following effects.

   
One-Percentage
   
One-Percentage
 
   
Point Increase
   
Point Decrease
 
   
(Thousands of dollars)
 
Effect on total of service and interest cost
  $ 1,989     $ (1,706 )
Effect on postretirement benefit obligation
  $ 19,585     $ (17,171 )

Plan Assets -   The following table sets forth our pension and postretirement benefit plan weighted-average asset allocations as of the measurement date.

 
Pension Benefits
   
Postretirement Benefits
 
 
Percentage of Plan Assets
   
Percentage of Plan Assets
 
Asset Category
 
2008
   
2007
   
2008
   
2007
 
Corporate bonds
    5 %     6 %     25 %     14 %
Insurance contracts
    13 %     11 %     -       -  
High yield corporate bonds
    9 %     10 %     -       -  
Large-cap value equities
    12 %     15 %     14 %     15 %
Large-cap growth equities
    14 %     18 %     17 %     22 %
Mid-cap equities
    9 %     13 %     6 %     8 %
Small-cap equities
    7 %     11 %     12 %     16 %
International equities
    12 %     16 %     10 %     13 %
Other (a)
    19 %     -       16 %     12 %
    Total
    100 %     100 %     100 %     100 %
(a) - Primarily money market funds
                         



Our investment strategy is to invest plan assets in accordance with sound investment practices that emphasize long-term fundamentals.  The goal of this strategy is to maximize investment returns while managing risk in order to meet the plan’s current and projected financial obligations.  The plan’s investments include a diverse blend of various US and international equities, investments in various classes of debt securities, insurance contracts and venture capital.  The target allocation for the assets of our pension plan is as follows.

Corporate bonds / insurance contracts
    20 %
High yield corporate bonds
    10 %
Large-cap value equities
    16 %
Large-cap growth equities
    16 %
Mid- and small-cap value equities
    10 %
Mid- and small-cap growth equities
    10 %
International equities
    15 %
Alternative investments
    2 %
Venture capital
    1 %
   Total
    100 %

As part of our risk management for the plans, minimums and maximums have been set for each of the asset classes listed above.  All investment managers for the plan are subject to certain restrictions on the securities they purchase and, with the exception of indexing purposes, are prohibited from owning our stock.

Contributions -   For 2008, $113.7 million and $8.0 million of contributions were made to our pension plan and other postretirement benefit plan, respectively.  We presently anticipate our total 2009 contributions will be $31.2 million for the pension plan and $11.4 million for the other postretirement benefit plan.

Pension and Other Postretirement Benefit Payments - Benefit payments for our pension and other postretirement benefit plans for the 15-month period ending December 31, 2008, were $66.6 million and $26.7 million, respectively.  The following table sets forth the pension benefits and postretirement benefit payments expected to be paid in 2009-2018.
 
 
Pension Benefits
Postretirement Benefits
Benefits to be paid in:
(Thousands of dollars)
2009
 $        52,958
    $
16,155
 
2010
 $        54,317
    $
17,253
 
2011
 $        55,882
    $
18,300
 
2012
 $        58,275
    $
19,238
 
2013
 $        60,136
    $
19,354
 
2014 through 2018
 $      339,437
    $
113,661
 

The expected benefits to be paid are based on the same assumptions used to measure our benefit obligation at December 31, 2008, and include estimated future employee service.

Other Employee Benefit Plans

Thrift Plan - We have a Thrift Plan covering all full-time employees.  Employee contributions are discretionary.  We match 100 percent of employee contributions up to 6 percent of each participant’s eligible compensation, subject to certain limits.  Our contributions made to the plan were $14.7 million, $13.2 million and $12.8 million in 2008, 2007 and 2006, respectively.

Profit-Sharing Plan - We have a profit-sharing plan for all nonbargaining unit employees hired after December 31, 2004.  Nonbargaining unit employees who were employed prior to January 1, 2005, were given a one-time opportunity to make an irrevocable election to participate in the profit-sharing plan and not accrue any additional benefits under our defined benefit pension plan after December 31, 2004.  We plan to make a contribution to the profit-sharing plan each quarter equal to 1 percent of each participant’s eligible compensation during the quarter.  Additional discretionary employer contributions may be made at the end of each year.  Employee contributions are not allowed under the plan.  Our contributions made to the plan were $3.2 million, $2.7 million and $1.6 million in 2008, 2007 and 2006, respectively.
 
 
Employee Deferred Compensation Plan -   The ONEOK, Inc. 2005 Nonqualified Deferred Compensation Plan provides select employees, as approved by our Board of Directors, with the option to defer portions of their compensation and provides nonqualified deferred compensation benefits that are not available due to limitations on employer and employee contributions to qualified defined contribution plans under the federal tax laws.  Our contributions made to the plan were not material in 2008, 2007 and 2006.

K.           COMMITMENTS AND CONTINGENCIES

Operating Leases - In July 2007, ONEOK Leasing Company, our subsidiary, gave notice of its intent to exercise its option to purchase ONEOK Plaza on or before the end of the current lease term set to expire on September 30, 2009.  In March 2008, ONEOK Leasing Company purchased ONEOK Plaza for a total purchase price of approximately $48 million, which included $17.1 million for the present value of the remaining lease payments and $30.9 million for the base purchase price.

We lease excess office space in ONEOK Plaza.  We received rental revenue of $2.6 million in 2008 and $2.9 million in 2007 and 2006.  Estimated minimum future rental payments to be received under existing contracts for subleases are $1.9 million in 2009, $0.8 million in 2010 and $0.7 million in 2011.

Future minimum lease payments under non-cancelable operating leases on a gas processing plant, storage contracts, office space, pipeline equipment, rights-of-way and vehicles are shown in the table below.

     
ONEOK
ONEOK Partners
Total
     
(Millions of dollars)
 
2009
 
 $  88.8
 $  18.4
 $  107.2
 
2010
 
 $  55.9
 $  16.0
 $    71.9
 
2011
 
 $  61.2
 $  15.5
 $    76.7
 
2012
 
 $  32.9
 $    8.8
 $    41.7
 
2013
 
 $  25.4
 $    2.1
 $    27.5

The amounts in the ONEOK column above include the following minimum lease payments relating to the lease of a gas processing plant for $24.0 million in 2009, $24.2 million in 2010, and $30.6 million in 2011.  We acquired the lease in a business combination and recorded a liability for uneconomic lease terms.  The liability is accreted to rent expense in the amount of $13.0 million per year over the term of the lease; however, the cash outflow under the lease remains the same.  The amounts in the ONEOK Partners column above exclude intercompany payments relating to the lease of a gas processing plant.

Environmental Liabilities - We are subject to multiple environmental, historical and wildlife preservation laws and regulations affecting many aspects of our present and future operations.  Regulated activities include those involving air emissions, stormwater and wastewater discharges, handling and disposal of solid and hazardous wastes, hazardous materials transportation, and pipeline and facility construction.  These laws and regulations require us to obtain and comply with a wide variety of environmental clearances, registrations, licenses, permits and other approvals.  Failure to comply with these laws, regulations, permits and licenses may expose us to fines, penalties and/or interruptions in our operations that could be material to our results of operations.  If a leak or spill of hazardous substances or petroleum products occurs from our lines or facilities, in the process of transporting natural gas, NGLs, or refined products, or at any facility that we own, operate or otherwise use, we could be held jointly and severally liable for all resulting liabilities, including investigation and clean-up costs, which could materially affect our results of operations and cash flows.  In addition, emission controls required under the federal Clean Air Act and other similar federal and state laws could require unexpected capital expenditures at our facilities.  We cannot assure that existing environmental regulations will not be revised or that new regulations will not be adopted or become applicable to us.  Revised or additional regulations that result in increased compliance costs or additional operating restrictions, particularly if those costs are not fully recoverable from customers, could have a material adverse effect on our business, financial condition and results of operations.

We own or retain legal responsibility for the environmental conditions at 12 former manufactured gas sites in Kansas.  These sites contain potentially harmful materials that are subject to control or remediation under various environmental laws and regulations.  A consent agreement with the KDHE presently governs all work at these sites.  The terms of the consent agreement allow us to investigate these sites and set remediation activities based upon the results of the investigations and
 
 
risk analysis.  Remediation typically involves the management of contaminated soils and may involve removal of structures and monitoring and/or remediation of groundwater.

Of the 12 sites, we have commenced soil remediation on 11 sites.  Regulatory closure has been achieved at two locations, and we have completed or are near completion of soil remediation at nine sites.  We have begun site assessment at the remaining site where no active remediation has occurred.

To date, we have incurred remediation costs of $7.8 million and have accrued an additional $4.2 million related to the sites where soil remediation has yet to be completed.  These estimates are recorded on an undiscounted basis.  For the site that is currently in the assessment phase, we have completed some analysis but are unable at this point to accurately estimate aggregate costs that may be required to satisfy our remedial obligations at this site.  Until the site assessment is complete and the KDHE approves the remediation plan, we will not have complete information available to us to accurately estimate remediation costs.

The costs associated with these sites do not include other potential expenses that might be incurred, such as ongoing and additional water monitoring and remediation, unasserted property damage claims, personal injury or natural resource claims, unbudgeted legal expenses or other costs for which we may be held liable but with respect to which we cannot reasonably estimate an amount.  As of this date, we have no knowledge of any of these types of claims.  The foregoing estimates do not consider potential insurance recoveries, recoveries through rates or recoveries from unaffiliated parties, to which we may be entitled.  We have filed claims with our insurance carriers relating to these sites, and we have recovered a portion of our costs incurred to date.  We have not recorded any amounts for potential insurance recoveries or recoveries from unaffiliated parties, and we are not recovering any environmental amounts in rates.  As more information related to the site investigations and remediation activities becomes available, and to the extent such amounts are expected to exceed our current estimates, additional expenses could be recorded.  Such amounts could be material to our results of operations and cash flows depending on the remediation and number of years over which the remediation is required to be completed.

Our expenditures for environmental evaluation, mitigation and remediation to date have not been significant in relation to our results of operations, and there were no material effects upon earnings during 2008, 2007 or 2006 related to compliance with environmental regulations.

Legal Proceedings - We are a party to various litigation matters and claims that are in the normal course of our operations.  While the results of litigation and claims cannot be predicted with certainty, we believe the final outcome of such matters will not have a material adverse effect on our consolidated results of operations, financial position or liquidity.

FERC Matter - As a result of a transaction that was brought to the attention of one of our affiliates by a third party, we conducted an internal review of transactions that may have violated FERC natural gas capacity release rules or related rules and determined that there were transactions that should be disclosed to the FERC.  We notified the FERC of this review and filed a report with the FERC regarding these transactions in March 2008.  We cooperated fully with the FERC in its investigation of this matter and have taken steps to better ensure that current and future transactions comply with applicable FERC regulations by implementing a compliance plan dealing with capacity release.  We entered into a global settlement with the FERC to resolve this matter and other FERC enforcement matters, which was approved by the FERC on January 15, 2009.  The global settlement provides for a total civil penalty of $4.5 million and approximately $2.2 million in disgorgement of profits and interest, of which $1.7 million of the civil penalty was allocated to ONEOK Partners.  The amounts were recorded as a liability on our Consolidated Balance Sheet as of December 31, 2008.  We made the required payments in January 2009.



L.           INCOME TAXES

The following table sets forth our provisions for income taxes for the periods indicated.

 
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
Current income taxes
(Thousands of dollars)
 
Federal
  $ 18,833     $ 100,517     $ 69,698  
State
    10,047       19,063       10,312  
Total current income taxes from continuing operations
    28,880       119,580       80,010  
Deferred income taxes
                       
Federal
    143,807       56,887       96,464  
State
    21,384       8,130       17,290  
Total deferred income taxes from continuing operations
    165,191       65,017       113,754  
                         
Total provision for income taxes before discontinued operations
    194,071       184,597       193,764  
Discontinued operations
    -       -       (232 )
Total provision for income taxes
  $ 194,071     $ 184,597     $ 193,532  

The following table is a reconciliation of our income tax expense for the periods indicated.

   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
   
(Thousands of dollars)
 
Pretax income from continuing operations
  $ 505,980     $ 489,518     $ 500,441  
Federal statutory income tax rate
    35 %     35 %     35 %
Provision for federal income taxes
    177,093       171,331       175,154  
Amortization of distribution property investment tax credit
    (455 )     (505 )     (525 )
State income taxes, net of federal tax benefit
    20,431       17,676       18,809  
Other, net
    (2,998 )     (3,905 )     326  
   Income tax expense
  $ 194,071     $ 184,597     $ 193,764  

The following table sets forth the tax effects of temporary differences that gave rise to significant portions of the deferred tax assets and liabilities for the periods indicated.
 
   
December 31,
 
   
2008
   
2007
 
Deferred tax assets
 
(Thousands of dollars)
 
Employee benefits and other accrued liabilities
  $ 161,947     $ 134,056  
Net operating loss carryforward
    4,226       4,715  
Other comprehensive income
    43,747       -  
Other
    23,051       27,374  
Total deferred tax assets
    232,971       166,145  
                 
Deferred tax liabilities
               
Excess of tax over book depreciation and depletion
    372,123       344,601  
Purchased gas adjustment
    20,047       9,015  
Investment in joint ventures
    564,234       490,093  
Regulatory assets
    180,037       115,689  
Other comprehensive income
    -       1,567  
Other
    746       2,720  
Total deferred tax liabilities
    1,137,187       963,685  
    Net deferred tax liabilities
  $ 904,216     $ 797,540  


At December 31, 2008, ONEOK Partners had approximately $4.2 million of tax benefits available related to net operating loss carryforwards, which will expire between the years 2022 and 2027.  We believe that it is more likely than not that the tax benefits of the net operating loss carryforwards will be utilized prior to their expiration; therefore, no valuation allowance is necessary.

We had income taxes receivable of approximately $77.1 million and $13.2 million at December 31, 2008 and 2007, respectively.

M.           SEGMENTS

Segment Descriptions - We have divided our operations into four reportable business segments based on similarities in economic characteristics, products and services, types of customers, methods of distribution and regulatory environment.  These segments are as follows: (i) our ONEOK Partners segment gathers, processes, transports, stores and sells natural gas and gathers, treats, fractionates, stores, distributes and markets NGLs; (ii) our Distribution segment delivers natural gas to residential, commercial and industrial customers, and transports natural gas; (iii) our Energy Services segment markets natural gas to wholesale and retail customers; and (iv) our Other segment primarily consists of the operating and leasing operations of our headquarters building and a related parking facility.  Our Distribution segment is comprised of regulated public utilities, and portions of our ONEOK Partners segment are also regulated.

Accounting Policies - The accounting policies of the segments are described in Note A.  Intersegment sales are recorded on the same basis as sales to unaffiliated customers.  Overhead costs relating to a reportable segment have been allocated for the purpose of calculating operating income.

Customers - The primary customers for our ONEOK Partners segment include major and independent oil and gas production companies, natural gas gathering and processing companies, petrochemical, refining and NGL marketing companies, LDCs, power generating companies, natural gas marketing companies, NGL gathering companies and propane distributors.  Our Distribution segment provides natural gas to residential, commercial, industrial, wholesale, public authority and transportation customers.  Our Energy Services segment buys natural gas from producers and other marketing companies and sells natural gas to LDCs, municipalities, producers, large industrials, power generators, retail aggregators and other marketing companies, as well as residential and small commercial/industrial companies.

In 2008, 2007 and 2006, we had no single external customer from which we received 10 percent or more of our consolidated gross revenues.

Operating Segment Information - The following tables set forth certain selected financial information for our operating segments for the periods indicated.

Year Ended December 31, 2008
 
ONEOK
Partners (a)
   
Distribution (b)
   
Energy
Services
   
Other and Eliminations
   
Total
 
   
(Thousands of dollars)
 
Sales to unaffiliated customers
  $ 6,975,320     $ 2,177,615     $ 7,001,296     $ 3,202     $ 16,157,433  
Intersegment revenues
    744,886       7       584,507       (1,329,400 )     -  
Total revenues
  $ 7,720,206     $ 2,177,622     $ 7,585,803     $ (1,326,198 )   $ 16,157,433  
                                         
Net margin
  $ 1,140,659     $ 680,971     $ 110,716     $ 3,181     $ 1,935,527  
Operating costs
    371,797       375,328       35,593       (5,806 )     776,912  
Depreciation and amortization
    124,765       116,782       921       1,459       243,927  
Gain or (loss) on sale of assets
    713       (21 )     1,500       124       2,316  
Operating income
  $ 644,810     $ 188,840     $ 75,702     $ 7,652     $ 917,004  
                                         
Equity earnings from
     investments
  $ 101,432     $ -     $ -     $ -     $ 101,432  
Investments in unconsolidated
     affiliates
  $ 755,492     $ -     $ -     $ -     $ 755,492  
Minority interests in
     consolidated subsidiaries
  $ 5,941     $ -     $ -     $ 1,073,428     $ 1,079,369  
Total assets
  $ 7,254,272     $ 3,063,374     $ 1,752,256     $ 1,056,160     $ 13,126,062  
Capital expenditures
  $ 1,253,853     $ 169,049     $ 62     $ 50,172     $ 1,473,136  
(a) - Our ONEOK Partners segment has regulated and non-regulated operations. Our ONEOK Partners segment's regulated operations had revenues of $439.3 million, net margin of $334.1 million and operating income of $158.8 million.
 
(b) - All of our Distribution segment's operations are regulated.
 


Year Ended December 31, 2007
 
ONEOK
Partners (a)
   
Distribution (b)
   
Energy
Services
   
Other and Eliminations
   
Total
 
   
(Thousands of dollars)
 
Sales to unaffiliated customers
  $ 5,204,794     $ 2,099,056     $ 6,170,084     $ 3,480     $ 13,477,414  
Intersegment revenues
    626,764       7       459,319       (1,086,090 )     -  
Total revenues
  $ 5,831,558     $ 2,099,063     $ 6,629,403     $ (1,082,610 )   $ 13,477,414  
                                         
Net margin
  $ 895,893     $ 663,648     $ 247,402     $ 3,165     $ 1,810,108  
Operating costs
    337,356       377,778       39,920       6,456       761,510  
Depreciation and amortization
    113,704       111,615       2,147       498       227,964  
Gain or (loss) on sale of assets
    1,950       (56 )     -       15       1,909  
Operating income
  $ 446,783     $ 174,199     $ 205,335     $ (3,774 )   $ 822,543  
                                         
Equity earnings from
     investments
  $ 89,908     $ -     $ -     $ -     $ 89,908  
Investments in unconsolidated
     affiliates
  $ 756,260     $ -     $ -     $ -     $ 756,260  
Minority interests in
     consolidated subsidiaries
  $ 5,802     $ -     $ -     $ 796,162     $ 801,964  
Total assets
  $ 6,112,065     $ 3,045,249     $ 1,549,012     $ 355,708     $ 11,062,034  
Capital expenditures
  $ 709,858     $ 162,044     $ 158     $ 11,643     $ 883,703  
(a) - Our ONEOK Partners segment has regulated and non-regulated operations. Our ONEOK Partners segment's regulated operations had revenues of $344.3 million, net margin of $273.7 million and operating income of $122.4 million.
 
(b) - All of our Distribution segment's operations are regulated.
 
 
Year Ended December 31, 2006
 
ONEOK
Partners (a)
   
Distribution (b)
   
Energy
Services
   
Other and Eliminations
   
Total
 
   
(Thousands of dollars)
 
Sales to unaffiliated customers
  $ 4,142,546     $ 1,958,192     $ 5,846,258     $ (26,670 )   $ 11,920,326  
Intersegment revenues
    595,702       7       489,549       (1,085,258 )     -  
Total revenues
  $ 4,738,248     $ 1,958,199     $ 6,335,807     $ (1,111,928 )   $ 11,920,326  
                                         
Net margin
  $ 843,548     $ 599,797     $ 273,818     $ 4,821     $ 1,721,984  
Operating costs
    325,774       371,460       42,464       1,069       740,767  
Depreciation and amortization
    122,045       110,858       2,149       491       235,543  
Gain on sale of assets
    115,483       18       -       1,027       116,528  
Operating income
  $ 511,212     $ 117,497     $ 229,205     $ 4,288     $ 862,202  
                                         
Equity earnings from
     investments
  $ 95,883     $ -     $ -     $ -     $ 95,883  
Investments in unconsolidated
     affiliates
  $ 748,879     $ -     $ -     $ -     $ 748,879  
Minority interests in
     consolidated subsidiaries
  $ 5,606     $ -     $ -     $ 795,039     $ 800,645  
Total assets
  $ 4,921,717     $ 2,940,514     $ 2,023,663     $ 505,188     $ 10,391,082  
Capital expenditures
  $ 201,746     $ 159,026     $ -     $ 15,534     $ 376,306  
(a) - Our ONEOK Partners segment has regulated and non-regulated operations. Our ONEOK Partners segment's regulated operations had revenues of $335.9 million, net margin of $261.8 million and operating income of $240.1 million, including $113.9 million from a gain on sale of assets, for the year ended December 31, 2006.
 
(b) - All of our Distribution segment's operations are regulated.
 



N.           STOCK-BASED COMPENSATION

Equity Compensation Plan

The ONEOK, Inc. Equity Compensation Plan provides for the granting of stock-based compensation, including incentive stock options, non-statutory stock options, stock bonus awards, restricted stock awards, restricted stock unit awards, performance stock awards and performance unit awards to eligible employees and the granting of stock awards to non-employee directors.  We have reserved a total of approximately 5.0 million shares of common stock for issuance under the plan.  In December 2008, we amended the Equity Compensation Plan to allow for the deferral of awards granted in stock or cash, in accordance with Internal Revenue Code section 409A requirements.  This deferral option is applicable for certain awards granted in 2006 and later, and vesting after 2008.

Restricted Stock Incentive Units - Restricted stock incentive units may be granted to key employees with ownership of the common stock underlying the incentive unit vesting over a period determined by the Committee.  Awards granted to date vest over a three-year period.  Awards granted in 2008, 2007 and 2006 entitle the grantee to receive shares of our common stock.  Awards granted in 2005 entitled the grantee to receive two-thirds of the grant in our common stock (equity awards) and one-third of the grant in cash (liability awards).  The equity awards are measured at fair value as if they were vested and issued on the grant date, reduced by expected dividend payments and adjusted for estimated forfeitures.   The portion of the grants that are settled in cash are classified as liability awards with fair value based on the fair market value of our common stock, reduced by expected dividend payments and adjusted for estimated forfeitures, at each reporting date.  No dividends are paid on the restricted stock incentive units.  Compensation expense is recognized on a straight-line basis over the vesting period of the award.

Performance Unit Awards -   Performance unit awards may be granted to key employees.  The shares of our common stock underlying the performance units vest at the expiration of a period determined by the Committee if certain performance criteria are met by us.  Performance units granted to date vest at the expiration of a three-year period.  Upon vesting, a holder of performance units is entitled to receive a number of shares of our common stock equal to a percentage (0 percent to 200 percent) of the performance units granted based on our total shareholder return over the vesting period, compared with the total shareholder return of a peer group of other energy companies over the same period.  Compensation expense is recognized on a straight-line basis over the period of the award.

If paid, the performance unit awards granted in 2008, 2007 and 2006 entitle the grantee to receive the grant in shares of our common stock.  Under Statement 123R, our 2008, 2007 and 2006 performance unit awards are equity awards with a market-based condition, which results in the compensation cost for these awards being recognized over the requisite service period, provided that the requisite service period is fulfilled, regardless of when, if ever, the market condition is satisfied.  The fair value of these performance units was estimated on the grant date based on a Monte Carlo model.   The compensation expense on these awards will only be adjusted for changes in forfeitures.

The performance unit awards granted in 2005 entitled the grantee to receive two-thirds of the grant in shares of our common stock (equity awards) and one-third of the grant in cash (liability awards).  The fair values of these performance units that were classified as equity awards were calculated as of the date of grant were not adjusted upon adoption of Statement 123R.  The fair values of the one-third liability portion of the performance units were estimated at each reporting date based on a Monte Carlo model.

Long-Term Incentive Plan

The ONEOK, Inc. Long-Term Incentive Plan (the LTIP) provides for the granting of stock awards similar to those described above with respect to the Equity Compensation Plan.  We have reserved a total of approximately 7.8 million shares of common stock for issuance under the plan.  The maximum number of shares for which options or other awards may be granted to any employee during any year is 300,000.

Options - Stock options may be granted that are not exercisable until a fixed future date or in installments.  Options issued to date become void upon voluntary termination of employment other than retirement.  In the event of retirement or involuntary termination, the optionee may exercise the option within a period determined by the Executive Compensation Committee (the Committee) and stated in the option.  In the event of death, the option may be exercised by the personal representative of the optionee within a period to be determined by the Committee and stated in the option.  A portion of the options issued to date
 
 
can be exercised after one year from grant date and an option must be exercised no later than 10 years after grant date.  Effective January 1, 2007, we eliminated the restored option feature for outstanding stock option grants.

Stock Compensation Plan for Non-Employee Directors

The ONEOK, Inc. Stock Compensation Plan for Non-Employee Directors (the DSCP) provides for the granting of stock options, stock bonus awards, including performance unit awards, restricted stock awards and restricted stock unit awards.  Under the DSCP, these awards may be granted by the Committee at any time, until grants have been made for all shares authorized under the DSCP.  We have reserved a total of 700,000 shares of common stock for issuance under the DSCP.  The maximum number of shares of common stock which can be issued to a participant under the DSCP during any year is 20,000.  No performance unit awards or restricted stock awards have been made to non-employee directors under the DSCP.

Options - Options may be granted to non-employee directors on the same terms as those granted under the LTIP.

General

Effective January 1, 2006, we adopted Statement 123R.  See Note A for additional information.  For all awards outstanding, we used a forfeiture rate ranging from zero percent to 13 percent based on historical forfeitures under our share-based payment plans.  We use a combination of issuances from treasury stock and repurchases in the open market to satisfy our share-based payment obligations.

Compensation cost expensed for our share-based payment plans described below was $13.1 million, $12.0 million and $17.6 million 2008, 2007 and 2006, respectively, which is net of $8.3 million, $7.5 million and $11.2 million of tax benefits, respectively.  No compensation cost was capitalized for 2008, 2007 and 2006.

Cash received from the exercise of awards under all share-based payment arrangements was $3.8 million and $7.4 million for 2008 and 2007, respectively.  The actual tax benefit realized for the anticipated tax deductions of the exercise of share-based payment arrangements totaled $1.4 million and $4.6 million for 2008 and 2007, respectively.  No cash was used to settle the equity portion of the restricted stock unit and performance unit awards granted under share-based payment arrangements.

Stock Option Activity

The following table sets forth the stock option activity for employees and non-employee directors for the periods indicated.

   
Number of
   
Weighted
 
   
Shares
   
Average Price
 
Outstanding December 31, 2007
    953,146     $ 24.69  
Exercised
    (176,215 )   $ 25.72  
Expired
    (2,625 )   $ 28.69  
Outstanding December 31, 2008
    774,306     $ 24.44  
                 
Exercisable December 31, 2008
    774,306     $ 24.44  

The aggregate intrinsic value in the table below represents the total pre-tax intrinsic value, based on our year-end closing stock price of $29.12, that would have been received by the option holders had all option holders exercised their options as of December 31, 2008.

     
Stock Options Outstanding and Exercisable
 
           
Weighted
         
Aggregate
 
           
Average
   
Weighted
   
Intrinsic
 
Range of
   
Number
   
Remaining
   
Average
   
Value
 
Exercise Prices
   
of Awards
   
Life (yrs)
   
Exercise Price
   
(in 000's)
 
$14.58 to $21.87
   
376,485
   
3.04
    $
16.98
    $ 4,571  
$21.88 to $32.82
   
179,666
   
1.86
    $
24.69
    $ 796  
$32.83 to $43.67
   
218,155
   
2.15
    $
37.11
    $ -  
 
 
The fair value of each restored option was estimated on the date of grant using the Black-Scholes model and the assumptions in the table below.

   
December 31, 2006
 
Volatility (a)
 
15.43% to 25.23%
 
Dividend Yield
 
3.24% to 4.00%
 
Risk-free Interest Rate
 
4.39% to 5.18%
 
(a) - Volatility was based on historical volatility over twelve months
        using daily stock price observations.

The weighted-average period of outstanding options is 2.5 years.  As of December 31, 2008, all stock options were fully vested and expensed.  The following table sets forth various statistics relating to our stock option activity.

   
December 31, 2008
   
December 31, 2007
   
December 31, 2006
 
Weighted-average grant date fair value of options restored (per share)
 
(a)
   
(a)
    $ 5.57  
Intrinsic value of options exercised (thousands of dollars)
  $ 3,652     $ 12,129     $ 10,246  
Fair value of options granted (thousands of dollars)
 
(a)
   
(a)
    $ 1,990  
(a) - Due to our elimination of the restored option feature effective January 1, 2007, no grants were restored in 2007 or 2008.
 
 
Restricted Stock Unit Activity

The total fair value of shares vested during 2008 was $5.9 million.  As of December 31, 2008, there was $5.5 million of total unrecognized compensation cost related to our nonvested restricted stock unit awards, which is expected to be recognized over a weighted-average period of 1.5 years.  The following tables set forth activity and various statistics for the equity portion of the restricted stock unit awards.

   
Number of
   
Weighted
 
   
Shares
   
Average Price
 
Nonvested December 31, 2007
    461,627     $ 31.56  
Granted
    53,550     $ 47.44  
Released to participants
    (86,076 )   $ 25.34  
Forfeited
    (1,969 )   $ 38.16  
Nonvested December 31, 2008
    427,132     $ 34.78  
 
   
December 31, 2008
   
December 31, 2007
   
December 31, 2006
 
Weighted-average grant date fair value (per share)
  $ 43.22     $ 36.82     $ 25.98  
Fair value of shares granted (thousands of dollars)
  $ 2,314     $ 9,733     $ 3,761  

The following table sets forth activity for the liability portion of the restricted stock unit awards.

   
Number of
   
Weighted
 
   
Shares
   
Average Price
 
Nonvested December 31, 2007
    40,583     $ 25.07  
Released to participants
    (40,583 )   $ 25.19  
Forfeited
    -     $ -  
Nonvested December 31, 2008
    -     $ -  

Performance Unit Activity

The total fair value of shares vested during 2008 was $14.9 million.  As of December 31, 2008, there was $14.5 million of total unrecognized compensation cost related to the nonvested performance unit awards, which is expected to be recognized
 
 
over a weighted-average period of 1.1 years.  The following tables set forth activity and various statistics related to the performance unit equity awards and the assumptions used in the valuations of the 2008, 2007 and 2006 grants at the grant date.

   
Number of
   
Weighted
 
   
Units
   
Average Price
 
Nonvested December 31, 2007
    936,916     $ 29.63  
Granted
    387,125     $ 47.44  
Released to participants (a)
    (211,517 )   $ 25.48  
Forfeited
    (20,975 )   $ 38.32  
Nonvested December 31,  2008
    1,091,549     $ 36.58  
(a) - Performance awards granted in 2005 and released in 2008 were adjusted with
 a 150 percent performance factor; for the equity awards, this resulted in an
 additional 105,760 shares released to participants.
 

   
2008
   
2007
 
2006
Volatility (a)
 
22.50%
   
20.30%
 
18.80%
Dividend Yield
 
3.20%
   
3.79%
 
3.70%
Risk-free Interest Rate
 
2.46%
   
4.80%
 
4.32%
(a) - Volatility was based on historical volatility over three years using daily stock price observations.
 
   
December 31, 2008
   
December 31, 2007
   
December 31, 2006
 
Weighted-average grant date fair value (per share)
  $ 43.88     $ 37.58     $ 25.98  
Fair value of shares granted (thousands of dollars)
  $ 16,987     $ 12,366     $ 12,444  

The following tables set forth activity for the performance unit liability awards and the assumptions used in the valuations at the end of each period indicated.

   
Number of
   
Weighted
 
   
Units
   
Average Price
 
Nonvested December 31, 2007
    106,139     $ 25.48  
Released to participants (a)
    (105,758 )   $ 25.48  
Forfeited
    (381 )   $ 26.57  
Nonvested December 31, 2008
    -     $ -  
(a) - Performance awards granted in 2005 and released in 2008 were adjusted with
 a 150 percent performance factor; for the liability awards, this resulted in an
 additional 52,880 liability units released to participants.
 
 
   
2008
   
2007
 
2006
Volatility (a)
 
(b)
   
21.80%
 
20.30%
Dividend Yield
 
(b)
   
3.05%
 
3.62%
Risk-free Interest Rate
 
(b)
   
3.07%
 
4.74%
(a) - Volatility was based on historical volatility over three years using daily stock price observations.
(b) - Nonvested balance at December 31, 2008 was zero.




Employee Stock Purchase Plan

We have reserved a total of 4.8 million shares of common stock for issuance under our ONEOK, Inc. Employee Stock Purchase Plan (the ESPP).  Subject to certain exclusions, all full-time employees are eligible to participate in the ESPP.  Employees can choose to have up to 10 percent of their annual base pay withheld to purchase our common stock, subject to terms and limitations of the plan.  The Committee may allow contributions to be made by other means, provided that in no event will contributions from all means exceed 10 percent of the employee’s annual base pay.  The purchase price of the stock is 85 percent of the lower of its grant date or exercise date market price.  Approximately 52 percent, 59 percent and 63 percent of employees participated in the plan in 2008, 2007 and 2006, respectively.  Under the plan, we sold 297,864 shares at $24.41 in 2008, 217,369 shares at $36.85 per share in 2007, and 340,364 shares at $22.57 per share in 2006.

Employee Stock Award Program

Under our Employee Stock Award Program, we issued, for no consideration, to all eligible employees (all full-time employees and employees on short-term disability) one share of our common stock when the per-share closing price of our common stock on the NYSE was for the first time at or above $26 per share, and we have issued and will continue to issue, for no consideration, one additional share of our common stock to all eligible employees when the closing price on the NYSE is for the first time at or above each one dollar increment above $26 per share.  We have reserved a total of 300,000 shares of common stock for issuance under this program.

There were no shares issued to employees under this program in 2008.  Shares issued to employees under this program totaled 44,099 and 40,705 for the years ended December 31, 2007 and 2006, respectively.  Compensation expense related to the Employee Stock Award Plan was $2.2 million and $1.6 million in 2007 and 2006, respectively.

Deferred Compensation Plan for Non-Employee Directors

The ONEOK, Inc. Nonqualified Deferred Compensation Plan for Non-Employee Directors provides our directors, who are not our employees, the option to defer all or a portion of their compensation for their service on our Board of Directors.  Under the plan, directors may elect either a cash deferral option or a phantom stock option.  Under the cash deferral option, directors may defer the receipt of all or a portion of their annual retainer and/or meeting fees, plus accrued interest.  Under the phantom stock option, directors may defer all or a portion of their annual retainer and/or meeting fees and receive such fees on a deferred basis in the form of shares of common stock under our Long-Term Incentive Plan or Equity Compensation Plan.  Shares are distributed to non-employee directors at the fair market value of our common stock at the date of distribution.  In December 2008, we amended the Deferred Compensation Plan for Non-Employee Directors in accordance with Internal Revenue Code section 409A requirements.

O.           UNCONSOLIDATED AFFILIATES

Investments in Unconsolidated Affiliates - The following table sets forth our investments in unconsolidated affiliates for the periods indicated.
 
   
Net
   
 
     
 
   
   
 Ownership
      December 31,         December 31,    
   
 Interest
   
2008
     
2007
   
         
(Thousands of dollars)
   
Northern Border Pipeline
   
50 %
    $ 392,601       $ 418,982    
Bighorn Gas Gathering, L.L.C.
   
49 %
      97,289         97,716    
Fort Union Gas Gathering
   
37 %
      108,642         85,197    
Lost Creek Gathering Company, L.L.C. (a)
   
35 %
      77,773         75,612    
Other
 
Various
      79,187         78,753    
Investments in unconsolidated affiliates
          $ 755,492  
(b)
  $ 756,260  
(b)
                             
(a) - ONEOK Partners is entitled to receive an incentive allocation of earnings from third-party gathering services revenue recognized by Lost Creek Gathering Company, L.L.C. As a result of the incentive, ONEOK Partners’ share of Lost Creek Gathering Company, L.L.C.'s income exceeds its 35 percent ownership interest.
(b) - Equity method goodwill (Note E) was $185.6 million at December 31, 2008 and 2007.
             
 
 
Equity Earnings from Investments -   The following table sets forth our equity earnings from investments for the periods indicated.  All amounts in the table below are equity earnings from investments in our ONEOK Partners segment.

   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
   
(Thousands of dollars)
 
Northern Border Pipeline (a)
  $ 65,912     $ 62,008     $ 72,393  
Bighorn Gas Gathering, L.L.C.
    8,195       7,416       8,223  
Fort Union Gas Gathering
    14,172       9,681       9,030  
Lost Creek Gathering Company, L.L.C.
    5,365       4,790       5,363  
Other
    7,788       6,013       874  
Equity Earnings From Investments
  $ 101,432     $ 89,908     $ 95,883  
                         
(a) - For the first three months of 2006, ONEOK Partners included 70 percent of Northern Border Pipeline’s income in equity earnings from investments. After the sale of a 20 percent interest in Northern Border Pipeline in April 2006, ONEOK Partners included 50 percent of Northern Border Pipeline’s income in equity earnings from investments (Note B).
 

Unconsolidated Affiliates Financial Information - Summarized combined financial information of our unconsolidated affiliates is presented below.

   
December 31,
 
   
2008
   
2007
 
   
(Thousands of dollars)
 
Balance Sheet
           
Current assets
  $ 106,833     $ 102,805  
Property, plant and equipment, net
  $ 1,777,350     $ 1,724,330  
Other noncurrent assets
  $ 27,547     $ 25,882  
Current liabilities
  $ 279,996     $ 79,593  
Long-term debt
  $ 543,894     $ 717,301  
Other noncurrent liabilities
  $ 14,360     $ 10,278  
Accumulated other comprehensive income (loss)
  $ (5,708 )   $ (2,441 )
Owners' equity
  $ 1,079,188     $ 1,048,286  
 
   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
   
(Thousands of dollars)
 
Income Statement
                 
Operating revenue
  $ 415,552     $ 404,399     $ 386,448  
Operating expenses
  $ 179,380     $ 172,997     $ 159,452  
Net income
  $ 209,915     $ 184,434     $ 183,732  
                         
Distributions paid to us
  $ 118,010     $ 103,785     $ 123,427  



P.           EARNINGS PER SHARE INFORMATION

The following table sets forth the computation of basic and diluted EPS from continuing operations for the periods indicated.

 
Year Ended December 31, 2008
             
Per Share
   
Income
   
Shares
 
Amount
Basic EPS from continuing operations
(Thousands, except per share amounts)
Income from continuing operations available for common stock
  $ 311,909       104,369     $ 2.99  
Diluted EPS from continuing operations
                       
Effect of dilutive securities:
                       
Options and other dilutive securities
    -       1,391          
Income from continuing operations available for common stock
                       
and common stock equivalents
  $ 311,909       105,760     $ 2.95  
 
   
Year Ended December 31, 2007
             
Per Share
   
Income
   
Shares
 
Amount
Basic EPS from continuing operations
(Thousands, except per share amounts)
Income from continuing operations available for common stock
  $ 304,921       107,346     $ 2.84  
Diluted EPS from continuing operations
                       
Effect of other dilutive securities:
                       
Options and other dilutive securities
    -       1,952          
Income from continuing operations available for common stock
                       
and common stock equivalents
  $ 304,921       109,298     $ 2.79  
 
   
Year Ended December 31, 2006
             
Per Share
   
Income
   
Shares
 
Amount
Basic EPS from continuing operations
(Thousands, except per share amounts)
Income from continuing operations available for common stock
  $ 306,677       112,006     $ 2.74  
Diluted EPS from continuing operations
                       
Effect of other dilutive securities:
                       
Mandatory convertible units
    -       629          
Options and other dilutive securities
    -       1,842          
Income from continuing operations available for common stock
                       
and common stock equivalents
  $ 306,677       114,477     $ 2.68  

There were 64,989, 4,601 and 66,463 option shares excluded from the calculation of diluted EPS for 2008, 2007 and 2006, respectively, since their inclusion would be anti-dilutive.

Q.           ONEOK PARTNERS

Ownership Interest in ONEOK Partners - See Note B for discussion of the acquisition of the additional general partner interest in ONEOK Partners.

In April 2006, we received newly created Class B limited partner units from ONEOK Partners.  As of April 7, 2007, the Class B limited partner units are no longer subordinated to distributions on ONEOK Partners’ common units and generally have the same voting rights as the common units and are entitled to receive increased quarterly distributions and distributions on liquidation equal to 110 percent of the distributions paid with respect to the common units.  On June 21, 2007, we, as the sole holder of ONEOK Partners Class B limited partner units, waived our right to receive the increased quarterly distributions on the Class B units for the period April 7, 2007, through December 31, 2007, and continuing thereafter until we give
 
 
ONEOK Partners no less than 90 days advance notice that we have withdrawn our waiver.  Any such withdrawal of the waiver will be effective with respect to any distribution on the Class B units declared or paid on or after 90 days following delivery of the notice.

Under the ONEOK Partners’ partnership agreement and in conjunction with the issuance of additional common units by ONEOK Partners, we, as the general partner, are required to make equity contributions in order to maintain our representative general partner interest.

Our ownership interest in ONEOK Partners is shown in the table below for the periods presented.
 
   
December 31,
 
December 31,
 
December 31,
   
2008
 
2007
 
2006
General partner interest
 
2.00%
   
2.00%
   
2.00%
 
Limited partner interest
 
45.70%
(a)
 
43.70%
(b)
 
43.70%
(b)
Total ownership interest
 
47.70%
   
45.70%
   
45.70%
 
(a) - Represents 5.9 million common units and approximately 36.5 million Class B units, which are convertible, at our option, into common units.
(b) - Represents 0.5 million common units and approximately 36.5 million Class B units, which are convertible, at our option, into common units.
 
In March 2008, we purchased from ONEOK Partners, in a private placement, an additional 5.4 million of ONEOK Partners’ common units for a total purchase price of approximately $303.2 million.  In addition, ONEOK Partners completed a public offering of 2.5 million common units at $58.10 per common unit and received net proceeds of $140.4 million after deducting underwriting discounts but before offering expenses.  In conjunction with ONEOK Partners’ private placement and public offering of common units, ONEOK Partners GP contributed $9.4 million to ONEOK Partners in order to maintain its 2 percent general partner interest.  We and ONEOK Partners GP funded these amounts with available cash and short-term borrowings.

In April 2008, ONEOK Partners sold an additional 128,873 common units at $58.10 per common unit to the underwriters of the public offering upon their partial exercise of their option to purchase additional common units to cover over-allotments.  ONEOK Partners received net proceeds of approximately $7.2 million from the sale of these common units after deducting underwriting discounts but before offering expenses.  In conjunction with the partial exercise by the underwriters, ONEOK Partners GP contributed $0.2 million to ONEOK Partners in order to maintain its 2 percent general partner interest.

Cash Distributions - Under the ONEOK Partners’ partnership agreement, distributions are made to the partners with respect to each calendar quarter in an amount equal to 100 percent of available cash.  Available cash generally consists of all cash receipts adjusted for cash disbursements and net changes to cash reserves.  Available cash will generally be distributed 98 percent to limited partners and 2 percent to the general partner.  The general partner’s percentage interest in quarterly distributions is increased after certain specified target levels are met.  Under the incentive distribution provisions, the general partner receives:
·  
15 percent of amounts distributed in excess of $0.605 per unit;
·  
25 percent of amounts distributed in excess of $0.715 per unit; and
·  
50 percent of amounts distributed in excess of $0.935 per unit.

ONEOK Partners’ income is allocated to the general and limited partners in accordance with their respective partnership ownership percentages.  The effect of any incremental income allocations for incentive distributions that are allocated to the general partner is calculated after the income allocation for the general partner’s partnership interest and before the income allocation to the limited partners.



The following table shows ONEOK Partners’ general partner and incentive distributions related to the periods indicated.
 
   
Years Ended December 31,
   
2008
   
2007
   
2006
 
 
(Thousands of dollars)
General partner distributions
  $ 9,456     $ 7,842     $ 6,228  
Incentive distributions
    76,042       50,627       31,102  
Total distributions to general partner
  $ 85,498     $ 58,469     $ 37,330  

The quarterly distributions paid by ONEOK Partners to limited partners in the first, second, third and fourth quarters of 2008 were $1.025 per unit, $1.04 per unit, $1.06 per unit, and $1.08 per unit, respectively.

In January 2009, ONEOK Partners declared a cash distribution of $1.08 per unit payable in the first quarter.  On February 13, 2009, we received the related incentive distribution of $20.3 million for the fourth quarter of 2008, which is included in the table above.

Relationship - We own 47.7 percent of ONEOK Partners and consolidate ONEOK Partners in our consolidated financial statements; however, we are restricted from the assets and cash flows from ONEOK Partners except for our distributions.  Distributions are declared quarterly by ONEOK Partners’ general partner based on the terms of its partnership agreement.  For the years ended December 31, 2008, 2007 and 2006, cash distributions declared from ONEOK Partners to us totaled $266.1 million, $207.4 million and $145.1 million, respectively.  See Note M for more information on ONEOK Partners results.

Affiliate Transactions - We have certain transactions with our ONEOK Partners affiliate and its subsidiaries, which comprise our ONEOK Partners segment.

ONEOK Partners sells natural gas from its natural gas gathering and processing operations to our Energy Services segment.  In addition, a large portion of ONEOK Partners’ revenues from its natural gas pipelines businesses are from our Energy Services and Distribution segments, which utilize ONEOK Partners’ natural gas transportation and storage services.  ONEOK Partners also purchases natural gas from our Energy Services segment for its natural gas liquids operations and its gathering and processing operations.

ONEOK Partners has certain contractual rights to the Bushton Plant through a Processing and Services Agreement with us, which sets out the terms for processing and related services we provide at the Bushton Plant through 2012.  ONEOK Partners has contracted for all of the capacity of the Bushton Plant from OBPI.  In exchange, ONEOK Partners pays us for all direct costs and expenses of the Bushton Plant, including reimbursement of a portion of our obligations under equipment leases covering the Bushton Plant.

We provide a variety of services to our affiliates, including cash management and financial services, employee benefits provided through our benefit plans, administrative services provided by our employees and management, insurance and office space leased in our headquarters building and other field locations.  Where costs are specifically incurred on behalf of an affiliate, the costs are billed directly to the affiliate by us.  In other situations, the costs may be allocated to the affiliates through a variety of methods, depending upon the nature of the expenses and the activities of the affiliates.  For example, a service that applies equally to all employees is allocated based upon the number of employees in each affiliate.  However, an expense benefiting the consolidated company but having no direct basis for allocation is allocated by the modified Distrigas method, a method using a combination of ratios that include gross plant and investment, earnings before interest and taxes and payroll expense.



The following table shows transactions with ONEOK Partners for the periods shown.

   
Years Ended December 31,
 
   
2008
   
2007
   
2006
 
   
(Thousands of dollars)
 
Revenues
  $ 744,886     $ 626,764     $ 595,702  
                         
Expenses
                       
  Cost of sales and fuel
  $ 107,983     $ 89,792     $ 177,367  
  Administrative and general expenses
    191,798       171,741       175,270  
  Interest expense
    -       -       21,372  
  Total expenses
  $ 299,781     $ 261,533     $ 374,009  

See “Ownership Interest in ONEOK Partners” above for additional discussion of our purchase of common units and ONEOK Partners GP’s additional general partner contributions in March and April 2008.

R.           QUARTERLY FINANCIAL DATA (UNAUDITED)

   
First
   
Second
   
Third
   
Fourth
 
Year Ended December 31, 2008
 
Quarter
   
Quarter
   
Quarter
   
Quarter
 
   
(Thousands of dollars, except per share amounts)
 
Total Revenues
  $ 4,902,076     $ 4,172,866     $ 4,239,246     $ 2,843,245  
Net Margin
  $ 585,912     $ 420,828     $ 455,026     $ 473,761  
Operating Income
  $ 333,123     $ 173,012     $ 192,179     $ 218,690  
Net Income
  $ 143,837     $ 41,865     $ 58,033     $ 68,174  
Earnings per share from continuing operations
                               
Basic
  $ 1.38     $ 0.40     $ 0.56     $ 0.65  
Diluted
  $ 1.36     $ 0.39     $ 0.55     $ 0.65  
 
   
First
   
Second
   
Third
   
Fourth
 
Year Ended December 31, 2007
 
Quarter
   
Quarter
   
Quarter
   
Quarter
 
   
(Thousands of dollars, except per share amounts)
 
Total Revenues
  $ 3,806,208     $ 2,876,241     $ 2,809,997     $ 3,984,968  
Net Margin
  $ 564,850     $ 367,699     $ 340,160     $ 537,399  
Operating Income
  $ 328,301     $ 135,745     $ 102,770     $ 255,727  
Net Income
  $ 152,880     $ 35,203     $ 13,914     $ 102,924  
Earnings per share from continuing operations
                               
Basic
  $ 1.38     $ 0.32     $ 0.13     $ 0.99  
Diluted
  $ 1.36     $ 0.31     $ 0.13     $ 0.98  
 
ITEM 9.                        CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

ITEM 9A.                    CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

We have established disclosure controls and procedures to ensure that information required to be disclosed by us, including our consolidated entities, in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms.  Under the supervision and with the
 
 
participation of senior management, including our Chief Executive Officer (“Principal Executive Officer”) and our Chief Financial Officer (“Principal Financial Officer”), we evaluated our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Exchange Act.  Based on this evaluation, our Principal Executive Officer and our Principal Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2008.

Management’s Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f).  Under the supervision and with the participation of our management, including our Principal Executive Officer and Principal Financial Officer, we evaluated the effectiveness of our internal control over financial reporting based on the framework in Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.  Because of inherent limitations, internal control over financial reporting may not prevent or detect misstatements.  Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.  Based on our evaluation under that framework and applicable SEC rules, our management concluded that our internal control over financial reporting was effective as of December 31, 2008.

Our internal control over financial reporting as of December 31, 2008, has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which is included herein (Item 8).

Changes in Internal Controls Over Financial Reporting

We have made no changes in our internal controls over financial reporting (as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act) during the quarter ended December 31, 2008, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

ITEM 9B.                    OTHER INFORMATION

Not applicable.
PART III.

ITEM 10.
    DIRECTORS , EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

Directors of the Registrant

Information concerning our directors is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Executive Officers of the Registrant

Information concerning our executive officers is included in Part I, Item 1. Business, of this Annual Report on Form 10-K.

Compliance with Section 16(a) of the Exchange Act

Information on compliance with Section 16(a) of the Exchange Act is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Code of Ethics

Information concerning the code of ethics, or code of business conduct, is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Nominating Committee Procedures

Information concerning the nominating committee procedures is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.


Audit Committee

Information concerning the Audit Committee is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Audit Committee Financial Expert

Information concerning the Audit Committee Financial Expert is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

ITEM 11.                       EXECUTIVE COMPENSATION

Information on executive compensation is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

ITEM 12.                       SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND
       RELATED STOCKHOLDER MATTERS

Security Ownership of Certain Beneficial Owners

Information concerning the ownership of certain beneficial owners is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Security Ownership of Management

Information on security ownership of directors and officers is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

Equity Compensation Plan Information

The following table sets forth certain information concerning our equity compensation plans as of December 31, 2008.

               
Number of Securities
               
Remaining Available For
   
Number of Securities
Weighted-Average
Future Issuance Under
   
to be Issued Upon
Exercise Price of
Equity Compensation
   
Exercise of Outstanding
Outstanding Options,
Plans (Excluding
 
Options, Warrants and Rights
Warrants and Rights
Securities in Column (a))
Plan Category
(a)
(b)
(c)
Equity compensation plans
                 
approved by security holders (1)
 
2,300,035
   
$31.71
   
6,053,331
 
Equity compensation plans
                 
not approved by security holders (2)
 
179,133
   
$27.03
  (3)
 
4,153,578
 
Total
 
2,479,168
   
$31.37
   
10,206,909
 
                     
(1) -
Includes shares granted under our Employee Stock Purchase Plan, Employee Stock Award Program, stock options, restricted stock incentive units and performance unit awards granted under our Long-Term Incentive Plan and Equity Compensation Plan.  For a brief description of the material features of these plans, see Note N of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.  Column (c) includes 1,408,443, 155,648, 2,120,616 and 2,368,624 shares available for future issuance under our Employee Stock Purchase Plan, Employee Stock Award Program, Long-Term Incentive Plan and Equity Compensation Plan, respectively.
(2) -
Includes our Employee Non-Qualified Deferred Compensation Plan, Deferred Compensation Plan for Non-Employee Directors and Stock Compensation Plan for Non-Employee Directors.  For a brief description of the material features of these plans, see Note N of the Notes to Consolidated Financial Statements in this Annual Report on Form 10-K.  Column (c) includes 503,602, 2,707,003 and 942,973 shares available for future issuance under our Stock Compensation Plan for Non-Employee Directors, Thrift Plan and Profit Sharing Plan, respectively.
(3) -
Compensation deferred into our common stock under our Employee Non-Qualified Deferred Compensation Plan and Deferred Compensation Plan for Non-Employee Directors is distributed to participants at fair market value on the date of distribution.  The price used for these plans to calculate the weighted-average exercise price in the table is $29.12, which represents the year-end closing price of our common stock on the NYSE.
 
 
ITEM 13.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Information on certain relationships and related transactions and director independence is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

ITEM 14.               P RINCIPAL ACCOUNTING FEES AND SERVICES

Information concerning the principal accountant’s fees and services is set forth in our 2009 definitive Proxy Statement and is incorporated herein by this reference.

 
PART IV.

ITEM 15.               E XHIBITS , FINANCIAL STATEMENT SCHEDULES
 
(1)   Financial Statements
 
Page No.
    (a)
Reports of Independent Registered Public Accounting Firms
 
67-68
    (b)
Consolidated Statements of Income for the years ended
December 31, 2008, 2007 and 2006
 
69
    (c)
Consolidated Balance Sheets as of December 31, 2008 and 2007
 
70-71
    (d)
Consolidated Statements of Cash Flows for the years ended
December 31, 2008, 2007 and 200
 
73
    (e)
Consolidated Statements of Shareholders’ Equity and Comprehensive
Income for the years ended December 31, 2008, 2007 and 2006
 
74-75
    (f)
Notes to Consolidated Financial Statements
76-117
 
(2)  Financial Statement Schedules

All schedules have been omitted because of the absence of conditions under which they are required.

(3)  Exhibits

 
3
Not used.

 
3.1
Not used.

 
3.2
Not used.

 
3.3
Not used.

 
3.4
Amended and Restated Bylaws of ONEOK, Inc. (incorporated by reference from Exhibit 99.1 to Form 8-K filed January 20, 2009).

 
3.5
Amended and Restated Certificate of Incorporation of ONEOK, Inc. dated May 15, 2008 (incorporated by reference from Exhibit 3.1 to Form 8-K filed May 19, 2008).

 
3.6
Certificate of Correction form dated November 5, 2008 (incorporated by reference from Exhibit 4.2 to Registration Statement on Form S-3 filed November 21, 2008).
 
 
 
4
Certificate of Designation for Convertible Preferred Stock of WAI, Inc. (now ONEOK, Inc.) filed November 21, 2008 (incorporated by reference from Exhibit 4.2 to Registration Statement on Form S-3 filed November 21, 2008, Commission File No. 333-155593).

 
4.1
Certificate of Designation for Series C Participating Preferred Stock of ONEOK, Inc. filed November 21, 2008 (incorporated by reference from Exhibit No. 4.2 to Registration Statement on Form S-3 filed November 21, 2008).

 
4.2
Form of Common Stock Certificate (incorporated by reference from Exhibit 1 to Registration Statement on Form 8-A filed November 21, 1997).

 
4.3
Indenture, dated September 24, 1998, between ONEOK, Inc. and Chase Bank of Texas (incorporated by reference from Exhibit 4.1 to Registration Statement on Form S-3 filed August 26, 1998, Commission File No. 333-62279).

 
4.4
Indenture dated December 28, 2001, between ONEOK, Inc. and SunTrust Bank (incorporated by reference from Exhibit 4.1 to Amendment No. 1 to Registration Statement on Form S-3 filed December 28, 2001, Commission File No. 333-65392).

 
4.5
First Supplemental Indenture dated September 24, 1998, between ONEOK, Inc. and Chase Bank of Texas (incorporated by reference from Exhibit 5(a) to Form 8-K filed September 24, 1998).
 
 
4.6
Second Supplemental Indenture dated September 25, 1998, between ONEOK, Inc. and Chase Bank of Texas (incorporated by reference from Exhibit 5(b) to Form 8-K filed September 24, 1998).
 
 
4.7
Third Supplemental Indenture dated February 8, 1999, between ONEOK, Inc. and Chase Bank of Texas (incorporated by reference from Exhibit 4 to Form 8-K filed February 8, 1999).

 
4.8
Fourth Supplemental Indenture dated February 17, 1999, between ONEOK, Inc. and Chase Bank of Texas (incorporated by reference from Exhibit 4.5 to Registration Statement on Form S-3 filed April 15, 1999, Commission File No. 333-76375).

 
4.9
Not used.

 
4.10
Not used.

 
4.11
Not used.

 
4.12
Eighth Supplemental Indenture dated April 6, 2001, between ONEOK, Inc. and The Chase Manhattan Bank (incorporated by reference from Exhibit 4.9 to Registration Statement on Form S-3 filed July 19, 2001, Commission File No. 333-65392).

 
4.13
First Supplemental Indenture, dated as of January 28, 2003, between ONEOK, Inc. and SunTrust Bank (incorporated by reference from Exhibit 4.22 to Registration Statement on Form 8-A/A filed January 31, 2003).

 
4.14
Second Supplemental Indenture, dated June 17, 2005, between ONEOK, Inc. and SunTrust Bank (incorporated by reference from Exhibit 4.1 to Form 8-K filed June 17, 2005).

 
4.15
Third Supplemental Indenture, dated June 17, 2005, between ONEOK, Inc. and SunTrust Bank (incorporated by reference from Exhibit 4.3 to Form 8-K filed June 17, 2005).
 
 
4.16
Form of Senior Note Due 2008 (included in Exhibit 4.13).
 
 
4.17
Form of 5.20 percent Notes Due 2015 (included in Exhibit 4.14).
 
 
4.18
Form of 6.00 percent Notes due 2035 (included in Exhibit 4.15).
                         

 
4.19
Not used.

4.20                     Not used.

 
4.21
Not used.

 
4.22
Not used.

 
4.23
Not used.

 
4.24
Amended and Restated Rights Agreement dated as of February 5, 2003, between ONEOK, Inc. and UMB Bank, N.A., as Rights Agent (incorporated by reference from Exhibit 1 to Registration Statement on Form 8-A/A (Amendment No. 1) filed February 6, 2003).

 
10
ONEOK, Inc. Long-Term Incentive Plan (incorporated by reference from Exhibit 10(a) to Form 10-K for the fiscal year ended December 31, 2001, filed March 14, 2002).

 
10.1
ONEOK, Inc. Stock Compensation Plan for Non-Employee Directors (incorporated by reference from Exhibit 99 to Form S-8 filed January 25, 2001).

 
10.2
ONEOK, Inc. Supplemental Executive Retirement Plan terminated and frozen December 31, 2004 (incorporated by reference from Exhibit 10.1 to Form 8-K filed on December 20, 2004).

 
10.3
ONEOK, Inc. 2005 Supplemental Executive Retirement Plan, as amended and restated, dated December 18, 2008.

 
10.4
Form of Termination Agreement between ONEOK, Inc. and ONEOK, Inc. executives, as amended, dated January 1, 2003 (incorporated by reference from Exhibit 10.3 to Form 10-K for the fiscal year ended December 31, 2002, filed March 10, 2003).

 
10.5
Form of Indemnification Agreement between ONEOK, Inc. and ONEOK, Inc. officers and directors, as amended, dated January 1, 2003 (incorporated by reference from Exhibit 10.4 to Form 10-K for the fiscal year ended December 31, 2002, filed March 10, 2003).

 
10.6
ONEOK, Inc. Annual Officer Incentive Plan (incorporated by reference from Exhibit 10(f) to Form 10-K for the fiscal year ended December 31, 2001, filed March 14, 2002).

 
10.7
ONEOK, Inc. Employee Nonqualified Deferred Compensation Plan, as amended and restated December 16, 2004 (incorporated by reference from Exhibit 10.3 to Form 8-K filed December 20, 2004).

 
10.8
ONEOK, Inc. 2005 Nonqualified Deferred Compensation Plan, as amended and restated, dated December 18, 2008.

 
10.9
ONEOK, Inc. Deferred Compensation Plan for Non-Employee Directors, as amended and restated, dated December 18, 2008.

 
10.10
Not used.

 
10.11
Not used.

 
10.12
Not used.

 
10.13
Not used.

 
10.14
Not used.

 
10.15
Not used.


 
10.16
Not used.

 
10.17
$1,200,000,000 Amended and Restated Credit Agreement dated as of July 14, 2006 among ONEOK, Inc., as the Borrower, Bank of America, N.A., as Administrative Agent, Swing Line Lender and L/C Issuer, Citibank, N.A., as L/C Issuer, and the Lenders party hereto (incorporated by reference from Exhibit 10.1 to the Form 10-Q for the quarter ended June 30, 2006, filed August 4, 2006).

 
10.18
Not used.

 
10.19
Not used.

 
10.20
Not used.

 
10.21
First Amendment, dated as of September 26, 2008, to the Amended and Restated Credit Agreement, dated as of July 14, 2006, among ONEOK, Inc., as the Borrower, Bank of America, N.A., as the Administrative Agent, Swing Line Lender and L/C Issuer, Citibank N.A., as L/C Issuer and the financial institutions named therein as lenders (incorporated by reference from Exhibit 10.1 to our Form 10-Q filed November 6, 2008).

 
10.22
Not used.

 
10.23
Not used.

 
10.24
Not used.

 
10.25
Not used.

 
10.26
Not used.

 
10.27
Not used.

 
10.28
Not used.

 
10.29
Not used.

 
10.30
Not used.

 
10.31
Not used.

 
10.32
Services Agreement among ONEOK, Inc. and its affiliates and Northern Border Partners, L.P. and Northern Border Intermediate Limited Partnership executed April 6, 2006, but effective as of April 1, 2006 (incorporated by reference from Exhibit 10.1 to our Form 8-K filed April 12, 2006).

 
10.33
Third Amended and Restated Agreement of Limited Partnership of ONEOK Partners, L.P. dated as of September 15, 2006 (incorporated by reference to Exhibit 3.1 to ONEOK Partners, L.P.’s Form 8-K filed on September 19, 2006 (File No. 1-12202)).

 
10.34
Not used.

 
10.35
Not used.

 
10.36
Not used.

 
10.37
ONEOK, Inc. Profit Sharing Plan dated January 1, 2005 (incorporated by reference from Exhibit 99 to Registration Statement on Form S-8 filed December 30, 2004).
 
 
 
10.38
ONEOK, Inc. Employee Stock Purchase Plan as amended and restated effective as of December 20, 2007 (incorporated by reference from Exhibit 4.2 to Registration Statement on Form S-8 filed August 4, 2008).

 
10.39
Form of Non-Statutory Stock Option Agreement (incorporated by reference from Exhibit 10.1 to Form 10-Q for the quarter ended September 30, 2004, filed November 3, 2004).

 
10.40
Not used.

 
10.41
Not used.

 
10.42
Not used.

 
10.43
Not used.

 
10.44
ONEOK, Inc. Equity Compensation Plan, as amended and restated, dated December 18, 2008.

 
10.45
Form of Restricted Unit Award Agreement (incorporated by reference from Exhibit 10.45 to Form 10-K filed February 28, 2007).

 
10.46
Form of Performance Unit Award Agreement (incorporated by reference from Exhibit 10.46 to Form 10-K filed February 28, 2007).

 
10.47
First Amendment to Letter of Credit Reimbursement Agreement by and between KBC Bank N.V. and ONEOK, Inc. dated December 19, 2005 (incorporated by reference from Exhibit 10.47 to our Form 10-K for the year ended December 31, 2006, filed March 1, 2007).

 
10.48
Amended and Restated Revolving Credit Agreement dated March 30, 2007, among ONEOK Partners, L.P., as Borrower, the lenders from time to time party thereto, SunTrust Bank, as Administrative Agent, Wachovia Bank, National Association, as Syndication Agent, and BMO Capital Markets, Barclays Bank PLC, and Citibank, N.A., as Co-Documentation Agents (incorporated by reference from Exhibit 10.1 to our Form 10-Q filed May 2, 2007).

 
10.49
Purchase Agreement dated June 27, 2007, by and between ONEOK, Inc. (the “Issuer”), and Bank of America, N.A., acting through Banc of America Securities LLC (“Agent”) as agent (incorporated by reference from Exhibit 10.1 to our Form 10-Q filed August 3, 2007).

 
10.50
Thrift Plan for Employees of ONEOK, Inc. and Subsidiaries as amended and restated effective as of January 1, 2008 (incorporated by reference from Exhibit 4.3 to Registration Statement on Form S-8 filed August 4, 2008).

 
10.51
Amendment No. 1 to Third Amended and Restated Agreement of Limited Partnership of ONEOK Partners, L.P. dated July 20, 2007 (incorporated by reference to Exhibit 3.1 to ONEOK Partners, L.P.’s Form 10-Q filed on August 3, 2007 (File No. 1-12202)).

 
10.52
$400,000,000 364-Day Revolving Credit Agreement dated as of August 6, 2008, among ONEOK, Inc., as Borrower, Bank of America, N.A., as the Administrative Agent and Swing Line Lender, the lenders named therein, Barclays Bank, PLC, BNP Paribas, Suntrust Bank and UBS Loan Finance LLC as Co-Documentation Agents, and Banc of America Securities LLC as sole Lead Arranger and sole Book Manager (incorporated by reference from Exhibit 10.4 to the Form 10-Q for the quarter ended June 30, 2008, filed August 6, 2008).

 
10.53
Common Unit Purchase Agreement between ONEOK, Inc. and ONEOK Partners, L.P. dated March 11, 2008 (incorporated by reference from Exhibit 1.1 to our Form 8-K filed March 12, 2008).

 
10.54
Form of Performance Unit Award Agreement dated January 15, 2009.

 
10.55
Form of Restricted Unit Stock Bonus Award Agreement dated January 15, 2009.


 
12
Computation of Ratio of Earnings to Fixed Charges for the years ended December 31, 2008, 2007, 2006, 2005 and 2004.
 
 
16.1
Letter from KPMG LLP dated May 2, 2007, to the Securities and Exchange Commission regarding change in certifying accountant (incorporated by reference to Exhibit 16.1 to our Form 8-K filed on May 2, 2007).
 
 
21
Required information concerning the registrant’s subsidiaries.
 
 
23.1
Consent of Independent Registered Public Accounting Firm - PricewaterhouseCoopers LLP.
 
 
23.2
Consent of Independent Registered Public Accounting Firm - KPMG LLP.
 
 
31.1
Certification of John W. Gibson pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
 
 
31.2
Certification of Curtis L. Dinan pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

 
32.1
Certification of John W. Gibson pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).

 
32.2
Certification of Curtis L. Dinan pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (furnished only pursuant to Rule 13a-14(b)).





Signatures

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

ONEOK, Inc.
Registrant

Date: February 24, 2009                                                                                                By: /s/ Curtis L. Dinan
Curtis L. Dinan
Senior Vice President,
Chief Financial Officer and Treasurer
(Principal Financial Officer)


Pursuant to the requirements of the Exchange Act, this report has been signed below by the following persons on behalf of the registrant and in the capacities indicated on this 24th day of February 2009.


/s/ John W. Gibson
 
/s/ David L. Kyle
John W. Gibson
 
David L. Kyle
Chief Executive Officer
 
Chairman of the
   
Board of Directors
     
/s/ Caron A. Lawhorn
 
/s/ James C. Day
Caron A. Lawhorn
 
James C. Day
Senior Vice President and
 
Director
Chief Accounting Officer
   
     
/s/ Julie H. Edwards
 
/s/ William L. Ford
Julie H. Edwards
 
William L. Ford
Director
 
Director
     
/s/ Bert H. Mackie
 
/s/ Jim W. Mogg
Bert H. Mackie
 
Jim W. Mogg
Director
 
Director
     
/s/ Pattye L. Moore
 
/s/ Gary D. Parker
Pattye L. Moore
 
Gary D. Parker
Director
 
Director
     
/s/ Eduardo A. Rodriguez
 
/s/ David J. Tippeconnic
Eduardo A. Rodriguez
 
David J. Tippeconnic
Director
 
Director
     
/s/ Mollie B. Williford
   
Mollie B. Williford
   
Director
   






 
- 126 -


 
Exhibit 10.3
 
 

ONEOK, INC.
 
2005 SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
 
As Amended and Restated December 18, 2008
 

 

 
 

 

ONEOK, INC.
2005 SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
As Amended and Restated December 18, 2008
 
Table of Contents
 
Page
 
PURPOSE
1
PART A.
EXCESS RETIREMENT BENEFITS
2
ARTICLE I.     PURPOSE AND SCOPE OF PART A
3
1.1
Part A; Excess Retirement Benefits
3
1.2
Separate Benefits
3
1.3
Deferral of Compensation
3
ARTICLE II.     ELIGIBILITY AND PARTICIPATION
3
2.1
Eligibility for Selection
3
2.2
Designation and Selection of Part A Participants in the Plan
3
2.3
Scope of Part A Participation
4
2.4
Election to Defer Compensation
4
ARTICLE III.     EXCESS RETIREMENT BENEFIT
5
3.1
Excess Retirement Benefit
5
3.2
Payment of Excess Retirement Benefit
6
3.3
Specified Employee; Six (6) Month Required Delay in Payment
8
3.4
Vesting of Excess Retirement Benefit
8
3.5
Form of Payment
9
3.6
Disability
9
3.7
Death
9
3.8
Nonqualified Deferred Compensation Plan Requirements
9
ARTICLE IV.     BENEFICIARY
10
ARTICLE V.      LEAVE OF ABSENCE
10
ARTICLE VI.     ADMINISTRATION OF PART A OF THIS PLAN
10
PART B.
SUPPLEMENTAL RETIREMENT BENEFITS
11
ARTICLE I.        PURPOSE AND SCOPE OF PART B
12
1.1
Part B, Supplemental Retirement Benefits
12
1.2
Separate Benefits
12
1.3
Deferral of Compensation
12
ARTICLE II.   BENEFIT ACCOUNTS
12
2.1
Eligibility for Selection
12

  - i -
 

 


2.2
Designation and Selection of Part B Participants in the Plan
12
2.3
Scope of Part B Participation
13
2.4
Election to Defer Compensation
13
ARTICLE III.     SUPPLEMENTAL RETIREMENT BENEFIT
14
3.1
Supplemental Retirement Benefit
14
3.2
Payment of Supplemental Retirement Benefit
16
3.3
Specified Employee; Six (6) Month Required Delay in Payment
19
3.4
Vesting of Supplemental Retirement Benefit
19
3.5
Form of Payment
19
3.6
Disability
20
3.7
Death
20
3.8
Nonqualified Deferred Compensation Plan Requirements
20
ARTICLE IV.   BENEFICIARY
20
ARTICLE V.   SUPPLEMENTAL RETIREMENT BENEFIT  ADJUSTMENTS
21
ARTICLE VI.   LEAVE OF ABSENCE
21
ARTICLE VII.  ADMINISTRATION OF PART B OF THE PLAN
21
PART C.
PLAN ADIMINSTRATION AND MISCELLANEOUS PROVISIONS
22
ARTICLE I.        PURPOSE AND SCOPE OF PART C
23
ARTICLE II.   DEFINITIONS AND CONSTRUCTION
23
2.1
Definitions
23
2.2
Construction
29
2.3
Plan Purpose
29
ARTICLE III.   COMMITTEE
29
3.1
Appointment of Committee
29
3.2
Committee Officials
29
3.3
Committee Action
30
3.4
Committee Rules and Powers
30
3.5
Reliance on Certificates, etc.
30
3.6
Liability of Committee
30
3.7
Determination of Benefits
30
3.8
Information to Committee
31
ARTICLE IV.   ADOPTION OF PLAN BY SUBSIDIARY, AFFILIATED OR ASSOCIATED COMPANIES
31
ARTICLE V.   SOURCE OF BENEFITS
31
5.1
Benefits Payable
31

  - ii -
 

 


5.2
Investments to Facilitate Payment of Benefits
31
5.3
Ownership of Insurance Contracts
31
5.4
Trust for Payment of Benefits
32
ARTICLE VI.                                 TERMINATION OF EMPLOYMENT
32
ARTICLE VII.                                TERMINATION OF PARTICIPATION
33
ARTICLE VIII.                                           TERMINATION, AMENDMENT, MODIFICATION, OR SUPPLEMENT OF THE PLAN
33
8.1
Amendment or Termination
33
8.2
Rights and Obligations Upon Amendment, Termination
34
ARTICLE IX.                                 TREATMENT OF BENEFITS
34
ARTICLE X.                                 RESTRICTIONS ON ALIENATION OF BENEFITS
35
ARTICLE XI.                                 MISCELLANEOUS
35
11.1
Deferral of Compensation Requirements
35
11.2
Execution of Receipts and Releases
36
11.3
No Guarantee of Interests
36
11.4
Company Records
36
11.5
Evidence
36
11.6
Notice
36
11.7
Change of Address
37
11.8
Effect of Provisions
37
11.9
Headings
37
11.10
Governing Law
37
11.11
Effective Date
37
APPENDIX I
38



  - iii -
 

 

ONEOK, INC.
2005 SUPPLEMENTAL EXECUTIVE RETIREMENT PLAN
As Amended and Restated December 18, 2008
 
PURPOSE
 
The purpose of the ONEOK, Inc. 2005 Supplemental Executive Retirement Plan is to provide the specified benefits to employees who are in a select group of management or highly compensated employees who contribute materially to the continued growth, development and future business success of ONEOK, Inc., and its subsidiaries, effective January 1, 2005.  It is the intention of ONEOK, Inc. that the Plan and the particular benefits provided to individuals hereunder be administered as an unfunded nonqualified deferred compensation and excess benefit plans established and maintained for a select group of management or highly compensated employees.
 
This Plan is a new and separate plan, and except as otherwise expressly provided herein, is not a continuation, successor plan to, or an amendment or restatement of the preexisting and separate ONEOK, Inc. Supplemental Executive Retirement Plan, as terminated and frozen pursuant to the terms thereof, effective December 31, 2004 (hereinafter referred to as the “Prior Frozen SERP”).  It is intended that no individual shall be entitled to benefit under both the Prior Frozen SERP and this Plan.
 
The Plan is intended to meet all requirements of Section 409A of the Code for compensation deferred under the Plan to not be includible in gross income of the Participant until actually paid or distributed pursuant to the Plan.
 
The capitalized words and terms in this Plan document shall have the meaning given in the definitions stated in Part C, Article II of the Plan, unless otherwise expressly indicated.
 
                       
 

 
- 1 -

 

PART A.                        EXCESS RETIREMENT BENEFITS
 

 
- 2 -

 

ARTICLE I.                                 
 
PURPOSE AND SCOPE OF PART A
 
1.1   Part A; Excess Retirement Benefits .  The provisions of Part A of the Plan shall establish and provide excess retirement benefits to Employees of the Company who are (i) in a select group of management or highly compensated employees of the Company within the meaning of Sections 201(a)(7), 301(a)(9) and 401(a)(1) of ERISA, and (ii) selected to participate in Excess Retirement Benefits pursuant to the terms and provisions of this Part A of the Plan.
 
1.2   Se parate Benefits .  The Excess Retirement Benefits provided to participants under Part A of the Plan are separate and independent from Supplemental Retirement Benefits provided under Part B of the Plan.
 
1.3   Deferral of Compensation .  The Excess Retirement Benefits provided to Participants under Part A of the Plan shall be considered and treated as deferral of compensation to the extent and in the manner provided for in Section 409A of the Code and Treasury Regulations thereunder.
 
ARTICLE II.                                 
 
ELIGIBILITY AND PARTICIPATION
 
2.1   Eligibility for Selection . In order to be eligible to be selected as a Part A Participant in the Plan pursuant to Section 2.2 of this Article II, below, an Employee must be in a select group of management or highly compensated employees of the Company, as determined by the Chief Executive Officer, or the Committee in the case of the Chief Executive Officer, in the Chief Executive Officer’s (or Committee’s, as applicable) sole and absolute discretion.  An eligible Employee may become a Part A Participant in the Plan only by being selected for participation pursuant to Section 2.2 of this Article II, below.
 
         2.2   Designation and Selection of Part A Participants in the Plan .
 
A.   In order to participate in Part A of the Plan an eligible Employee must also be specifically designated and selected by the Chief Executive Officer, or in the case of the Chief Executive Officer, by the Committee, to be a Part A Participant in the Plan, with such designation and selection to be in the Chief Executive Officer’s (or Committee’s, as applicable) sole and absolute discretion.
 
B.   The designation and selection of any eligible Employee to be a Part A Participant in the Plan by the Chief Executive Officer/Committee, shall be confirmed in writing by a written instrument and/or memorandum which shall specify the date that compensation is first deferred under this Plan for such Part A Participant and the date of his/her designation and selection, in such form as is prescribed by the Committee that shall be in substantially the same form as Appendix I to this Plan and that shall be made a part of the records of the Plan and the Company.
 
C.   Not every eligible Employee is required to be, or necessarily will be designated and selected to be a Part A Participant in the Plan.
 

 
- 3 -

 

D.   An eligible Employee who is not designated and selected to be a Part A Participant pursuant to this Section 2.2, shall not be entitled to any benefit or payment under Part A of the Plan.
 
E.   No Employee who is a participant in the Prior Frozen SERP or entitled to receive any benefit or payment under the Prior Frozen SERP shall be designated and selected to be a Part A Participant in the Plan; and it may be made a condition to the designation and selection of an eligible Employee as a Part A Participant that such Employee shall have elected in writing to completely terminate his/her participation in the Prior Frozen SERP and waive all his/her entitlement to any benefit or payment under the Prior Frozen SERP.
 
F.   Notwithstanding anything otherwise provided herein, any eligible Employee who becomes a Part A Participant shall be deemed to consent and agree that his/her participation in Part A of the Plan shall supersede and cancel any entitlement he/she had to any benefit or payment under the Prior Frozen SERP.
 
2.3   Scope of Part A Participation .  An eligible Employee designated and selected to be a Part A Participant in the Plan shall, as a Part A Participant, be entitled solely to the rights and benefits provided under the terms of Part A of the Plan, and such designation and selection shall not entitle such Employee to participate in Part B of the Plan or to receive benefits thereunder; provided, that an Employee who is an Officer of the Company may be designated and selected to be a Part A Participant, and selected under Part B of the Plan to be a Part B Participant.
 
         2.4   Election to Defer Compensation .
 
A.   Except as provided in Section 2.4.B., of this Article, the Company, pursuant to the Plan, elects, determines and provides for the time and form of payment of an Excess Retirement Benefit to any eligible Employee who is designated and selected to be a Part A Participant.  The time and form of payment of an Excess Retirement Benefit is stated and provided in Article III of this Part A of the Plan.
 
B.   A Part A Participant shall make a written Election that shall include a Specified Time which shall be the Normal Specified Time of Distribution when his/her Excess Retirement Benefit is to be paid and distributed under the Plan. The Specified Time that may be stated in the Election, shall be:
 
(1)  The later of (a) a Specified Date, or (b) the date such Part A Participant (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company; or
 
(2)  The date such Part A Participant (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company.
 

 
- 4 -

 

The Normal Specified Time of Distribution of a Part A Participant shall in no event be before he/she (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company.
 
C.   The designation and Election of the time and form of payment of the Excess Retirement Benefit of an eligible Employee  when he/she is first designated and selected to be a Part A Participant in the Plan shall be made and confirmed in writing on or before the date that is thirty (30 days after the date of such designation and selection in an instrument prescribed by the Committee that shall be in substantially the same form as Appendix I to this Plan and that shall be made a part of the records of the Plan and the Company.
 
D.   The designation and Election of the time and form of payment of an Excess Retirement Benefit of a Part A Participant shall apply with respect to all compensation deferred under the Plan for the Part A Participant after the date of his/her designation and selection.  The designation and Election of the time and form of payment of an Excess Retirement Benefit of a Part A Participant shall be effective on and after the date that it is made by the Part A Participant and the Company as to compensation deferred under the Plan for all taxable years of the Part A Participant thereafter.
 
E.   The Plan does not provide an eligible Employee or Part A Participant the opportunity to make an initial election of the form of payment of the Excess Retirement Benefit to him/her under the Plan.  A Part A Participant shall be allowed to change the form of an annuity benefit to the extent provided in Section 3.5 of Article III of this Part A of the Plan.  A Part A Participant shall be allowed to make a Subsequent Election as to time of payment of an Excess Retirement Benefit as provided in Section 3.2 of Article III of this Part A of the Plan.
 
F.   All Elections made under the Plan by and for a Part A Participant on or before December 31, 2008, shall be retroactively effective to conform to the terms and provisions of the Plan, as amended and restated effective December 18, 2008, to meet the requirements of Code section 409A and Treasury Regulations to the extent allowed under such regulations and published guidance of the Internal Revenue Service.
 
ARTICLE III.                                 
 
EXCESS RETIREMENT BENEFIT
 
3.1   Excess Retirement Benefit .
 
A.           The Company shall pay each Part A Participant the vested Excess Retirement Benefit attributable to a Part A Participant’s annual eligible compensation under the Retirement Plan that is in excess of the limitations on such Part A Participant’s Retirement Plan Benefits contained in Code Sections 401(a)(17) and 415(b).
 
B.           The Excess Retirement Benefit will be calculated by applying the same benefit formula, vesting provisions, and early retirement provisions as are in and apply to the Part A Participant’s Retirement Plan Benefit under the Retirement Plan.
 

 
- 5 -

 

C.           The Excess Retirement  Benefit shall be calculated for the time of the commencement of payment of it to a Part A Participant (hereinafter referred to as "Excess Retirement Benefit Commencement Date") pursuant to the terms and provisions of the Plan governing the time and form of payment thereof, irrespective of whether or not a corresponding Retirement Plan Benefit is then being paid or is to commence payment to such Part A Participant at that time, and irrespective of the time and form of payment of the Retirement Plan Benefit that has been elected, is being paid or may be paid to the Part A Participant.
 
D.           The Excess Retirement Benefit shall be calculated and determined for the Excess Retirement Benefit Commencement Date of a Part A Participant as follows:
 
(1)  Calculate as a single (straight) life annuity payable at age sixty-five (65);
 
(2)  Apply early retirement provisions based upon the age of the Part A Participant at the Excess Retirement Benefit Commencement Date;
 
(3)  Apply the factors for the form of payment that has been elected by the Part A Participant in accordance with the terms and provisions of this Plan as an actuarial equivalent of a single (straight) life annuity, if such elected form of payment is other than a single (straight) life annuity in accordance with the Plan and reasonable actuarial assumptions and methods, as determined by the Committee; and
 
(4)  Deduct the Retirement Plan Benefit calculated at the same time and form of payment as the Excess Retirement Benefit, irrespective of the time and form of payment of the Retirement Plan Benefit elected by the Participant for the Retirement Plan.
 
E.           The Committee shall be authorized to take such other actions and apply procedures that it determines, in its discretion, to calculate, determine and commence the payment of an Excess Retirement Benefit to a Part A Participant at the Excess Retirement Benefit Commencement Date.
 
F.           All Elections made under the Plan by and for a Part B Participant on or before December 31, 2008, shall be retroactively effective to conform to the terms and provisions of the Plan, as amended and restated effective December 18, 2008, to meet the requirements of Code section 409A and Treasury Regulations to the extent allowed under such regulations and published guidance of the Internal Revenue Service.
 
3.2   Payment of Excess Retirement Benefit .
 
A.   Subject to the requirements of Section 3.3 below (six-month required delay of payment for Specified Employee), a vested Excess Retirement Benefit shall be paid to a Part A Participant entitled thereto or his/her Beneficiary, commencing on his/her Normal Specified Distribution Date.
 

 
- 6 -

 

B.   A Part A Participant shall be allowed to make a Subsequent Election to change the time of distribution and payment of his/her Excess Retirement Benefit from his/her Normal Specified Distribution Date to a Subsequent Election Distribution Date resulting from such election, if:
 
(i)   he/she delivers a written notification of such Subsequent Election to the Committee, or its designee, in the form it prescribes, not less than twelve (12) months prior to his/her Normal Specified Distribution Date, and
 
(ii)   he/she makes a corresponding Subsequent Election with respect to any Supplemental Retirement Benefit he/she is entitled to under Part B of the Plan in such written notification.
 
C.    A Part A Participant shall be allowed to make a Subsequent Election as to any Subsequent Election Distribution Date established for the payment of his/her Excess Retirement Benefit if:
 
(i)   he/she delivers a written notification of such Subsequent Election to the Committee, or its designee, in the form it prescribes, not less than twelve (12) months prior to such Subsequent Election Distribution Date, and
 
(ii)   he/she makes a corresponding Subsequent Election with respect to any Supplemental Retirement Benefit he/she is entitled to under Part B of the Plan in such written notification.
 
D.   Notwithstanding anything otherwise provided in the Plan or in any Election or Subsequent Election of a Part A Participant, any Subsequent Election made by a Part A Participant under the Plan shall result in a Subsequent Election Distribution Date of his/her Excess Retirement Benefit being established for it, and the first distribution and payment with respect to which such Subsequent Election is made being deferred to a Subsequent Election Distribution Date that is not less than five (5) years from the date such distribution and payment would otherwise have been made.
 
E.   Except as otherwise expressly specified in the Plan, a distribution or payment shall be treated as made upon the date specified under the Plan if the payment is made at such date or a later date within the same taxable year of the Participant or, if later, by the 15th day of the third calendar month following the date specified under the Plan and the Participant is not permitted, directly or indirectly, to designate the taxable year of the payment. In addition, a distribution or payment shall be treated as made upon the date specified under the Plan and shall not be treated as an accelerated payment if the payment is made no earlier than thirty (30) days before the designated payment date and the Participant is not permitted, directly or indirectly, to designate the taxable year of the payment. For purposes of this paragraph, if the date specified is only a designated taxable year of the Participant, or a period of time during such a taxable year, the date specified under the Plan is treated as the first day of such taxable year or the first day of the period of time during such taxable year, as applicable. If calculation of the amount of the distribution or payment is not administratively practicable due to events beyond the
 

 
- 7 -

 

control of the Participant (or Participant's beneficiary), the distribution or payment will be treated as made upon the date specified under the Plan if the distribution or payment is made during the first taxable year of the Participant in which the calculation of the amount of the distribution or payment is administratively practicable. For purposes of this section, the inability of a Corporation to calculate the amount or timing of a distribution or payment due to a failure of a Participant (or Participant's beneficiary) to provide reasonably available information necessary to make such calculation does not constitute an event beyond the control of the Participant.
 
3.3   Specified Employee ; Six (6) Month Required Delay in Payment .  If a Part A Participant is a Specified Employee, his/her vested Excess Retirement Benefit shall not commence being paid until after the end of the Specified Employee Required Deferral Period.
 
In the case of any Participant who is a Specified Employee as of the date of a Separation from Service, distribution and payments of any Deferred Compensation may not be made before the date that is six (6) months after the date of Separation from Service (or, if earlier than the end of the six-month period, the date of death of the Specified Employee). For this purpose, a Participant who is not a Specified Employee as of the date of a Separation from Service will not be treated as subject to this requirement even if the Participant would have become a Specified Employee if the Participant had continued to provide services through the next Specified Employee Effective Date; and a Participant who is treated as a Specified Employee as of the date of a Separation from Service will be subject to this requirement even if the Participant would not have been treated as a Specified Employee after the next Specified Employee Effective Date had the Specified Employee continued in employment with the Corporation through the next Specified Employee Effective Date. The required delay in payment is met if payments to which a Specified Employee would otherwise be entitled during the first six (6) months following the date of Separation from Service are accumulated and paid on the first day of the seventh month following the date of Separation from Service, or if each payment to which a Specified Employee is otherwise entitled upon a Separation from Service is delayed by six (6) months. The Committee shall have and retain discretion to choose which method will be implemented, provided that no direct or indirect election as to the method may be provided to the Participant. For an affected Specified Employee, a date upon which the Committee or the Corporation designates that the payment will be made after the six-month delay is treated as a fixed payment date for purposes of the other requirements of the Plan once the Separation from Service has occurred.
 
In such a case, the Part A Participant shall, to the extent permissible under Code Section 409A, receive a Specified Employee Catch-Up Payment at the end of the Specified Employee Required Deferral Period and thereafter receive vested Excess Retirement Benefit monthly payments in accordance with the Plan.  If such a Specified Employee Catch-Up Payment is not permissible under Code Section 409A, the Excess Retirement Benefit shall be paid and distributed to the Specified Employee in accordance with the requirements of Code Section 409A and the regulations thereunder, and the time and form of payment elected shall not otherwise be changed or accelerated.
 
3.4   Vesting of Excess Retirement Benefit . A Part A Participant’s Excess Retirement Benefit shall unconditionally vest in such Participant and become nonforfeitable upon such Part
 

 
- 8 -

 

A Participant’s completion of five (5) Years of Service; provided, that the Excess Retirement Benefit shall not be vested and nonforfeitable upon Retirement if the Part A Participant has not completed five (5) Years of Service.
 
3.5   Form of Payment.    The vested Excess Retirement Benefit shall be paid to a Part A Participant in the form of a 50% qualified joint and survivor annuity, as defined in the Retirement Plan, if such Part A Participant is married on his/her Initial Participation Date as a Part A Participant.  The vested Excess Retirement Benefit shall be paid in the form of a single (straight) life annuity, as defined in the Retirement Plan, if such Part A Participant is unmarried on his/her Initial Participation Date as a Part A Participant.  A Part A Participant shall be allowed to change the form of payment of an Excess Retirement Benefit that is initially elected and designated, or any permissible form previously elected by the Part A Participant hereunder, to the extent provided in this Section 3.5.  Any such change in the form of payment pursuant to this Section 3.5 shall be allowed only if (i) it is made in writing by the Participant in an instrument prescribed by the Committee prior to the first payment and distribution of an Excess Retirement Benefit, (ii) the Committee determines that the previously elected form of payment and the changed form of payment are actuarially equivalent applying reasonable actuarial methods and assumptions, and (iii) the Part A Participant complies with such other requirements as the Committee may prescribe. A change in form of payment pursuant to the foregoing provisions shall not change, delay or accelerate the scheduled date for the first annuity payment of an Excess Retirement Benefit under the Plan. Each change in form of payment of an Excess Retirement Benefit pursuant to the foregoing provisions shall be deemed to make a similar change in the form of payment with respect to any Supplemental Retirement Benefit payable to the Participant under the Plan
 
3.6   Disability .  If a Part A Participant shall become Disabled prior to Retirement and such total disability continues for more than six (6) months, such Participant shall be entitled to receive an Excess Retirement Benefit.  The vested Excess Retirement Benefit of such Part A Participant shall be distributed on the first day of the month next following the time he/she becomes Disabled if he/she has attained age fifty (50) at the time he/she becomes Disabled. The vested Excess Retirement Benefit of such Part A Participant shall be distributed on the first day of the month next following such Part A Participant attaining the age of fifty (50) if he/she becomes Disabled prior to attaining that age. A Part A Participant shall be entitled to make a Subsequent Election with respect to the distribution of a vested Excess Retirement Benefit in accordance with and subject to the provisions of Section 3.2, above.
 
3.7   Death .  In event of the death of a Part A Participant prior to commencing payment of his/her Excess Retirement Benefit under this Plan, , an amount equal to fifty-five percent (55%) of his/her vested Excess Retirement Benefit of such Part A Participant shall be paid and distributed to the Beneficiary of such Part A Participant pursuant to Article IV of this Part A of the Plan, below, on the first day of the month next following the date of death of such Part A Participant.
 
3.8   Nonqualified Deferred Compensation Plan Requirements .  Notwithstanding anything to the contrary expressed or implied herein, the deferral of all Compensation under this Plan shall be subject to the requirements set forth in Article XI, Section 11.1 of Part C of the Plan.
 

 
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ARTICLE IV.                                 
 
BENEFICIARY
 
The Beneficiary of a Part A Participant’s Excess Retirement Benefit shall be the person or persons who would be the beneficiary or beneficiaries entitled to receive the Retirement Plan Benefit of the Part A Participant under the terms and provisions of the Retirement Plan if he/she died prior to the commencement of payment of such Retirement Plan Benefit under the Retirement Plan.
 
ARTICLE V.                                 
 
LEAVE OF ABSENCE
 
If a Part A Participant is authorized by the Company for any reason, including military, medical, or other, to take a leave of absence from employment, such Part A Participant’s participation in Part A of the Plan shall remain in effect.
 
ARTICLE VI.                                 
 
ADMINISTRATION OF PART A OF THE PLAN
 
Except as otherwise expressly provided herein, this Part A of the Plan shall be administered pursuant to the provisions of Part C of the Plan.
 
                     
 

 
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PART B.                        SUPPLEMENTAL RETIREMENT BENEFITS
 
                                
 

 
- 11 -

 

ARTICLE I.                                 
 
PURPOSE AND SCOPE OF PART B
 
1.1   Part B, Supplemental Retirement Benefits .  The provisions of Part B of the Plan shall establish and provide supplemental retirement benefits to employees who are (i) in a select group of management or highly compensated employees of the Company within the meaning of Sections 201(a)(2), 301(a)(3) and 401(a)(1) of ERISA, (ii) Officers of the Company, and (iii) selected to participate in and receive Supplemental Retirement Benefits pursuant to the terms and provisions of this Part B of the Plan.
 
1.2   Separate Benefits .  The Supplemental Retirement Benefits provided to participants under Part B of the Plan are separate and independent from Excess Retirement Benefits provided under Part A of the Plan.
 
1.3   Deferral of Compensation .  The Supplemental Retirement Benefits provided to Participants under Part B of the Plan shall be considered and treated as deferral of compensation to the extent and in the manner provided for in Section 409A of the Code and Treasury Regulations thereunder.
 
ARTICLE II.                                 
 
ELIGIBILITY AND PARTICIPATION
 
2.1   Eligibility for Selection .  In order to be eligible to be selected as a Part B Participant in the Plan, pursuant to Section 2.2 of this Article II, below, an Employee must be an Officer of the Company, who is in a select group of management or highly compensated employees of the Company, as determined by the Chief Executive Officer, or in the case of the Chief Executive Officer, by the Committee, in the Chief Executive Officer’s (or Committee’s, as applicable) sole and absolute discretion.  An eligible Employee/Officer may become a Part B Participant in the Plan only by being selected pursuant to Section 2.2 of this Article II, below.
 
2.2   Designation and Selection of Part B Participants in the Plan .
 
A.   In order to participate in Part B of the Plan an eligible Employee/Officer must be specifically designated and selected by the Chief Executive Officer, or in the case of the Chief Executive Officer, by the Committee, to be a Part B Participant in the Plan, with such designation and selection to be in the Chief Executive Officer’s (or Committee’s, as applicable) sole and absolute discretion.
 
B.   The designation and selection of an eligible Employee/Officer to be a Part B Participant in the Plan by the Chief Executive Officer/Committee shall be confirmed in writing by a written instrument and/or memorandum which shall specify the date that compensation is first deferred under this Plan for such Part B Participant and the date of his/her designation and selection, in such form as is prescribed by the Committee that shall be in substantially the same form as Appendix I to this Plan and that shall be made a part of the records of the Plan and the Company.
 
C.   Not every eligible Employee/Officer is required to be, or necessarily will be designated and selected to be a Part B Participant in the Plan.
 

 
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D.   An eligible Employee/Officer who is not designated and selected to be a Part B Participant in the Plan, pursuant to this Section 2.2, shall not be entitled to any benefit or payment under Part B of the Plan.
 
E.   No Employee/Officer, and who is a participant in the Prior Frozen SERP or entitled to receive any benefit or payment under the Prior Frozen SERP shall be designated and selected to be a Part B Participant in the Plan; and it may be made a condition to the designation and selection of an eligible Employee/Officer to be a Part B Participant that he/she shall have elected in writing to completely terminate his/her participation in the Prior Frozen SERP and waive all his/her entitlement to any benefit or payment under the Prior Frozen SERP.
 
F.   Notwithstanding anything otherwise provided herein, any eligible Employee/Officer who becomes a Part B Participant shall be deemed to consent to and agree that his/her participation in Part B of the Plan shall supersede and cancel any entitlement he/she had to any benefit or payment under the Prior Frozen SERP.
 
2.3   Scope of Part B Participation .  An Employee/Officer designated and selected to be a Part B Participant in the Plan shall as a Part B Participant be entitled solely to the rights and benefits provided under Part B of the Plan, and such designation and selection shall not entitle such Employee/Officer to participate in Part A of the Plan or receive any benefit thereunder; provided, that an Employee/Officer may be designated and selected to be a Part B Participant and designated and selected under Part A of the Plan to be a Part A Participant under the Plan.
 
         2.4   Election to Defer Compensation
 
A.   Except as otherwise provided in Section 2.4.B. of this Article, the Company, pursuant to the Plan, elects, determines and provides for the time and form of payment of a Supplemental Retirement Benefit to any eligible Employee who is designated and selected to be a Part B Participant.  The time and form of payment of a Supplemental Retirement Benefit is stated and provided in Article III of this Part B of the Plan.
 
B.   A Part B Participant shall make a written Election that shall include a Specified Time which shall be the Normal Specified Time of Distribution when his/her Supplemental Retirement Benefit is to be paid and distributed under the Plan. The Specified Time that may be stated in the Election, shall be:
 
(1) The later of (a) a Specified Date, or (b) the date such Part B Participant (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company; or
 
(2) the date such Part B Participant (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company.
 

 
- 13 -

 

The Normal Specified Time of Distribution of a Part B Participant shall in no event be before he/she (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company.
 
C.   The designation and Election of the time and form of payment of the Supplemental Retirement Benefit of an eligible Employee when he/she is first designated and selected to be a Part B Participant in the Plan shall be made and confirmed in writing on or before the date that is thirty (30) days after the date of such designation and selection in an instrument prescribed by the Committee, that shall be in substantially the same form as Appendix I and that shall be made a part of the records of the Plan and the Company.
 
D.   The designation of the time and form of payment of a Supplemental Retirement Benefit of a Part B Participant shall apply with respect to all compensation deferred under the Plan for the selected Part B Participant after the date of his/her designation and selection.  The designation of the time and form of payment of a Supplemental Retirement Benefit of a Part B Participant shall be effective on and after the date that it is made by the Part B Participant and the Company as to compensation deferred under the Plan for all taxable years of the Part B Participant thereafter.
 
E.   The Plan does not provide an eligible Employee or Part B Participant the opportunity to make an initial election of the form of payment of the Supplemental Retirement Benefit to him/her under the Plan.  A Part B Participant shall be allowed to change the form of an annuity benefit to the extent provided in Section 3.5 of Article III of this Part B of the Plan.  A Part B Participant shall be allowed to make a Subsequent Election as to time of payment of an Excess Retirement Benefit as provided in Section 3.2 of Article III of this Part B of the Plan.
 
F.   All Elections made under the Plan by and for a Part B Participant on or before December 31, 2008, shall be retroactively effective to conform to the terms and provisions of the Plan, as amended and restated effective December 18, 2008, to meet the requirements of Code section 409A and Treasury Regulations to the extent allowed under such regulations and published guidance of the Internal Revenue Service.
 
ARTICLE III.                                 
 
SUPPLEMENTAL RETIREMENT BENEFIT
 
3.1   Supplemental Retirement Benefit .
 
A.     The Company shall pay  a monthly Supplemental Retirement Benefit to each Part B Participant which shall be an amount calculated as follows:
 
(1) Calculate a single (straight) life annuity payable at age sixty-five (65) equal to the product of the Part B Participant’s Final Average Earnings, multiplied by the Part B Participant’s Benefit Factor Percentage at his/her Retirement under the Table in Section 3.1.D. of this Article III, below, and then multiplied by the Part B Participant’s Service Factor Percentage at his/her Retirement under the Table in Section 3.1.E. of this Article III, below;
 

 
- 14 -

 

(2) Apply early commencement of payment provisions based upon the age of the Part B Participant when Supplemental Retirement Benefit payments to the Part B Participant commence pursuant to Section 3.1.F. of this Article III, below;
 
(3) Apply the factors for the form of payment that has been elected by the Part B Participant in accordance with the terms and provisions of this Plan as an actuarial equivalent of a single (straight) life annuity, if such elected form of payment is other than a single (straight) life annuity, in accordance with the Plan and reasonable actuarial assumptions and methods, as determined by the Committee; and
 
(4) Deduct the Retirement Plan Benefit pursuant to Section 3.1.G. of this Article III, below, and the Excess Retirement Benefit pursuant to Section 3.1.H. of this Article III, below, calculated at the same time and the form of the Supplemental Retirement Benefit elected under this Plan, irrespective of the time and form of payment of the Retirement Plan Benefit elected by the Participant for the Retirement Plan.
 
B.   The Supplemental Retirement Benefit shall be calculated for the time of the commencement of payment of it to the Part B Participant (hereinafter referred to as the "Supplemental Retirement Benefit Commencement Date") pursuant to the terms and provisions of this Plan governing the time and form of payment thereof, irrespective of whether or not a corresponding Retirement Plan Benefit is then being paid or is to commence payment to such Part B Participant at that time, and irrespective of the time and form of payment of the Retirement Plan Benefit that has been elected, is being paid or may be paid to the Part B Participant.
 
C.   The Committee shall be authorized to take such other actions and apply procedures that it determines, in its discretion, to calculate, determine and commence the payment of a Supplemental Retirement Benefit to a Part B Participant at the Supplemental Retirement Benefit Commencement Date.
 
D.   Benefit Factor Percentage .  A Part B Participant’s Benefit Factor Percentage shall be based upon his/her age at his/her Retirement, as follows:
 
Retirement Age
Benefit Factor
Percentage
50 & under
51
52
53
54
55
56
57
58
59
60
61
50%
51%
52%
53%
54%
55%
56%
57%
58%
58.5%
59%
59.5%
 
 
- 15 -

Retirement Age
Benefit Factor
Percentage
62
63
64
65 & over
60%
60%
60%
60%
 
         E.            Service Factor Percentage .  A Part B Participant’s Service Factor Percentage shall be based upon his/her completed Years of Service at his/her Retirement, as follows:
 
Years of Service
Service Factor Percentage
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20 & over
5%
10%
15%
20%
25%
30%
35%
40%
45%
50%
55%
60%
65%
70%
75%
80%
85%
90%
95%
100%
 
         F.            Adjustment of Retirement Benefit Payments; Early Commencement .  The amount of a Part B Participant’s Supplemental Retirement Benefit payments will be reduced by reason of early commencement of payment thereof, based on the following table depending upon the Part B Participant’s age when Supplemental Retirement Benefit payments to the Part B Participant commence:
 
Part B Participant
Age At Commencement
Early Commencement Reduced
Payout Percentage Factor
Under 50
50
51
0
50%
55%
 
- 16 -

 
Part B Participant
Age At Commencement
Early Commencement Reduced
Payout Percentage Factor
52
53
54
55
56
57
58
59
60
61
62 & over
60%
65%
70%
75%
80%
85%
90%
95%
97%
99%
100%
 
G.   Retirement Plan Benefit Offset .  The Supplemental Retirement Benefit of a Part B Participant shall be offset and reduced by an amount equal to the Retirement Plan Benefit payable to such Part B Participant to be calculated in the same form of payment and as if it is to be paid at the time payment of the Supplemental Retirement Benefit is calculated and made under this Plan.
 
H.   Excess Retirement Benefit Offset .  If a Part B Participant is also a Part A Participant under the Plan and entitled to receive an Excess Retirement Benefit under Part A of the Plan, the Supplemental Retirement Benefit of such Part B Participant shall be offset and reduced by an amount equal to such Excess Retirement Benefit payable to such Part B Participant pursuant to Part A of the Plan.
 
 
3.2   Payment of Supplemental Retirement Benefit .
 
A.   Subject to the requirements of Section 3.3 below (six-month required delay of payment for a Specified Employee), a vested Supplemental Retirement Benefit shall be paid to a Part B Participant entitled thereto or his/her Beneficiary, commencing on his/her Normal Specified Distribution Date.
 
B.   A Part B Participant shall be allowed to make a Subsequent Election to change the time of distribution and payment of his/her Supplemental Retirement Benefit from his/her Normal Specified Distribution Date to a Subsequent Election Distribution Date resulting from such election, if:
 
(i)   he/she delivers a written notification of such Subsequent Election to the Committee, or its designee, in the form it prescribes, not less than twelve (12) months prior to his/her Normal Specified Distribution Date, and
 
(ii)   he/she makes a corresponding Subsequent Election with respect to any Excess Retirement Benefit he/she is entitled to under Part A of the Plan in such written notification.
 

 
- 17 -

 

C.    A Part B Participant shall be allowed to make a Subsequent Election as to any Subsequent Election Distribution Date established for payment of his/her Supplemental Retirement Benefit if:
 
(i)   he/she delivers a written notification of such Subsequent Election to the Committee, or its designee, in the form it prescribes, not less than twelve (12) months prior to such Subsequent Election Distribution Date, and
 
(ii)   he/she makes a corresponding Subsequent Election with respect to any Excess Retirement Benefit he/she is entitled to under Part A of the Plan in such written notification.
 
D.   Notwithstanding anything to the contrary otherwise provided in the Plan or in any Election or Subsequent Election of a Part B Participant, any Subsequent Election made under the Plan shall result in a Subsequent Election Distribution Date of his/her Supplemental Retirement Benefit being established for it, and the first distribution and payment with respect to which such Subsequent Election is made being deferred to a Subsequent Election Distribution Date that is for not less than five (5) years from the date such distribution and payment would otherwise have been made.
 
E.   Except as otherwise expressly specified in the Plan, a distribution or payment shall be treated as made upon the date specified under the Plan if the payment is made at such date or a later date within the same taxable year of the Participant or, if later, by the 15th day of the third calendar month following the date specified under the Plan and the Participant is not permitted, directly or indirectly, to designate the taxable year of the payment. In addition, a distribution or payment shall be treated as made upon the date specified under the Plan and shall not be treated as an accelerated payment if the payment is made no earlier than thirty (30) days before the designated payment date and the Participant is not permitted, directly or indirectly to designate the taxable year of the payment. For purposes of this paragraph, if the date specified is only a designated taxable year of the Participant, or a period of time during such a taxable year, the date specified under the Plan is treated as the first day of such taxable year or the first day of the period of time during such taxable year, as applicable. If calculation of the amount of the distribution or payment is not administratively practicable due to events beyond the control of the Participant (or Participant's beneficiary), the distribution or payment will be treated as made upon the date specified under the Plan if the distribution or payment is made during the first taxable year of the Participant in which the calculation of the amount of the distribution or payment is administratively practicable. For purposes of this section, the inability of a Corporation to calculate the amount or timing of a distribution or payment due to a failure of a Participant (or Participant's beneficiary) to provide reasonably available information necessary to make such calculation does not constitute an event beyond the control of the Participant.
 

 
- 18 -

 

3.3   Specified Employee; Six (6) Month Required Delay in Payment.  If a Part B Participant is a Specified Employee his/her Supplemental Retirement Benefit shall not commence being paid until after the end of the Specified Employee Required Deferral Period.
 
In the case of any Participant who is a Specified Employee as of the date of a Separation from Service, distribution and payments of any Deferred Compensation may not be made before the date that is six (6) months after the date of Separation from Service (or, if earlier than the end of the six-month period, the date of death of the Specified Employee). For this purpose, a Participant who is not a Specified Employee as of the date of a Separation from Service will not be treated as subject to this requirement even if the Participant would have become a Specified Employee if the Participant had continued to provide services through the next Specified Employee Effective Date; and a Participant who is treated as a Specified Employee as of the date of a Separation from Service will be subject to this requirement even if the Participant would not have been treated as a Specified Employee after the next Specified Employee Effective Date had the Specified Employee continued in employment with the Corporation through the next Specified Employee Effective Date. The required delay in payment is met if payments to which a Specified Employee would otherwise be entitled during the first six (6) months following the date of Separation from Service are accumulated and paid on the first day of the seventh month following the date of Separation from Service, or if each payment to which a Specified Employee is otherwise entitled upon a Separation from Service is delayed by six (6) months. The Committee shall have and retain discretion to choose which method will be implemented, provided that no direct or indirect election as to the method may be provided to the Participant. For an affected Specified Employee, a date upon which the Committee or the Corporation designates that the payment will be made after the six-month delay is treated as a fixed payment date for purposes of the other requirements of the Plan once the Separation from Service has occurred.
 
In such a case the Part B Participant shall, to the extent permissible under Code Section 409A, receive a Specified Employee Catch-Up Payment at the end of the Specified Employee Required Deferral Period and thereafter receive vested Supplemental Retirement Benefit monthly payments in accordance with the Plan.  If such a Specified Employee Catch-Up Payment is not permissible under Code Section 409A, the Supplemental Retirement Benefit shall be paid and distributed to the Specified Employee in accordance with the requirements of Code Section 409A and the regulations thereunder, and the time and form of payment elected shall not otherwise be changed or accelerated.
 
3.4   Vesting of Supplemental Retirement Benefit .  Subject to Sections 3.5 and 3.6 of this Article III, below, a Part B Participant’s Supplemental Retirement Benefit shall unconditionally vest in such Part B Participant and become nonforfeitable upon the Part B Participant’s completion of five (5) Years of Service; provided that the Supplemental Retirement Benefit shall not vest in a Part B Participant at the time of, or by reason of his/her Retirement or under any other circumstance if he/she has not completed five (5) Years of Service.
 
3.5   Form of Payment.   The vested Supplemental Retirement Benefit shall be paid to a Part B Participant in the form of a 50% qualified joint and survivor benefit, as defined in the Retirement Plan, if such Part B Participant is married on his/her Initial Participation Date as a Part B Participant.  The vested Supplemental Retirement Benefit shall be paid in the form of a
 

 
- 19 -

 
 
single (straight) life annuity, as defined in the Retirement Plan, if such Part B Participant is unmarried on his/her Initial Participation Date as a Part B Participant.  A Part B Participant shall be allowed to change the form of payment of a Supplemental Retirement Benefit that is initially elected and designated, or any permissible form previously elected by the Part B Participant hereunder, to the extent provided in this Section 3.5.  Any such change in the form of payment pursuant to this Section 3.5 shall be allowed only if (i) it is made in writing by the Part B Participant in an instrument prescribed by the Committee prior to the first payment and distribution of a Supplemental Retirement Benefit, (ii) the Committee determines that the previously elected form of payment and the changed form of payment are actuarially equivalent applying reasonable actuarial methods and assumptions, and (iii) the Part B Participant complies with such other requirements as the Committee may prescribe.  A change in form of payment pursuant to the foregoing provisions shall not change, delay or accelerate the scheduled date for the first annuity payment of a Supplemental Retirement Benefit under the Plan. Each change in form of payment of a Supplemental Retirement Benefit pursuant to the foregoing provisions shall be deemed to make a similar change in form of payment with respect to any Excess Retirement Benefit payable to the Participant under the Plan
 
3.6   Disability.    If a Part B Participant becomes Disabled prior to his/her Separation from Service, the vested Supplemental Retirement Benefit of such Part B Participant shall be distributed on the first day of the month next following the time he/she becomes Disabled if he/she has attained age fifty (50) at the time he/she becomes Disabled. The vested Supplemental Retirement Benefit of such Part B Participant shall be distributed on the first day of the month next following such Part B Participant attaining the age of fifty (50) if he/she becomes Disabled prior to attaining that age. A Part B Participant shall be entitled to make a Subsequent Election with respect to the distribution of a vested Supplemental Retirement Benefit in accordance with and subject to the provisions of Section 3.2, above.
 
3.7   Death . In the event of the death of a Part B Participant prior to commencing payment of his/her Supplemental Retirement Benefit an amount equal to fifty-five percent (55%) of his/her vested Supplemental Retirement Benefit shall be paid and distributed to the Beneficiary of such Part B Participant on the first day of the month next following the date of death of such Part B Participant.
 
3.8   Nonqualified Deferred Compensation Plan Requirements . Notwithstanding anything to the contrary expressed or implied herein, the deferral of all Compensation under this Plan shall be subject to the requirements set forth in Article XI, Section 11.1 of Part C of the Plan.
 
ARTICLE IV.                                 
 
BENEFICIARY
 
The Beneficiary of a Part B Participant’s Supplemental Retirement Benefit shall be the person or persons who would be the beneficiary or beneficiaries entitled to receive the Retirement Plan Benefit of the Part B Participant under the terms and provisions of the Retirement Plan if he/she died prior to the commencement of payment of such Retirement Plan Benefit under the Retirement Plan.
 

 
- 20 -

 

ARTICLE V.                                 
SUPPLEMENTAL RETIREMENT BENEFIT ADJUSTMENTS
 
The Committee shall be authorized to make and apply special adjustments in determining the amount of a Part B Participant’s Supplemental Retirement Benefit.  Such adjustments may be made from time to time by the Committee for any Part B Participant, and may include, without limitation, the granting or deemed accrual of additional Years of Service, the waiver of an offset of retirement benefits provided by a prior employer, or such other adjustments as the Committee determines, in its sole discretion; provided, however, that no such adjustment shall be effective until it is made and expressly acknowledged in writing by the Committee.
 
ARTICLE VI.                                 
LEAVE OF ABSENCE
 
If a Part B Participant is authorized by the Company for any reason, including military, medical, or other, to take a leave of absence from employment, such Part B Participant’s Plan Agreement shall remain in effect.
 
ARTICLE VII.                                 
ADMINISTRATION OF PART B OF THE PLAN
 
Except as otherwise expressly provided herein, this Part B of the Plan shall be administered pursuant to the provisions of Part C of the Plan.
 

 
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PART C.
PLAN ADMINISTRATION AND MISCELLANEOUS PROVISIONS
 
                                   
 

 
- 22 -

 

ARTICLE I.                                 
PURPOSE AND SCOPE OF PART C
 
The purpose of Part C of the Plan is to establish and provide certain provisions governing the administration, and interpretation and application of all the provisions of the Plan.  Unless otherwise expressly indicated, the terms and provisions of Part C of the Plan shall be applicable to Part A, Part B and Part C of the Plan.
 
ARTICLE II.                                 
DEFINITIONS AND CONSTRUCTION
 
2.1   Definitions . For purposes of Parts A, B and C of the Plan, the following phrases or terms shall have the indicated meanings unless otherwise clearly apparent from the context:
 
“Base Cash Compensation” shall mean the regular monthly salary paid to a Participant by the Company before any deductions or exclusions for taxes or other purposes, and excluding any vehicle allowance, incentives, commissions and any other special pay.
 
“Beneficiary” shall mean the individual or individuals entitled to receive any benefits in accordance with the terms of Article IV of Part A, and Article IV of Part B of the Plan, respectively.
 
“Board of Directors” shall mean the Board of Directors of ONEOK, Inc., unless otherwise indicated or the context otherwise requires.
 
“Change in Ownership or  Control” shall mean to the extent provided by Treasury Regulations issued under Code Section 409A, 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.
 
“Chief Executive Officer” shall mean the Chief Executive Officer of the Company.
 
“Code” shall mean the Internal Revenue Code of 1986, as amended.
 
“Committee” shall mean the Executive Compensation Committee of the Board of Directors or such other Committee appointed to manage and administer the Plan and individual Plan Agreements in accordance with the provisions of Article III of this Part C of the Plan.
 
“Company” shall mean ONEOK, Inc., an Oklahoma corporation, or any division or subsidiary thereof.
 
“Compensation” shall mean the Base and Short-Term Incentive Cash Compensation from the Company paid to or deferred by a Participant during a calendar year.
 

 
- 23 -

 

“Deferred Compensation” shall mean any Excess Retirement Benefit or Supplemental Retirement Benefit to be paid to a Participant pursuant to the Plan.
 
“Disabled” shall mean that a Participant is unable to engage in substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or is, by reason of any medically determinable physical or mental impairment which can be expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident or health plan covering Employees of the Company.
 
“Effective Date” shall mean the effective date of the Plan, January 1, 2005.
 
“Election” shall mean the initial Election of a Participant or by the Company to defer payment and distribution of Deferred Compensation to a Participant made pursuant to the terms and provisions of the Plan, that shall include the Participant's Election of the time of payment and the Company's Election of the form of payment.
 
“Election Date” shall mean the date of the Election by the Participant and the Company to defer compensation under the Plan for an eligible Employee who is a Part A Participant or a Part B Participant, that is made or deemed made pursuant to the terms of the Plan.
 
“Employee” shall mean any person who is in the regular full-time employment of the Company or is on authorized leave of absence therefrom, as determined by the personnel rules and practices of the Company.  The term does not include persons who are retained by the Company solely as consultants or under contract.
 
“ERISA” shall mean the Employee Retirement Income Security Act of 1974, as amended.
 
“Excess Retirement Benefit” shall mean an amount equal to the difference between (i) the Retirement Plan Benefit to which the Part A Participant would be entitled under the Retirement Plan if such Retirement Plan Benefit was computed without the restrictions or limitations imposed by Sections 401(a)(17) and 415(b) of the Code as now or hereafter in effect, less (ii) the amount of Retirement Plan Benefit payable to the Part A Participant under the Retirement Plan.
 
“Final Average Earnings” shall mean the average of the highest thirty-six (36) consecutive months Compensation during the last sixty (60) month period of an Employee’s employment with the Company.
 
“Fixed Schedule” shall mean the distribution or payment of compensation deferred under the Plan in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such Compensation is first elected by the Participant.
 

 
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“Initial Participation Date” shall mean the date an Employee or Officer first becomes a Part A Participant and/or Part B Participant in the Plan.
 
”Normal Specified Distribution Date” shall mean as to a Part A Participant or Part B Participant, the first day of the calendar month next following or coincident with the later of the date the Participant has elected in his/her Election the Specified Time of payment and distribution of compensation deferred under the Plan which shall be either (1) the later of (a) a Specified Date, or (b) the date such Part A Participant (i) attains age fifty (50), (ii) completes five (5) years of service with the Company, and (iii) has a Separation from Service with the Company; or (2) the date such Part A Participant (a) attains age fifty (50), (b) completes five (5) years of service with the Company, and (c) has a Separation from Service with the Company.
 
“Officer” shall mean a person who is an elected officer of the Company.
 
“Part A Participant” shall mean an Employee who is selected and elects to participate in Part A of the Plan in accordance with the provisions of Article II of Part A of the Plan.
 
“Part B Participant” shall mean an Employee who is selected and elects to participate in Part B of the Plan in accordance with the provisions of Article II of Part B of the Plan.
 
“Performance-Based Compensation” shall mean Compensation that is conditioned upon or subject to meeting certain requirements similar to those under Code Section 162(m), as more particularly provided for in Treasury Regulations issued under Code Section 409A.
 
“Plan Agreement” shall mean a form of written agreement which is entered into by and between the Company and an Employee selected to become a Participant as a condition to participation in the Plan as provided in Sections 2.2 and 2.4 of Article II of Part B of the Plan.
 
“Plan” shall mean this ONEOK, Inc. 2005 Supplemental Executive Retirement Plan as embodied herein and as amended from time to time.
 
“Prior Frozen SERP” shall mean the separate preexisting ONEOK, Inc. Supplemental Executive Retirement Plan, terminated and frozen by the Board of Directors effective December 31, 2004.
 
“Rabbi Trust” shall mean the trust created to hold assets which will be used to pay the benefits provided hereunder, as provided in Section 5.4 of Article V of this Part C of the Plan.
 
“Retirement” and “Retire” shall mean when Participant attains age fifty (50), completes five (5) years of service with the Company, and has a Separation from Service from the Company other than Separation from Service as a result of death of the Employee, irrespective of whether or not the Employee is considered to have retired
 

 
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under the Retirement Plan or for any other purpose at the time of  his/her termination of employment with the Company.
 
 “Retirement Plan” shall mean the Retirement Plan for Employees of ONEOK, Inc. and Subsidiaries.
 
“Retirement Plan Benefit” shall mean the benefit or benefits to which a Part A and/or Part B Participant is entitled under the Retirement Plan.
 
“Retirement Plan Benefit Commencement Date” means the date a Participant commences receiving payments of his/her Retirement Benefits under the Retirement Plan.
 
“Separation from Service” shall mean the termination of a Participant’s employment with the Company.
 
 “Service” shall mean employment of a Participant by the Company as a regular full-time employee.
 
“Short-Term Incentive Cash Compensation” shall mean any payment by the Company under the ONEOK, Inc. Annual Employee Incentive Plan or the ONEOK, Inc. Annual Officer Incentive Plan.
 
“Specified Date” means a specific future date in a calendar year.
 
“Specified Employee” shall mean an Employee who, as of the date of the Employee's separation from service, is a key employee of the Company if any stock of the Company is then publicly traded on an established securities market or otherwise; and for purposes of this definition, an Employee is a key employee if the Employee meets the requirements of Code Section 416(i)(1)(A)(i), (ii), or (iii) (applied in accordance with the regulations thereunder and disregarding section 416(i)(5)) at any time during the 12-month period ending on a Specified Employee Identification Date. If an Employee is a key employee as of a Specified Employee Identification Date, the Employee shall be treated as a key employee for purposes of the Plan for the entire 12-month period beginning on the Specified Employee Effective Date. For purposes of identifying a Specified Employee by applying the requirements of section 416(i)(1)(A)(i), (ii), and (iii), the definition of compensation under §1.415(c)-2(a) shall be used, applied as if the Company were not using any safe harbor provided in §1.415(c)-2(d), were not using any of the elective special timing rules provided in §1.415(c)-2(e), and were not using any of the elective special rules provided in §1.415(c)-2(g).
 
“Specified Employee Catch-Up Payment” shall mean a lump sum payment equal to all regularly scheduled Excess Retirement Benefit and/or Supplemental Retirement Benefit monthly payments to which a Part A Participant or Part B Participant is entitled to under the Plan but which are not paid on and after the commencement of payment of his/her Retirement Plan Benefit because of a Key Employee Required Deferral Period.
 

 
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“Specified Employee Effective Date” means the first day of the fourth month following the Specified Employee Identification Date.
 
“Specified Employee Identification Date” means December 31.
 
“Specified Employee Required Deferral Period” shall mean the deferral of payment and distribution of an Excess Retirement Benefit or a Supplemental Retirement Benefit with respect to a Part A Participant or Part B Participant, respectively, until a date which is six (6) months after the date of the Separation from Service of such Participant.
 
In the case of any Participant who is a Specified Employee as of the date of a Separation from Service, distribution and payments of any Deferred Compensation may not be made before the date that is six (6) months after the date of Separation from Service (or, if earlier than the end of the six-month period, the date of death of the Specified Employee). For this purpose, a Participant who is not a Specified Employee as of the date of a Separation from Service will not be treated as subject to this requirement even if the Participant would have become a Specified Employee if the Participant had continued to provide services through the next Specified Employee Effective Date; and a Participant who is treated as a Specified Employee as of the date of a Separation from Service will be subject to this requirement even if the Participant would not have been treated as a Specified Employee after the next Specified Employee Effective Date had the Specified Employee continued in employment with the Corporation through the next Specified Employee Effective Date. The required delay in payment is met if payments to which a Specified Employee would otherwise be entitled during the first six (6) months following the date of Separation from Service are accumulated and paid on the first day of the seventh month following the date of Separation from Service, or if each payment to which a Specified Employee is otherwise entitled upon a Separation from Service is delayed by six (6) months. The Committee shall have and retain discretion to choose which method will be implemented, provided that no direct or indirect election as to the method may be provided to the Participant. For an affected Specified Employee, a date upon which the Committee or the Corporation designates that the payment will be made after the six-month delay is treated as a fixed payment date for purposes of the other requirements of the Plan once the Separation from Service has occurred.
 
“Specified Time” shall mean a specified date at which Deferred Compensation deferred by or for a Participant pursuant to the Plan is required to be distributed or paid and which is specified at the time the Election of deferral of such Deferred Compensation.
 
“Subsequent Election” shall mean an irrevocable written election made by a Participant to change the time of distribution or payment of Deferred Compensation deferred under the Plan that is made at any time after the initial Election with respect to such Deferred Compensation, or after a prior Subsequent Election.  Provided, that a change in a form of payment before a life annuity payment has been made under the Plan, from one type of life annuity to another type of life annuity with the same scheduled date of the first annuity payment shall not be considered as a change in the time and form of
 

 
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payment constituting a Subsequent Election if the annuities are actuarially equivalent, and such change is allowed as contemplated in Treasury Regulations §1.409A-2(b)(ii).
 
A Subsequent Election may be made and effective under the Plan only if the following conditions are met:
 
(i)   Such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made in order for it to be considered valid;
 
(ii)   Except in the case of an election permitted under Section 409A and the Treasury Regulations §1.409A-3(a)(2) (payment on account of disability), § 1.409A-3(a)(3) (payment on account of death), or §1.409A-3(a)(6) (payment on account of the occurrence of an unforeseeable emergency), the payment with respect to which such Subsequent Election shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been paid (or in the case of a life annuity or installment payments treated as a single payment, five (5) years from the date the first amount was scheduled to be paid); and
 
(iii)   Any Subsequent Election related to a payment described in Treasury Regulations §1.409A-3(a)(4) (payment at a specified time or pursuant to a fixed schedule) shall be made not less than twelve (12) months before the date the payment is scheduled to be paid (or in the case of a life annuity or installment payments treated as a single payment, twelve (12) months before the date the first amount was scheduled to be paid)..
 
“Subsequent Election Distribution Date” shall mean with respect to a Part A Participant or Part B Participant, the first day of the calendar month next following or coincident with the first date on or after Subsequent Election Specified Time on which the Participant (i) has a Separation from Service with the Company, (ii) has attained age fifty (50), and (iii) has completed five (5) years of service with the Company.
 
"Subsequent Election Specified Time" shall mean a specified fixed date in a calendar year that must be specified in writing by the Participant in a Subsequent Election that is not less than five (5) years from the date payment would otherwise have been made to the Participant. The written specification of the then applicable Specified Time or Subsequent Election Specified Time shall in all cases specify and fix a Subsequent Election Specified Time that is not less than five (5) years from the then applicable  Specified Time or Subsequent Election Specified Time,  as the case may be, that has been elected and is in effect under the Plan.
 
 “Supplemental Retirement Benefit” shall mean the supplemental retirement benefit to be paid to a Part B Participant pursuant to Article III and other applicable provisions of Part B of the Plan.
 

 
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 “Unforeseeable Emergency” shall mean a severe financial hardship to the Participant resulting from illness or accident of the Participant, the Participant’s spouse, or a dependent (as defined in Code Section 152(a)) of the Participant, loss of the Participant’s property due to casualty, or other similar extraordinary circumstances arising as a result of events beyond the control of the Participant, and it is intended and directed with respect to any such Unforeseeable Emergency that any amounts distributed under the Plan by reason thereof shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participant’s assets (to the extent the liquidation of such assets would not itself cause severe financial hardship.
 
“Years of Service” shall include each full year, but not any portion of a year, during which the Participant has been employed by the Company or any division or subsidiary thereof.
 
2.2   Construction .  The singular when used herein may include the plural unless the context clearly indicates to the contrary.  The words “hereof”, “herein”, “hereunder”, and other similar compounds of the word “here” shall mean and refer to the entire Plan and not to any particular provision or section.  Whenever the words “Article” or “Section” are used in the Plan, or a cross reference to an “Article” or “Section” is made, the Article or Section referred to shall be an Article or Section of the same Part of the Plan unless otherwise specified.
 
2.3   Plan Purpose . The Plan is intended to be an unfunded deferred compensation, excess and supplemental retirement benefit plan established and maintained for a select group of management and highly compensated employees of the Company within the meaning of Sections 201(2) and (7), 301(a)(3), (9) and 401(a)(1) of ERISA, as provided under the respective provisions of Part A and Part B of the Plan, and the Company intends that any Participant or Beneficiary shall have the status of an unsecured creditor as to the Plan or any trust, fund or other arrangement established under or with respect to the Plan, and the Plan shall be construed, interpreted and administered in accordance with such intended purpose.
ARTICLE III.                                 
COMMITTEE
 
3.1   Appointment of Committee . The general administration of the Plan, including all provisions of Part A and Part B of the Plan, and any Plan Agreements executed hereunder, as well as construction and interpretation thereof, shall be vested in the Committee, the number and members of which shall be designated and appointed from time to time by, and shall serve at the pleasure of, the Board of Directors.  Any such member of the Committee may resign by notice in writing filed with the Board of Directors.  Vacancies shall be filled promptly by the Board of Directors.
 
3.2   Committee Officials . The Board of Directors may designate one of the members of the Committee as Chairman and may appoint a secretary who need not be a member of the Committee.  The secretary shall keep minutes of the Committee’s proceedings and all data,
 

 
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records, and documents relating to the Committee’s administration of the Plan and any Plan Agreements executed hereunder. The Committee may appoint from its number such subcommittees with such powers as the Committee shall determine.  The Committee may authorize one or more of its members, or any other person as agent of the Committee to execute or deliver any instrument, make any payment on behalf of the Committee, or otherwise act for and on behalf of the Committee with respect to the Plan.
 
3.3   Committee Action . All resolutions or other actions taken by the Committee shall be by the vote of a majority of those present at a meeting at which a majority of the members are present, or in writing by all the members at the time in office if they act without a meeting.
 
3.4   Committee Rules and Powers . Subject to the provisions of the Plan, the Committee may from time to time establish rules, forms, and procedures for the administration of the Plan, including Plan Agreements. Except as herein otherwise expressly provided, the Committee shall have the exclusive right to interpret the Plan and any Plan Agreements, and to decide any and all matters arising thereunder or in connection with the administration of the Plan and any Plan Agreements, and it shall endeavor to act, whether by general rules or by particular decisions, so as not to discriminate in favor of or against any person. The Committee shall have the exclusive right to determine if a Participant has become Disabled with respect to a Participant (consistent with the Plan’s definition of the term), such determinations to be made on the basis of such medical and/or other evidence that the Committee, in its sole and absolute discretion, may require.  Such decisions, actions, and records of the Committee shall be conclusive and binding upon the Company, the Participants, and all persons having or claiming to have rights or interests in or under the Plan.
 
3.5   Reliance on Certificates, etc.   The members of the Committee and the Officers and Directors of the Company shall be entitled to rely on all certificates and reports made by any duly appointed accountants, and on all opinions given by any duly appointed legal counsel.  Such legal counsel may be counsel for the Company.
 
3.6   Liability of Committee .  No member of the Committee shall be liable for any act or omission of any other member of the Committee, or for any act or omission on his part, excepting only his own willful misconduct. The Company shall indemnify and save harmless each member of the Committee against any and all expenses and liabilities arising out of membership on the Committee, excepting only expenses and liabilities arising out of a Committee member’s own willful misconduct. Expenses against which a member of the Committee shall be indemnified hereunder shall include, without limitation, the amount of any settlement or judgment, costs, counsel fees, and related charges reasonably incurred in connection with a claim asserted, or a proceeding brought, or settlement thereof.  The foregoing right of indemnification shall be in addition to any other rights to which any such member may be entitled.
 
3.7   Determination of Benefits . In addition to the powers hereinabove specified, the Committee shall have the power to compute and certify, under the Plan and/or any Plan Agreement, the amount and kind of benefits from time to time payable to Participants and their Beneficiaries, and to authorize all disbursements for such purposes.
 

 
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3.8   Information to Committee . To enable the Committee to perform its functions, the Company shall supply full and timely information to the Committee on all matters relating to the compensation of all Participants, their retirement, death, or other cause for termination of employment, and such other pertinent facts as the Committee may require.
 
ARTICLE IV.
 
ADOPTION OF PLAN BY SUBSIDIARY,
 
AFFILIATED OR ASSOCIATED COMPANIES
 
Any corporation which is a subsidiary of the Company may, with the approval of the Board of Directors, adopt the Plan and thereby come within the definition of Company in Article I of Part C of the Plan.
 
ARTICLE V.                                 
SOURCE OF BENEFITS
 
5.1   Benefits Payable . Excess Retirement Benefits and Supplemental Retirement Benefits payable hereunder shall be paid exclusively from the general assets of the Company or the Rabbi Trust to be established pursuant to Section 5.4 of this Article V; provided, that no person entitled to payment hereunder shall have any claim, right, security interest, or other interest in any fund, trust, account, insurance contract, or asset of the Company which may be looked to for such payment.  The Company’s liability for the payment of benefits hereunder shall be evidenced only by the Plan and each Plan Agreement entered into between the Company and a Participant.
 
5.2   Investments to Facilitate Payment of Benefits . Although the Company is not obligated to invest in any specific asset or fund, or purchase any insurance contract, in order to provide the means for the payment of any Excess Retirement Benefits and Supplemental Retirement Benefits under the Plan, the Company may elect to do so, and, in such event, no Participant shall have any interest whatever in such asset, fund, or insurance contract.  In the event the Company elects to purchase or causes to be purchased insurance contracts on the life of a Participant as a means for making, offsetting, or contributing to any payment, in full or in part, which may become due and payable by the Company under the Plan or a Participant’s Plan Agreement, such Participant agrees to cooperate in the securing of life insurance on his/her life by furnishing such information as the Company and the insurance carrier may require, including the results and reports of previous Company and other insurance carrier physical examinations as may be requested, and taking any other action which may be requested by the Company and the insurance carrier to obtain such insurance coverage.  If a Participant does not cooperate in the securing of such life insurance, the Company shall have no further obligation to such Participant under the Plan.
 
5.3   Ownership of Insurance Contracts . The Company shall be the sole owner of any insurance contracts acquired on the life of a Participant with all incidents of ownership therein, including, but not limited to, the right to cash and loan values, dividends, if any, death benefits, and the right to termination thereof, and a Participant shall have no interest whatsoever in such contracts, if any, and shall exercise none of the incidents of ownership thereof.  Provided, however, the Company may assign any such insurance contracts to the trustee of the Rabbi Trust.
 

 
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5.4     Trust for Payment of Benefits . The Company shall create or utilize a Rabbi Trust for the purpose of facilitating any retirement benefits payable hereunder.  Such trust will be funded to provide the applicable vested Excess Retirement Benefits and Supplemental Retirement Benefits payable under the Plan upon the occurrence of any of the following events:
 
a)           At the Retirement of, and commencement of payment of an Excess Retirement Benefit or a Supplemental Retirement Benefit to a Plan Participant;
 
b)           Upon a decision by the Committee, or by the Board of Directors; or
 
c)           Upon a Change in Ownership or Control.
 
Such funding may be in the form of single premium annuities, or an amount sufficient for the trustee to purchase single premium annuities, or life insurance policies or contracts insuring the lives of Participants, as the case may be, from qualified and financially sound insurance companies, and such other forms or types of investments the Company may select from time to time to provide the applicable vested Excess Retirement Benefits and Supplemental Retirement Benefits payable under the Plan and Plan Agreements.  Such funding and the purchase of insurance, if any, will not relieve the Company of its obligations to pay or cause to be paid the benefits hereunder.
 
The Rabbi Trust may be maintained and administered to also provide for the funding of payment of amounts payable to participants in other deferred compensation and benefit plans of the Company.  The funding, investments and administration of the Rabbi Trust in connection with such other separate plan or plans shall be separately administered and accounted for as determined to be necessary and appropriate by the Company and trustee pursuant to the terms of the Rabbi Trust.  It shall be permissible for the trustee to invest funds of the Rabbi Trust in one or more forms of investment that is common to plans being funded thereunder.
 
The Rabbi Trust shall be a grantor trust of which the Company is the grantor within the meaning of the Code.  The principal of the Rabbi Trust held and administered for providing payments under this Plan, or any share thereof so held and administered, and any earnings thereon, shall be held separate and apart from other funds of the Company and shall be used exclusively for the uses and purposes of Part A Participants and/or Part B Participants in the Plan and general creditors of the Company as specified herein below and in the trust instrument.  Part A Participants and Part B Participants in the Plan and their Beneficiaries shall have no preferred claim on, or any beneficial ownership in any assets of the Rabbi Trust; and any rights created under the Plan or any Plan Agreements, and the Rabbi Trust are to be made unsecured contractual rights of Part A Participants and Part B Participants (and their Beneficiaries, if applicable) against the Company; and assets held by the Rabbi Trust will be subject to the claims of the Company’s general creditors under federal and state law in the event of insolvency of the Company.
 
ARTICLE VI.                                 
TERMINATION OF EMPLOYMENT
 
Neither the Plan nor any Plan Agreement with a Participant hereunder, either singly or collectively, in any way obligate the Company, or any subsidiary of the Company, to continue
 

 
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the employment of a Part A Participant or a Part B Participant with the Company, or any subsidiary of the Company, nor does either limit the right of the Company or any subsidiary of the Company at any time and for any reason to terminate such Part A Participant’s or Part B Participant’s employment.  Termination of a Part A Participant’s or Part B Participant’s employment with the Company, or any subsidiary of the Company, for any reason, whether by action of the Company, subsidiary, or such a Part A Participant or Part B Participant, shall immediately terminate such Participant’s participation in the Plan and any such Participant’s Plan Agreement, and all further obligations of either party thereunder, except as may be provided in Article VIII of this Part C, and the Participant’s Plan Agreement.  In no event shall the Plan or a Plan Agreement, either singly or collectively, by their terms or implications constitute an employment contract of any nature whatsoever between the Company, or any subsidiary, and a Part A Participant or Part B Participant.
 
ARTICLE VII.                                 
TERMINATION OF PARTICIPATION
 
A Part A Participant and a Part B Participant reserves the right to terminate participation in the Plan and any such Participant’s Plan Agreement at any time by giving the Company written notice of such termination not less than 30 days (i) prior to the anniversary date of any contract or contracts of insurance on the life of such Part A Participant or Part B Participant which may be in force and utilized by the Company in connection with the Plan, or (ii) prior to the date a Part A Participant or Part B Participant selects for termination if no insurance contract is in effect.
 
ARTICLE VIII.                                            
TERMINATION, AMENDMENT, MODIFICATION,
OR SUPPLEMENT OF THE PLAN
 
8.1      Amendment or Termination . Subject to Section 8.2, below, the Company reserves the right to amend, modify, supplement, or terminate the Plan, wholly or partially, from time to time, and at any time.  The Company likewise reserves the right to amend, modify, or supplement any written instrument made or delivered with respect to the administration of the Plan, or any Plan Agreement, wholly or partially, from time to time.  Such right to amend, modify, supplement, or terminate the Plan or any Plan Agreement, as the case may be, shall be exercised for the Company by the Board of Directors; provided , that the Committee shall also be authorized to amend or modify the terms and provisions of the Plan, or such a written instrument or Plan Agreement, except that any amendment or modification of the Plan or Plan Agreement that changes the form or amount of any payment or benefit provided for under the Plan shall be made only by action of the Board of Directors;   provided , further , in the event of a Change in Ownership or Control of the Company, for a period of two (2) years after the date of such Change of Ownership or Control the surviving corporation may terminate or amend the Plan only by substitution by such corporation of another plan or program, or by amendments to the Plan, which provide benefits no less favorable to the Part A Participants or Part B Participants of this Plan; and upon the expiration of such two (2) year period such surviving corporation may thereafter terminate or amend the Plan or any such substituted plan subject in any case to Section 8.2, below.
 

 
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8.2      Rights and Obligations Upon Amendment, Termination .  The following terms and conditions shall govern the rights and obligations of a Part A Participant or Part B Participant and the Company (including any surviving corporation in event of a Change of Ownership or Control), respectively, with respect to the amendment or termination of the Plan.
 
A.   Notwithstanding anything to the contrary expressed or provided in the Plan or any Plan Agreement of a Part A Participant or Part B Participant, no amendment, modification or termination of the Plan, shall decrease a Part A Participant’s or Part B Participant’s accrued Excess Retirement Benefit or Supplemental Retirement Benefit, as applicable.  For purposes of this Paragraph A., a Plan amendment which has the effect of decreasing a Part A Participant’s or Part B Participant’s accrued Excess Retirement Benefit or Supplemental Retirement Benefit, as the case may be, or eliminating any optional form of payment of a Participant’s accrued Excess Retirement Benefit or Supplemental Retirement Benefit, with respect to benefits attributable to service before the amendment shall be treated as reducing an accrued Excess Retirement Benefit or Supplemental Retirement Benefit. If a vesting schedule under the Plan or any Plan Agreement is amended, a Part A Participant’s and Part B Participant’s non-forfeitable percentage, determined as of the later of the date such amendment is adopted or the date it becomes effective, will not be less than the percentage computed under Part A and Part B of the Plan and Plan Agreements, as applicable, without regard to such amendment.
 
B.   Except as provided in paragraph A of this Section 8.2, upon the termination of the Plan by the Board of Directors, or a termination of the Plan Agreement of a Participant, in accordance with the provisions for such termination, neither the Plan nor the Plan Agreement shall be of any further force or effect, and no party shall have any further obligation under either the Plan or any Plan Agreement so terminated, except as provided in the Plan or Plan Agreement with respect to accrued benefits at the time of such termination or as elsewhere provided in the Plan.
 
C.   For purposes of paragraphs A and B of this Section 8.2, the term “Plan” shall also mean and include any substituted plan that may be established in event of a Change of Ownership or Control as described in Section 8.1, above, and the terms “Excess Retirement Benefit” and “Supplemental Retirement Benefit” shall also mean and include any benefit provided for under such a substituted plan.
 
ARTICLE IX.                                 
TREATMENT OF BENEFITS
 
The Excess Retirement Benefit provided for a Part A Participant and the Supplemental Retirement Benefit provided for a Part B Participant under the Plan and/or under any Plan Agreement are in addition to any other benefits available to such Participant under any other Plan, plan or agreement of the Company for its Employees and the Participants, and, except as may be otherwise expressly provided for, the Plan and Plan Agreements entered into hereunder shall supplement and shall not supersede, modify, or amend any other Plan, plan or agreement of the Company.  The Excess Retirement Benefits and Supplemental Retirement Benefits under the Plan and/or Plan Agreements entered into hereunder shall not be considered compensation for
 

 
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the purpose of computing contributions or benefits under any plan maintained by the Company, or any of its subsidiaries, which is qualified under Section 401(a) of the Code.
 
ARTICLE X.                                 
RESTRICTIONS ON ALIENATION OF BENEFITS
 
No Excess Retirement Benefit or Supplemental Retirement Benefit under the Plan or a Plan Agreement shall be subject to anticipation, alienation, sale, assignment, pledge, encumbrance, or charge, and any attempt to anticipate, alienate, sell, assign, pledge, encumber, or charge the same shall be void.  No Excess Retirement Benefit and Supplemental Retirement Benefit under the Plan or under any Plan Agreement shall in any manner be liable for or subject to the debts, contracts, liabilities, or torts of the person entitled to such thereto.  If any Part A Participant or Part B Participant under the Plan or a Plan Agreement should become bankrupt or attempt to anticipate, alienate, sell, assign, pledge, encumber, or charge any right to a benefit under the Plan or under any Plan Agreement, then such right or benefit shall, in the discretion of the Committee, cease, and in such event, the Committee may, but shall have no duty to hold or apply the same or any part thereof for the benefit of such Part A Participant or Part B Participant, or his/her Beneficiary, in such portion as the Committee, in its sole and absolute discretion, may deem proper.
 
ARTICLE XI.                                 
MISCELLANEOUS
 
11.1      Deferral of Compensation Requirements . The following requirements stated in this Section 11.1 shall apply to the Plan, to all Elections or Subsequent Elections made by Participants under the Plan, and to all distributions and payments made pursuant to the Plan.
 
A.   Any Compensation deferred under the Plan shall not be distributed earlier than:
 
(i)   Separation from Service of the Participant,
 
(ii)   the date the Participant becomes Disabled,
 
(iii)   death of the Participant,
 
(iv)   a Specified Time (or pursuant to a Fixed Schedule) specified under the Plan at the date of deferral of such Compensation,
 
(v)   a Change in Ownership or Control, or
 
(vi)   the occurrence of an Unforeseeable Emergency.
 
B.   Notwithstanding the foregoing, in the case of a Participant who is a Specified Employee, no distribution shall be made before the date which is six (6) months after the date of the Participant’s Separation from Service, or, if earlier, the date of death of such Participant.
 

 
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C.   No acceleration of the time or schedule of any distribution or payment under the Plan shall be permitted or allowed, except to the extent provided in Treasury Regulations issued under Code Section 409A.
 
If the Plan, or the Committee acting pursuant to the Plan, permits under any Subsequent Election by a Participant a delay in a payment or a change in the form of payment of Compensation deferred under the Plan, such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made.  In the case of a Subsequent Election related to a payment to be made upon Separation from Service of a Participant, at a Specified Time or pursuant to a Fixed Schedule, or upon a Change in Ownership or Control, the first payment with respect to which such Subsequent Election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such Subsequent Election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.
 
11.2      Execution of Receipts and Releases .  Any payment to a Participant, a Participant’s legal representative, or Beneficiary in accordance with the provisions of the Plan or any Plan Agreement executed hereunder shall, to the extent thereof, be in full satisfaction of all claims hereunder against the Company.  The Company may require such Participant, legal representative, or Beneficiary, as a condition precedent to such payment, to execute a receipt and release therefore in such form as it may determine.
 
11.3      No Guarantee of Interests .  Neither the Committee nor any of its members guarantees the payment of any amounts which may be or becomes due to any person or entity under the Plan or any Plan Agreement executed hereunder.  The liability of the Company to make any payment under the Plan or any Plan Agreement executed hereunder is limited to the then available assets of the Company and the Rabbi Trust established under Section 5.4 of this Part C.
 
11.4      Company Records .  Records of the Company as to a Participant’s employment, termination of employment and the reason therefore, reemployment, authorized leaves of absence, and compensation shall be conclusive on all persons and entities, unless determined to be incorrect.
 
11.5      Evidence .  Evidence required of anyone under the Plan and any Plan Agreement executed hereunder may be by certificate, affidavit, document, or other information which the person or entity acting on it considers pertinent and reliable, and signed, made, or presented by the proper party or parties.
 
11.6      Notice . Any notice which shall be or may be given under the Plan or a Plan Agreement executed hereunder shall be in writing and shall be mailed by United States mail, postage prepaid.  If notice is to be given to the Company, such notice shall be addressed to the Company at:
 
100 West Fifth Street
 
Tulsa, Oklahoma 74103
 

 
- 36 -

 

and marked to the attention of the Secretary, Executive Compensation Committee; or, if notice to a Participant, addressed to the address shown on such Participant’s most recent employment file with the Company.
 
11.7      Change of Address .  Any party may, from time to time, change the address to which notices shall be mailed by giving written notice of such new address.
 
11.8      Effect of Provisions .  The provisions of the Plan and of any Plan Agreement executed hereunder shall be binding upon the Company and its successors and assigns, and upon a Participant, the Participant’s Beneficiary, assigns, heirs, executors, and administrators.
 
11.9      Headings .  The titles and headings of Articles and Sections are included for convenience of reference only and are not to be considered in the construction of the provisions hereof or any Plan Agreement executed hereunder.
 
11.10         Governing Law .  All questions arising with respect to the Plan and any Plan Agreement executed hereunder shall be determined by reference to the laws of the State of Oklahoma in effect at the time of their adopting and execution, respectively.
 
11.11         Effective Date .  Except to the extent explicitly stated otherwise herein, the terms and provisions of this amended and restated Plan shall be effective December 18, 2008.
 
 
ONEOK, Inc.
 
                                                     By:                                                                      
 
____________________
 


 
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APPENDIX I
 
ONEOK, Inc. 2005 Supplemental Executive Retirement Plan

DESIGNATION AND ELECTION OF AND FOR  PARTICIPANT AND PARTICIPATION AGREEMENT

(PLEASE PRINT OR TYPE) Mail to: ONEOK, Inc., Attn: David Roth, Mail Drop 18-48, P.O. Box 871, Tulsa, OK 74102

PARTICIPANT INFORMATION

Name: ___________________            Employee No._______________________

SERP Part A & B Participant Commencement Date ____________________

Marital Status at Part A & B Participant Commencement Date _________________

PART I - DETERMINATION OF ELIGIBILITY AND DESIGNATION AND SELECTION OF EMPLOYEE TO BE PARTICIPANT

__________________________(“Participant”) is hereby determined to be in a select group of management or highly compensated employees of the Company, who is eligible to become and is selected to be as a Participant in the ONEOK, Inc. 2005 Supplemental Executive Retirement Plan (Plan), effective _____________, 200___.

___________________________ is hereby designated to be a Part A Participant in the Plan.
___________________________ is hereby designated to be a Part B Participant in the Plan.

This determination and selection is made pursuant to Sections 2.1 and 2.2 of Article II, Part A of the Plan and Sections 2.1 and 2.2 of Article II of Part B of the Plan.

Except as otherwise provided in this instrument and the Plan with respect to the Participant's election of a Specified Time for his/her Normal Specified Distribution Date, the time and form of payment shall be elected and determined under the Plan and by the Company as confirmed by this instrument.

Pursuant to Section 2.4 of Article II, Part A of the Plan, Participant, as a designated Part A Participant in the Plan is determined to be entitled to and shall be paid an Excess Retirement Benefit at his/her Normal Specified Time of Distribution, as provided for under the Plan. Pursuant to Section 2.4 of Article II, Part B of the Plan, Participant, as a designated Part B Participant in the Plan is determined to be entitled to and shall be paid a Supplemental Retirement Benefit at his/her Normal Specified Time of Distribution, as provided for under the Plan.

The time and form of payment designated by or for the Participant shall be effective on the date of this instrument and shall be as provided for in Article III of Part A of the Plan for the Excess

 
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Retirement Benefit, and as provided for in Article III of Part B of the Plan for the Supplemental Retirement Benefit.

This determination and deferral of compensation under the Plan shall apply with respect to compensation to the deferred by or to the selected Participant on and after the date of this instrument.

Date:                      ______________________              ____________________________
                                               John W. Gibson
                                                                    Chief Executive Officer
ONEOK, Inc.



PART II - ELECTION AND PARTICIPATION AGREEMENT

SECTION 1: BACKGROUND AND INSTRUCTIONS

Time of Payment of SERP Benefit

The ONEOK, Inc. 2005 Supplement Executive Retirement Plan (“SERP" or the “Plan”), as amended,  provides that the Excess Retirement Benefit that you accrue as a Part A Participant and Supplemental Retirement Benefit that you accrue as a Part B Participant will be paid and distributed to you at your Normal Specified Distribution Date.  

Your Normal Specified Distribution Date is the later of (1) the Specified Time (specified calendar date) you elect to receive payment and distribution of the Excess Retirement Benefit and Supplemental Retirement Benefit, or  (2) the date you (i) have attained age 50, (ii) completed 5 years of service with the Company, and (iii) separated from service with the Company.

For example, if at the Specified Time that you elect for payment and distribution of your Excess Retirement Benefit and Supplemental Retirement Benefit you are still employed by the Company, your Excess Retirement Benefit and Supplemental Retirement Benefit will not be paid and distributed to you at that Specified Time, and instead will be paid and distributed to you when you subsequently separate from service with the Company.

Similarly, if the Specified Time you elect is later than the date you separate from service with the Company, your Excess Retirement Benefit and Supplemental Retirement Benefit will be paid and distributed to you at the Specified Time you elect.

You may elect a time of payment that is the date you have (i) attained age 50, (ii) completed 5 years of service with the Company, and (iii) separated from service with the Company, and not otherwise elect a specific other date of payment in your election.


 
- 39 -

 

Time of Election of Specific Date (Time of Payment) as Your Normal Specified Distribution Date

Election of Specified Time (Time of Payment) of Excess Retirement Benefit and Supplemental Retirement  Benefit

You must make an irrevocable election of the Specified Time you want to be your Normal Specified Distribution Date within thirty (30) days after the date you are designated and selected to be a Part A Participant or Part B Participant in the SERP.

Subsequent Election

The SERP provides that as a Part A Participant and Part B Participant you may make a Subsequent Election to change the Normal Specified Distribution Date you initially elect to a Subsequent Election Distribution Date. The Subsequent Election is made as to the Specified Time you initially elected, or any Subsequent Election Specified Time you have previously elected under the Plan.

A Subsequent Election to change the Specified Time of payment of an Excess Retirement Benefit and Supplemental Retirement Benefit is subject to several special requirements that limit its effect and use.

A Subsequent Election cannot take effect until at least twelve (12) months after the date it is made, the payment of the Excess Retirement Benefit and Supplemental Retirement Benefit must be deferred for a period of not less than five (5) years from the date payment would otherwise have been paid, and the Subsequent Election cannot be made less than twelve (12) months before the payment of the Excess Retirement Benefit and Supplemental Retirement Benefit  is to be paid.

Because of these special restrictions and limitations, you should review your initially elected Normal Specified Distribution Date periodically and carefully consider it and any possible Subsequent Election to change the Specified Time you initially elect in this instrument.

You may obtain information about making a Subsequent Election from the Company Employee Benefits department.

Form of Payment of SERP Benefit

The SERP provides that if you are married at the time you commence participation as a Part A Participant and Part B Participant, your Excess Retirement Benefit and Supplemental Retirement Benefit will be paid to you in the form of a 50% joint and survivor annuity.

If you are unmarried at the time you commence participation as a Part A Participant and Part B Participant, your Excess Retirement Benefit and Supplemental Retirement Benefit will be paid to you in the form of a single (straight) life annuity.

 
- 40 -

 

As a Part A Participant  and Part B Participant, you may elect to change the form of payment of your Excess Retirement Benefit and Supplemental Retirement Benefit to any actuarially equivalent annuity form of payment that is provided for under the Retirement Plan for Employees of ONEOK, Inc. and Subsidiaries if you make that change election prior to commencement of payment of your Excess Retirement Benefit and Supplemental Retirement Benefit. A change only in such allowed annuity forms of payment is not considered a Subsequent Election subject to the special rules and limitations described above for Subsequent Elections.

SECTION 2: PART A PARTICIPANT ELECTION OF NORMAL SPECIFIED DISTRIBUTION DATE

I hereby irrevocably elect as the time of payment of my Excess Retirement Benefit and Supplemental Retirement Benefit:
( Initial and date one space)

_______     _______The later of (1)_____________, or (2) the date I have (i) attained age fifty (50) , (ii) completed five (5) years of service with the Company, and (iii) separated from service with the Company.

________    _______The date I have (i) attained age fifty (50), (iii) completed five (5) years of service with the Company and (iii) separated from service with the Company.

I understand my election of the Specified Time stated above in this instrument is irrevocable and shall remain in effect as the time of payment of my Excess Retirement Benefit and Supplemental Retirement Benefit unless and until I file a written Subsequent Election as to time of payment in accordance with the terms of the SERP.

I understand, acknowledge and agree that I elect to participate in the Plan in accordance with and subject to all terms and provisions of the Plan, and subject to the terms and provisions of this instrument, which shall be administered, interpreted and applied as determined by the Company and Committee under such terms and provisions of the Plan.

Employee’s Signature__________________________ Date_________________

Witness _____________________________________ Date_________________

SECTION 3: ONEOK USE ONLY

Received By___________________________            Date__________________


 

 

 


 
- 41 -

 

 
 
 

Exhibit 10.8







ONEOK, Inc.

2005 NONQUALIFIED

DEFERRED COMPENSATION PLAN

As Amended and Restated December 18, 2008

 
 

 

ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
As Amended and Restated December 18, 2008

Table of Contents

ARTICLE I PURPOSE
1
1.1
Statement of Purpose; Effective Date
1
ARTICLE II DEFINITIONS
1
2.1
Definitions
1
ARTICLE III ELIGIBILITY AND PARTICIPATION
12
3.1
Eligibility
  12
3.2
Participation
  12
3.3
Elections to Participate Irrevocable
  12
3.4
Exclusion from Eligibility
12
ARTICLE IV DEFERRAL OF COMPENSATION AND EXCESS AMOUNTS
13
 
4.1
Amount and Time of Election to Defer
13
4.2
Deferral Periods; Payment
14
4.3
Committee Authority; Deferral of Compensation
15
4.4
General Requirements for All Elections
15
4.5
Subsequent Elections
16
4.6
Crediting Deferred Base Salary and Bonus
18
4.7
Crediting of Plan Excess Amounts
18
ARTICLE V PLAN EXCESS AMOUNTS
18
5.1
General
18
5.2
Thrift Plan Excess Employee Amount
19
5.3
Thrift Plan Excess Matching Amount
19
5.4
Profit Sharing Plan Excess Amount
19
5.5
Retirement Plan Covered Compensation Excess Amount
19
5.6
Supplemental Credit Amount
20
5.7
Required Elections to Defer Excess Amounts
20
ARTICLE VI BENEFIT ACCOUNTS
20
6.1
Determination of Account
20
6.2
Crediting of Investment Return; Other Items to Participant Accounts
20
6.3
Investment Return; Designated Deemed Investment
21
6.4
Statement of Account
21
6.5
Vesting of Participant Accounts
21

  i
 

 


ARTICLE VII PAYMENT OF BENEFITS
22
7.1
Requirements for Distributions and Payments
22
7.2
Payment of Plan Benefit; Long-Term Deferrals
23
7.3
Payment of Plan Benefit; Short-Term Deferrals
23
7.4
Specified Employee Six (6) Month Required Delay in Distribution and Payment
23
7.5
Form of Distribution and Payment
24
7.6
Distribution and Payment for Subsequent Elections
25
7.7
Distribution and Payment for Early Separation from Service
25
7.8
Distribution and Payment of Plan Benefit Upon Disability
25
7.9
Distribution and Payment of Plan Benefit Upon Death
25
7.10
Payment of Deferrals for Unforeseeable Emergency
25
7.11
Commencement of Distributions and Payments
26
7.12
No Acceleration of Distribution and Payment
26
7.13
Retirement Plan Excess Amount
27
ARTICLE VIII BENEFICIARY DESIGNATION
27
8.1
Beneficiary Designation
27
8.2
Amendments
28
8.3
No Designation
28
8.4
Effect of Payment
28
ARTICLE IX ADMINISTRATION
28
9.1
Plan Committee; Authority and Duties
28
9.2
Agents
30
9.3
Binding Effect of Decisions
30
9.4
Indemnity of Committee
30
ARTICLE X AMENDMENT AND TERMINATION OF PLAN
30
10.1
Amendment
30
10.2
Termination
31
ARTICLE XI PLAN EFFECT, LIMITATIONS, MISCELLANEOUS PROVISIONS
31
11.1
Nature of Employer Obligation; Funding
31
11.2
Trusts; Transfers of Assets, Property
31
11.3
Nonassignability
32
11.4
Captions
33
11.5
Governing Law
33
11.6
Successors
33
11.7
No Right to Continued Service
33

  ii
 

 


EXHIBIT A
34
EXHIBIT B
35
EXHIBIT C
36
EXHIBIT D
38




iii 
 

 

 
ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
As Amended and Restated December 18, 2008
 
ARTICLE I
PURPOSE
 
1.1  
Statement of Purpose; Effective Date
 
This ONEOK, Inc., 2005 Nonqualified Deferred Compensation Plan (the “Plan”) and related agreements between the Employer and certain management or highly compensated employees is an unfunded, nonqualified deferred compensation plan and arrangement.
 
The purpose of the Plan is to provide a select group of management and highly compensated employees of the Employer with the option to defer the receipt of portions of their compensation payable for services rendered to the Employer, and provide nonqualified deferred compensation benefits which are not available to such employees by reason of limitations on employer and employee contributions to qualified pension or profit-sharing plans under the federal tax laws.
 
It is intended that the Plan will assist in attracting and retaining qualified individuals to serve as officers and managers of the Employer; and the Plan is intended to constitute a plan which is unfunded and maintained by an employer primarily for the purpose of providing deferred compensation for a select group of management or highly compensated employees within the meaning of, and as described in Section 201(2) and related provisions of ERISA.
 
The Plan is intended to meet all requirements of Section 409A of the Code for compensation deferred under the Plan to not be includible in gross income of the Participant until actually paid or distributed pursuant to the Plan.
 
The Plan is generally effective on January 1, 2005.
 
ARTICLE II
DEFINITIONS
 
2.1  
Definitions
 
When used in this Plan and initially capitalized, the following words and phrases shall have the meanings indicated:
 
Account
 
“Account” means an account established and maintained for a Participant pursuant to this Plan, to which there shall be credited with and include all amounts of Deferred Compensation that is deferred by and for the Participant under the Plan, which may be accounted for as one or more separate items, amounts or subaccounts for the compensation that is deferred and credited pursuant to the Plan, and investment return thereon, to as determined and prescribed by the Committee.
 

 
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Base Salary
 
“Base Salary” means a Participant’s basic wage or salary paid by the Employer to the Participant without regard to any increases or decreases in such basic wage or salary as a result of (i) an Election to defer basic wage or salary under this Plan or (ii) an Election between benefits or cash provided under a plan of the Employer maintained pursuant to Sections 125 or 401(k) of the Code, and as limited in Exhibit B attached hereto. The Base Salary does not include any Lump Sum Merit Award paid to a Participant, nor any Bonus, as defined in Section 2.5, below.
 
Beneficiary
 
“Beneficiary” means the person or persons designated or deemed to be designated by the Participant pursuant to Article VIII to receive benefits payable under the Plan in the event of the Participant’s death.
 
Board
 
“Board” means the Board of Directors of the Corporation.
 
Bonus
 
“Bonus” means the cash bonus paid or payable by the Employer to a Participant under an Incentive Plan without regard to any decreases as a result of (i) an Election to defer all or any portion of such Bonus under this Plan or (ii) an Election between benefits or cash provided under the Thrift Plan or any other plan of the Employer maintained pursuant to Section 401(k) of the Code.
 
Change in Ownership or Control
 
“Change in Ownership or Control” means to the extent provided by Treasury Regulations issued under Code Section 409A, a change in the ownership or effective control of the Corporation, or in the ownership of a substantial portion of the assets of the Corporation.
 
Code
 
“Code” means the Internal Revenue Code of 1986, and Treasury regulations thereunder, as amended from time to time.
 
Committee
 
“Committee” means the Executive Compensation Committee of the Board of Directors of the Corporation.
 
Compensation
 
“Compensation” means the Base Salary and Bonus payable with respect to an Eligible Employee for each calendar year.
 

 
- 2 -

 

Corporation
 
“Corporation” means ONEOK, Inc., its successors and assigns, or any division or Subsidiary thereof.
 
Deferred Compensation
 
"Deferred Compensation" means the Base Salary and Bonus deferred by a Participant under the Plan, and Qualified Employer Plan Excess Amounts and Supplemental Credit Amounts that are accrued, deferred and credited by the Corporation for a Participant under the Plan, that are made payable to a Participant in a later taxable year of the Participant pursuant to this Plan.
 
Defined Contribution Plan Excess Amounts
 
"Defined Contribution Plan Excess Amounts" means the excess amounts deferred by or for a Participant under this Plan with respect to qualified defined contribution plans established and maintained by the Corporation pursuant to Article V of the Plan.
 
Determination Date
 
“Determination Date” means a date on which the amount of a Participant’s Account is determined and updated as provided in Article VI. Each December 31 of a calendar year shall be the Determination Date.
 
Disabled
 
“Disabled” or “Disability” means that a Participant is unable to engage in substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident or health plan covering Employees of the Corporation. A Participant will be deemed to be Disabled if such Participant is determined to be totally disabled by the Social Security Administration.
 
Early Separation from Service
 
“Early Separation from Service” means a Participant’s Separation from Service prior to attaining age fifty (50) and completing five (5) years of service with the Corporation that is not by reason of death or Disability.
 
Early Separation from Service Form of Payment
 
“Early Separation from Service Form of Payment” shall mean the form of payment and distribution of a Participant’s Plan Benefit in the event of his/her Early Separation from Service which shall be a single lump sum payment at his/her Early Separation from Service Specified Time of Distribution.
 

 
- 3 -

 

Early Separation from Service Specified Time of Distribution
 
“Early Separation from Service Specified Time of Distribution” means a time of distribution and payment of the Participant’s Plan Benefit which is the date of his/her Early Separation from Service.
 
Election
 
“Election” means the election of a Participant or the Corporation for payment and distribution of Deferred Compensation to the Participant for services performed for a Plan Year.
 
Eligible Employee
 
“Eligible Employee” means a highly compensated or management employee of the Corporation who is designated by the Committee, by individual name, or group or description, in accordance with Section 3.1, as eligible to participate in the Plan.
 
Employee
 
“Employee” means an employee of the Corporation or a Subsidiary.
 
Employer
 
“Employer” means, with respect to a Participant, the Corporation or the Subsidiary which pays such Participant’s Compensation.
 
ERISA
 
“ERISA” means the Employee Retirement Income Security Act of 1974, as amended.
 
Exchange Act
 
“Exchange Act” means the Securities Exchange Act of 1934, as amended.
 
Fiscal Year
 
“Fiscal Year” means the fiscal year of the Corporation commencing January 1 and ending the following December 31.
 
Fixed Schedule
 
“Fixed Schedule” means the distribution or payment of Deferred Compensation deferred under the Plan in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such compensation is first elected by the Participant or Corporation under the Plan.
 

 

 
- 4 -

 

Incentive Plan
 
“Incentive Plan” means the Annual Officer Incentive Plan or Annual Employee Incentive Plan of the Corporation, as applicable to a Participant under the terms and provisions thereof.
 
Investment Return
 
“Investment Return” means the rate of investment return to be credited to a Participant’s Account pursuant to Section 6.2, which rate shall be determined in accordance with Section 6.3 and Exhibit “C” attached hereto; provided, that no Investment Return shall be credited with respect to the Retirement Plan Excess Amount.
 
Just Cause
 
“Just Cause”   shall mean the Employee’s conviction in a court of law of a felony, or any crime or offense in a court of law of a felony, or any crime or offense involving misuse or misappropriation of money or property; the Employee’s violation of any covenant, agreement or obligation not to disclose confidential information regarding the business of the Corporation (or a division or Subsidiary); any violation by the Employee of any covenant not to compete with the Corporation (or a division or Subsidiary); any act of dishonesty by the Employee which adversely affects the business of the Corporation (or a division or Subsidiary); any willful or intentional act of the Employee which adversely affects the business of, or reflects unfavorably on the reputation of the Corporation (or a division or Subsidiary); the Employee’s use of alcohol or drugs which interferes with the Employee’s performance of duties as an employee of the Corporation (or a division or Subsidiary); or the Employee’s failure or refusal to perform the specific directives of the Corporation’s Board, or its officers which directives are consistent with the scope and nature of the Employee’s duties and responsibilities with the existence and occurrence of all of such causes to be determined by the Corporation in its sole discretion; provided, that nothing contained in the foregoing provisions of this paragraph shall be deemed to interfere in any way with the right of the Corporation (or a division or Subsidiary), which is hereby acknowledged, to terminate the Employee’s employment at any time without cause.
 
Long-Term Deferral
 
“Long-Term Deferral” means a deferral Election that is not a Short-Term Deferral and under which distribution and payment of the Deferred Compensation and the Plan Benefit shall be distributed and paid at a Specified Time that shall be the Normal Specified Time of Distribution of the Participant. If a Subsequent Election is made, the Plan Benefit deferred by a Long-Term Deferral in the Election shall then be distributed and paid at the Subsequent Election Specified Time of Distribution elected in the Subsequent Election.
 
Lump Sum Merit Award
 
“Lump Sum Merit Award” means a Lump Sum Merit Award granted and paid to a Participant pursuant to the merit compensation program of the Corporation and its Subsidiaries.
 

 
- 5 -

 

Normal Specified Time of Distribution
 
"Normal Specified Time of Distribution" means a specified time that must be expressly designated as the Specified Time of Distribution of the compensation deferred by a Participant in and for each Long-Term Deferral Election, which Normal Specified Time of Distribution shall be the first date on which the Participant has (i) attained the age of fifty (50) years, (ii) completed five (5) years of service with the Corporation, and (iii) had a Separation from Service.
 
Participant
 
“Participant” means any Eligible Employee who elects to participate by filing a Participation Agreement as provided in Section 3.2.
 
Participation Agreement
 
“Participation Agreement” means the agreement filed by a Participant, in the form prescribed by the Committee, pursuant to Section 3.2.
 
Person
 
“Person” means an individual, a trust, estate, partnership, limited liability company, association, corporation or other entity.
 
Performance-Based Compensation
 
“Performance-Based Compensation” means compensation, including Bonus (as hereinabove defined), that is conditioned upon or subject to meeting certain requirements similar to those under Code Section 162(m), as more particularly provided for in Treasury Regulations issued under Code Section 409A.
 
Plan
 
“Plan” means this ONEOK, Inc. 2005 Nonqualified Deferred Compensation Plan, as amended from time to time.
 
Plan Benefit
 
“Plan Benefit” means the deferred benefit payable to a Participant or a Participant’s Beneficiary pursuant to Article VII and otherwise under the Plan.
 
Plan Year
 
“Plan Year” means a twelve-month period commencing January 1 and ending the following December 31.
 
Profit Sharing Plan
 
“Profit Sharing Plan” means the Profit Sharing Plan of the Corporation.
 

 
- 6 -

 

Profit Sharing Plan Excess Amount
 
“Profit Sharing Plan Excess Amount” means an amount equal to the Participant’s Compensation for the Plan Year that is used for calculating Company Contributions to the Profit Sharing Plan multiplied by the applicable percentage for determining the Company Contributions under the Profit Sharing Plan for the Plan Year, minus the amount of Profit Sharing Plan Company Contributions that are allocated to the Participant’s  Account for that Plan Year; it being intended that a Participant shall have credited with a Profit Sharing Plan Excess Amount that is equivalent to the amount of Company Contributions which could not be allocated to the Participant’s Account for the Plan Year by reason of all limitations on compensation and Company Contributions applicable to Profit Sharing Plan Company Contributions under the Code and Treasury regulations under the Code, including (i) the limitation on annual compensation of an Employee that may be taken into account under Code section 401(a)(17), (ii) the limitation on contributions and other additions under Code section 415(c), and (iii) the exclusion of the amount that a Participant has elected to defer out of his or her Base Salary or Bonus under this Plan from “compensation” as defined in the Profit Sharing Plan and/or used for calculation of Profit Sharing Plan contributions and allocations, which amount is to be credited to a Participant’s Account under Section 5.4 of the Plan.
 
Qualified Employer Plan Excess Amounts
 
"Qualified Employer Plan Excess Amounts" means amounts deferred by or for a Participant with respect to participation and/or benefits provided under a qualified defined contribution plan or defined benefit plan established and maintained by the Employer, as more particularly provided for under Article V and otherwise in this Plan.
 
Retirement Plan
 
“Retirement Plan” means the Retirement Plan for Employees of ONEOK, Inc. and Subsidiaries.
 
Retirement Plan Covered Compensation Excess Account
 
“Retirement Plan Covered Compensation Excess Account” means the account maintained on the books of the Employer for the purpose of accounting for the Retirement Plan Covered Compensation Excess Amount and for the amount of investment return credited thereto for each Participant pursuant to Article VI of the Plan.
 
Retirement Plan Covered   Compensation Excess Amount
 
“Retirement Plan Covered Compensation Excess Amount” means an amount for a Participant who is a participant in the Retirement Plan, and not a participant in the ONEOK, Inc. 2005 Supplemental Executive Retirement Plan nor a participant in the Profit Sharing Plan, that is equal to the Participant’s Compensation for the Plan Year less the limitations on compensation and contributions by the Corporation under the Code and Treasury regulations under the Code, including (i) the limitation on annual compensation of an Employee that may be taken into account under Code section 401(a)(17), and (ii) the limitation on contributions and other additions under Code section 415(c) multiplied by the applicable percentage for determining the Company Contributions under the Profit Sharing Plan for the Plan Year, which amount is to be
 

 
- 7 -

 

credited to be allocated to, or recorded in and accounted for in the Account of a Participant under Section 5.5 of the Plan.
 
Retirement Plan Excess Amount
 
“Retirement Plan Excess Amount” means the additional amount payable to a Participant with respect to the Retirement Plan pursuant to Section 7.13.
 
Separation from Service
 
“Separation from Service” means the termination of a Participant’s employment with the Corporation other than by reason of the Participant’s Disability or death.
 
Shares
 
“Shares” means the common stock, par value $0.01 per share, of the Corporation and any other securities into which such shares are changed or for which such shares are exchanged.
 
Short-Term Deferral
 
“Short-Term Deferral” means a deferral elected by a Participant under which payment of the Plan Benefit shall be deferred to commence at a Specified Time of Distribution irrespective of the Participant’s Separation from Service that is specified by the Participant in his or her Election, that shall be not less than five (5) years after the Participant’s Election thereof; provided, that the Committee, may, in its sole discretion, determine and direct that a shorter period, of not less than one (1) year, be applied to any Short-Term Deferral. If a Subsequent Election is made, the Plan Benefit deferred by a Short-Term Deferral in the Election shall then be distributed and paid at the Subsequent Election Specified Time of Distribution elected in the Subsequent Election.
 
Specified Employee
 
"Specified Employee" means an Employee who, as of the date of the Employee's separation from service, is a key employee of a Corporation if any stock of the Corporation is then publicly traded on an established securities market or otherwise; and for purposes of this definition, an Employee is a key employee if the Employee meets the requirements of Code Section 416(i)(1)(A)(i), (ii), or (iii) (applied in accordance with the regulations thereunder and disregarding section 416(i)(5)) at any time during the 12-month period ending on a Specified Employee Identification Date. If an Employee is a key employee as of a Specified Employee Identification Date, the Employee shall be treated as a key employee for purposes of the Plan for the entire 12-month period beginning on the Specified Employee Effective Date. For purposes of identifying a Specified Employee by applying the requirements of section 416(i)(1)(A)(i), (ii), and (iii), the definition of compensation under §1.415(c)-2(a) shall be used, applied as if the Corporation were not using any safe harbor provided in §1.415(c)-2(d), were not using any of the elective special timing rules provided in §1.415(c)-2(e), and were not using any of the elective special rules provided in §1.415(c)-2(g).
 

 
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Specified Employee Effective Date
 
"Specified Employee Effective Date" is the first day of the fourth month following the Specified Employee Identification Date.
 
Specified Employee Identification Date
 
"Specified Employee Identification Date" means December 31.
 
Specified Time
 
“Specified Time” means a date or dates that are not discretionary and objectively determinable at the time an amount of compensation is deferred and at which objectively determinable deferred amounts are to be payable.
 
Specified Time of Distribution
 
“Specified Time of Distribution” means a Specified Time at which compensation deferred by a Participant’s Election pursuant to the Plan is required to be distributed or paid and which is specified in writing by the Participant in and at the time the deferral of such compensation is elected by the Election of a Participant.
 
Subsequent Election
 
“Subsequent Election” means an election made by a Participant with respect to the time of distribution or payment of deferred compensation and Plan Benefit under the Plan that is made at any time after Election that is made by the Participant and/or Corporation with respect to such deferred compensation.
 
Subsequent Election Specified Date
 
"Subsequent Election Specified Date" shall mean a specified fixed date in a calendar year that must be specified in writing by the Participant in a Subsequent Election that is not less than five (5) years from the date payment would otherwise have been made to the Participant under the Plan if such Subsequent Election was not made by the Participant. The written specification of the Subsequent Election Specified Date shall in all cases specify and fix a Specified Time that is not less than five (5) years from the date payment would otherwise have been made to the Participant, it being contemplated and intended that such written specification shall, without limitation, in the case of a Long-Term Deferral (i) meet the requirement in the case of a Participant who has not attained the age of fifty (50) years that the specified Subsequent Election Specified Date be on or after the date the Participant would attain the age of fifty-five (55) years, and (ii) meet the requirement in the case of a Participant who has attained the age of fifty (50) years, that the specified Subsequent Election Specified Date be not less than five (5) years from the date next following the date of the Subsequent Election; and in the case of a Short-Term Deferral meet the requirement that the Subsequent Election Specified Date is not less than five (5) years after the date payment would otherwise have been made to the Participant.
 

 
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Subsequent Election Specified Time of Distribution
 
"Subsequent Election Specified Time of Distribution" means:
 
(a) in the case of a Long-Term Deferral, a Specified Time of Distribution that shall be the first date on or after the Subsequent Election Specified Date for the Long-Term Deferral on which the Participant has (i) attained the age of fifty (50) years, (ii) completed five (5) years of service with the Corporation, and (iii) had a Separation from Service, and
 
(b) in the case of a Short-Term Deferral, a Specified Time of Distribution that shall be the Subsequent Election Specified Date for the Short-Term Deferral.
 
Subsidiary
 
“Subsidiary” means any corporation of which the Corporation owns, directly or indirectly, at least a majority of the shares of stock having voting power in the election of directors of such corporation.
 
Supplemental Credit Amount
 
“Supplemental Credit Amount” means a supplemental amount that may be deferred at the election and direction of the Committee under Section 4.3(b).
 
Taxable Year
 
“Taxable Year” shall mean the Plan Year commencing January 1 and ending the following December 31.
 
Thrift Plan
 
“Thrift Plan” means the Thrift Plan for Employees of ONEOK, Inc. and Subsidiaries.
 
Thrift Plan Excess Employee Amount
 
"Thrift Plan Excess Employee Amount" means an amount equal to the amounts that would have been allocated to the Participant's Account under the Thrift Plan for the Plan Year by reason of the Participant's elections under the Thrift Plan, minus the amount that was allocated to the Participant's account under the Thrift Plan for that Plan Year it being intended that a Participant shall have credited to the Participant’s Account the amount of contributions which could not be allocated to the Participant’s Thrift Plan account for the Plan Year by reason of and after application of the limitations on compensation and contributions or annual additions and otherwise applicable to the Thrift Plan under the Code and Treasury regulations, including (i) Code section 401(a)(17), (ii) Code section 415(c), (iii) the exclusion of the amount the Participant elected to defer out of his or her Compensation under this Plan from “compensation” as defined and/or used for calculation of Thrift Plan contributions or allocations, and other limitations on Thrift Plan employee elective contributions under the Code.
 

 
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Thrift Plan Excess Matching Amount
 
“Thrift Plan Excess Matching Amount” means an amount equal to the Participant’s Thrift Plan Matching Contribution Percentage under the Thrift Plan for the Plan Year multiplied by the Participant’s compensation as defined in the Thrift Plan and/or used for calculation of Thrift Plan contributions and allocations in that Plan Year, minus the amount of Thrift Plan matching contributions made by the Corporation that are allocated to the Participant’s Thrift Plan account for that Plan Year; it being intended that a Participant shall have credited to the Participant’s Account the amount of matching contributions which could not be allocated to the Participant’s Thrift Plan account for the Plan Year by reason of and after application of the limitations on compensation and contributions or annual additions and otherwise applicable to the Thrift Plan under the Code and Treasury regulations, including (i) Code section 401(a)(17), (ii) Code section 415(c), (iii) the exclusion of the amount the Participant elected to defer out of his or her Compensation under this Plan from “compensation” as defined and/or used for calculation of Thrift Plan contributions or allocations, and other limitations on Thrift Plan matching contributions under the Code.
 
Thrift Plan Matching Contribution Percentage
 
“Thrift Plan Matching Contribution Percentage” means the matching contribution percentage in effect for a specific Plan Year under the Thrift Plan.
 
Trust
 
“Trust” means a trust created and established pursuant to Section 11.2 of the Plan, or otherwise by the Corporation with respect to the Plan.
 
Unforeseeable Emergency
 
“Unforeseeable Emergency” means a severe financial hardship to the Participant resulting from illness or accident of the Participant, the Participant’s spouse, or a dependent (as defined in Code Section 152(a)) of the Participant, loss of the Participant’s property due to casualty, or other similar extraordinary circumstances arising as a result of events beyond the control of the Participant, including such events and circumstances as are described and considered to be an unforeseeable emergency under Code section 409A and the regulations thereunder. It is intended and directed with respect to any such unforeseeable emergency that any amounts distributed under the Plan by reason thereof shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participant’s assets (to the extent the liquidation of such assets would not itself cause severe financial hardship).
 

 
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ARTICLE III
ELIGIBILITY AND PARTICIPATION

3.1
Eligibility
 
Eligibility to participate in the Plan shall be granted to those Eligible Employees who are designated by the Committee. Subject to Section 3.4, below (providing for exclusion of Employees not qualifying under certain definitional terms of federal law), the Committee shall adopt a complete written list and/or designation of the Eligible Employees, by individual name or by reference to an identifiable group of persons or by descriptions of the components of compensation of an individual which would qualify the individuals who are eligible to participate, and all of whom shall be a select group of management or highly compensated employees. The written list and/or designation of Eligible Employees by the Committee, from time to time, shall be adopted and maintained in the records of the Committee and Corporation.
 
3.2            Participation
 
Participation in the Plan shall be limited to Eligible Employees who make an Election to participate in the Plan by timely filing a Participation Agreement with the Committee. An Eligible Employee shall commence participation in the Plan upon the first day of the Plan Year or Fiscal Year as the case may be, designated in his or her Participation Agreement filed with the Committee prior to the beginning of such Plan Year.
 
The Committee may in its sole discretion, allow in the case of the first Plan Year in which an individual becomes an Eligible Employee to make an initial Election to participate in the Plan and elect a deferral with respect to Compensation or other amounts that become payable under the Plan for services to be performed after the Election; provided, that any Election by such an Eligible Employee shall be made within thirty (30) days after the date he/she becomes eligible to participate in the Plan.
 
3.3            Elections to Participate Irrevocable
 
A Participant may not change a previously elected percentage of compensation deferred by an Election, or terminate his or her Election to participate in the Plan and defer compensation for a Plan Year. Except as may otherwise be determined and approved by the Committee pursuant to the Plan, a Participant’s Election to defer compensation shall only be effective as of the beginning of the next Plan Year following receipt of the Participant’s Election by the Corporation. Determinations on all Elections and of any effective dates other than as specified above, shall be made by the Committee in accordance with its prevailing administrative procedures.
 
3.4            Exclusion from Eligibility
 
Notwithstanding any other provisions of this Plan to the contrary, if the Committee determines that any Participant may not qualify as a “management or highly compensated employee” within the meaning of ERISA, or regulations thereunder, the Committee may determine, in its sole discretion, that such Participant shall cease to be eligible to participate in this Plan.
 

 
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ARTICLE IV
DEFERRAL OF COMPENSATION AND EXCESS AMOUNTS

4.1            Amount and Time of Election to Defer
 
(a)  
Time of Election . A Participant’s Election to defer compensation for services performed during a Plan Year shall be made not later than the close of the preceding Plan Year, or such other time as provided in Treasury Regulations published under Code Section 409A; provided that in the case of the first Plan Year in which a Participant becomes eligible to participate in the Plan, such Election may be made with respect to services to be performed subsequent to the Election within thirty (30) days after the Participant becomes eligible to participate in the Plan. A Participant’s Election to defer that part of Compensation which constitutes Bonus that constitutes Performance-Based Compensation based on services over a period of at least twelve (12) months in and for a Plan Year shall be made no later than six (6) months before the end of that Plan Year.
 
(b)  
Participant Election Amounts. With respect to each Plan Year, a Participant may voluntarily elect the deferral of compensation by making an Election for deferral of or within the percentages stated below, and subject to the terms described in Exhibit B attached hereto; provided, that each Participant who makes an Election for a Plan Year may elect a deferral that is within or consists of one (1) or more of the following allowable percentages (in one percent (1%) increments) and types of compensation and amounts for that Plan Year, as applicable:
 
(1)  
deferral of at least two percent (2%) and not more than ninety percent (90%) of the Participant’s Base Salary for the Plan Year;
 
(2)  
deferral of at least ten percent (10%) and not more than ninety percent (90%) of the Participant’s Bonus for the Plan Year;
 
deferral of one hundred percent (100%) of each Qualified Employer Plan Excess Amount (except the Retirement Plan Excess Amount) to be accrued or deferred by or for the Participant for the Plan Year;
 
(c)  
Corporation Election Amounts . The Supplemental Credit Amount and Retirement Plan Excess Amount shall be deferred as elected and designated by the Corporation as provided for in Sections 4.3(b) and 7.13, respectively, below.
 
(d)  
Election Choices and Effect . The deferral and crediting of Compensation, a Qualified Employer Plan Excess Amount and/or Supplemental Credit Amount to the Account of a Participant shall be made in respect of an Election of a Participant or the Corporation for a Plan Year as follows:
 
(1)  
A Participant may elect to defer Base Salary or Bonus for services performed during a Plan Year.
 

 
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(2)  
A Participant who does not elect to defer Base Salary or Bonus for services performed during a Plan Year may nevertheless elect to defer a Qualified Employer Plan Excess Amount, (except the Retirement Plan Excess Amount), which shall be deferred and credited to the extent applicable and as provided for and in accordance with Article V, below, for the Plan Year.
 
(3)  
Notwithstanding any other provisions herein, a Participant shall be required to elect to defer and have credited all Qualified Employer Plan Excess Amounts (except the Retirement Plan Excess Amount)  to which he or she is or becomes entitled to for a Plan Year, and shall not be allowed to defer only one or several of the Qualified Employer Plan Excess Amounts and not others for a Plan Year.
 
(e)  
Except as otherwise expressly provided in the Plan in the case of mid-year Elections for new Participants, an Election to defer Base Salary, Bonus, Qualified Employer Plan Excess Amounts or Supplemental Credit Amounts shall apply only to the next Plan Year following such Election. Except as otherwise directed by the Committee, Participants in the Plan shall make separate and new Elections  for each Plan Year.
 
4.2            Deferral Periods ; Payment
 
(a)  
Participant Elections of Specified Time of Distribution. Every Election made by a Participant shall include a specific election of the Participant of deferral of compensation (i) to be paid or distributed at a Specified Time or pursuant to a Fixed Schedule, and (ii) in a specific form of payment stated in the Election.
 
(b)  
Deferral of Base Salary or Bonus. Subject to the requirements of Section 4.2(d), below, a Participant shall be allowed to defer Base Salary or Bonus under the Plan by electing either a Long-Term Deferral or a Short-Term Deferral. The Participant shall elect and designate his or her deferral period as either a Long-Term Deferral or a Short-Term Deferral in the Election and Participation Agreement filed by the Participant with the Committee for a Plan Year.
 
(c)  
Qualified Employer Plan Excess Amounts, Supplemental Credit Amounts; Only Long-Term Deferral . For compensation of Participants in Plan Years beginning on or after January 1, 2009, subject to the requirements of Section 4.4, below, every Election to defer and credit with a Qualified Employer Plan Excess Amount and/or a Supplemental Credit Amount shall be a Long-Term Deferral.
 
(d)  
Early Separation from Service. Notwithstanding the foregoing or any Specified Time or form of payment elected by a Participant in his/her Election or otherwise elected and specified by the Corporation pursuant to Plan, or in any allowed Subsequent Election, in the event the Participant has an Early Separation from Service the Participant’s Plan Benefit shall be paid and distributed to the Participant in a single lump sum payment at the Participant’s Early Separation
 

 
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from Service Distribution Date, except for Short-Term Deferral installment payments that have already commenced, as described and provided fro in Section 7.7 of the Plan. The time and form of payment in event of an Early Separation from Service is determined and specified by the Corporation under the Plan, and a Participant may change or modify such time and form of payment, and may not elect otherwise by his/her Election or any Subsequent Election.
 
(e)  
The Investment Return and/or any other actual, notional or deemed earnings credited to a Participant's Account pursuant to this Plan with respect to any Deferred Compensation by an Election of a Participant or the Corporation shall be paid at the same time and in the same form of payment as the Participant has elected in his/her Election for such Deferred Compensation , and no separate election or time or form of payment shall be allowed or occur with respect to the Investment Return or other earnings credited.
 
4.3            Committee Authority; Deferral of Compensation
 
(a)  
General . Subject to the requirements of Section 4.4, below, the Committee may, in its sole discretion, determine and direct that the amount of deferral and period of deferral which may be elected for Deferred Compensation, for any particular Plan Year or other period of service, be limited to an amount or amounts, and for a period or periods other than that which is otherwise generally provided herein.
 
(b)  
Supplemental Credit Amount . The Committee may elect to have a Supplemental  Credit Amount credited to the Account of a Participant with respect to a Plan Year. A Supplemental Credit Amount shall be established and deferred by irrevocable designation of the time and form of payment by the Corporation, by the written action and election of the Committee or its designee, which shall be made no later than the later of the time the Participant becomes entitled to the amount thereof by such designation, or if later, the time the Participant would be required to make an election if the Participant were provided such election. The Corporation by this Plan designates that each such Supplemental Credit Amount designated by it in a Plan Year shall be deferred for the same period, and be payable at the same Specified Time and in the same form of payment as the Long-Term Deferrals of and for a Participant for that Plan Year. A Participant shall have no right or opportunity to make any election with respect to the amount, deferral and the time and form of payment of a Supplemental Credit Amount.
 
4.4            General Requirements for All Elections
 
Notwithstanding anything to the contrary expressed or, implied herein, the following requirements stated in this Section 4.4 shall apply to the Plan and to all Elections by Participants under the Plan.
 
(a)  
Time of Election . The deferral of compensation for services performed by a Participant may be deferred by Election only if the Election to defer
 

 
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compensation payable with respect to services performed by the Participant in the immediately following year is made and becomes irrevocable not later than the close of the Plan Year (December 31), or such other time as is provided for in Treasury Regulations issued under Code Section 409A. Each Election to defer compensation shall be made not later than the close of the Participant’s taxable year preceding the service year. Provided, that in the case of the first year in which a Participant is eligible to participate in the Plan, such Election may be made with respect to services to be performed subsequent to the Election within thirty (30) days after the date the Participant becomes eligible to the participate in the Plan. Provided, further, in the case of any Performance-Based Compensation based on services performed over a period of at least twelve (12) months, such Election may be made on or before the date that is six (6) months before the end of the performance period, provided that the Participant performs services continuously from the later of the beginning of the performance period or the date the performance criteria are established through the date an Election is made and provided the criteria are established through the date an Election is made, and in no event may such an Election to defer Performance-Based Compensation be made after such Performance-Based Compensation has become readily ascertainable.
 
(b)  
Time and Form of Payment . Every Election to defer compensation shall include an election as to the Specified Time and form of payment and distribution of the compensation deferred.
 
4.5            Subsequent Elections
 
(a)  
General.   Any Subsequent Election that is made under the Plan to elect a delay in a payment or a change in the form of payment of compensation deferred by an Election under the Plan, shall not take effect until at least twelve (12) months after the date on which it is made. In the case of a Subsequent Election related to a payment to be made upon Separation from Service of a Participant, at a Specified Time or pursuant to a Fixed Schedule, or upon a Change in Ownership or Control, the first payment with respect to which Subsequent Election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such Subsequent Election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.
 
(b)  
No Subsequent Election shall be allowed to be made under the Plan that does not comply with the provisions of section 409A of the Code and Treasury Regulations. A Subsequent Election may be made and effective under the Plan with respect to the payment of deferred compensation only if the following conditions are met:
 
(1)  
Such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made;
 

 
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(2)  
Except in the case of an election permitted under Section 409A and the Treasury Regulations §1.409A-3(a)(2) (payment on account of disability), § 1.409A-3(a)(3) (payment on account of death), or §1.409A-3(a)(6) (payment on account of the occurrence of an unforeseeable emergency), the payment with respect to which such Subsequent Election shall be deferred for a period of five (5) years from the date such payment would otherwise have been paid (or in the case of a life annuity or installment payments treated as a single payment, five (5) years from the date the first amount was scheduled to be paid); and
 
(3)  
Any Subsequent Election related to a payment described in Treasury Regulations §1.409A-3(a)(4) (payment at a specified time or pursuant to a fixed schedule) shall be made not less than twelve (12) months before the date the payment is scheduled to be paid (or in the case of a life annuity or installment payments treated as a single payment, twelve (12) months before the date the first amount was scheduled to be paid).
 
(c)  
A Participant by or for whom an Election to defer compensation has been made under the Plan may make a Subsequent Election to change the time of payment of such deferred compensation by written instrument filed with the Committee in such form as it may prescribe at least twelve months (12) prior to the date of the first scheduled payment to which it relates.
 
(d)  
A Participant who has not made any prior Subsequent Election to change the Normal Specified Time of Distribution of deferred compensation under the Plan provided for in the Election shall be allowed to make a Subsequent Election applicable to such Normal Specified Time of Distribution in accordance with this Section 4.5 and the other provisions of the Plan.
 
(e)  
A Participant who has made a prior Subsequent Election of a Subsequent Election Specified Time of Distribution of Deferred Compensation under the Plan shall be allowed to make another Subsequent Election applicable to such Subsequent Election Specified Time of Distribution in accordance with this Section 4.5 and other provisions of the Plan.
 
(f)  
A Participant shall not be authorized to make changes between Long-Term and Short-Term Deferrals elected or provided for in an Election by making a Subsequent Election.
 
(g)  
The Committee shall be authorized to administer, construe and interpret the foregoing provisions and the Plan with respect to all Subsequent Elections to assure compliance with the intent thereof and the requirements of the Plan and of section 409A of the Code and Treasury Regulations.
 
(h)  
Notwithstanding the foregoing provisions, the Committee, in its sole discretion, shall be authorized to determine, from time to time and/or in the particular case
 

 
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of any one or more Participants, that a Subsequent Election not be allowed to be made to change the time of payment of deferred compensation under the Plan.
 
4.6            Crediting Deferred Base Salary and Bonus
 
The amount of Base Salary that a Participant elects to defer pursuant to an Election of the Participant under the Plan shall be credited by the Employer to the Participant’s Account monthly, provided that the Employer shall reduce the deferral amount credited by the amount of taxes, including taxes imposed by the Federal Insurance Contribution Act (FICA) or other amounts, if any, required to be withheld by the Employer from a Participant’s Compensation pursuant to any state, federal or local law. The amount of Bonus that a Participant elects to defer pursuant to an Election of the Participant under the Plan shall be credited by the Employer to the Participant’s  Account at the time the Bonus would otherwise be paid or payable to the Participant under the Incentive Plan pursuant to which such Bonus is paid or payable.
 
4.7            Crediting of Plan Excess Amounts
 
The amount of any Qualified Employer Plan Excess Amount or  Supplemental Credit Amount  that a Participant or the Corporation elects to defer pursuant to an Election of the Participant or the Corporation shall be credited in accordance with Article V, below. Such amounts shall be credited on or before the last day of the Plan Year for which they are deferred by the Participant or Corporation Election.
 
ARTICLE V
PLAN EXCESS AMOUNT

5.1            General
 
(a)  
Qualified Employer Plan Excess Amounts. There shall be deferred and credited to the Account of a Participant the Qualified Employer Plan Excess Amounts (except the Retirement Plan Excess Amount) that apply to such Participant for the Plan Year by reason or and based upon his/her participation during the Plan Year in one or more qualified defined contribution plans or defined benefit plans of the Corporation, as more particularly described and provided for in this Article V, including the Thrift Plan, Profit Sharing Plan and Retirement Plan. A Participant shall be entitled to defer and have credited to his/her Account such Qualified Employer Plan Excess Amounts (except the Retirement Plan Excess Amount) to the extent he/she is a participant in the qualified plan of the Corporation and his/her participation in, and benefits under such qualified plan come under and are affected in the manner described herein below.
 
(b)  
Supplemental Credit Amount. There shall be deferred and credited to the Account of a Participant Supplemental Credit Amounts that apply to such Participant for the Plan Year by reason or and based upon his/her entitlement thereto during the Plan Year as specified in the written authorization and direction of the deferral and credit thereof by the Corporation. A Participant shall be entitled to defer and have credited to his/her Account such Supplemental Credit Amounts to the extent provided for in such authorization.
 

 
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5.2            Thrift Plan Excess Employee Amount
 
a. The Employer shall provide and credit a Thrift Plan Excess Employee Amount elected under this Plan for each Participant making an Election thereof and eligible to make and be allocated contributions under the Thrift Plan; except that the Committee may, in its discretion, prior to any Plan Year, make a determination not to provide for the election and crediting of Thrift Plan Excess Employee Amounts for that Plan Year.
 
b. The Thrift Plan Excess Employee Amount under the Plan for each Participant under this Section 5.2 shall be credited by the Employer as soon as practicable after the time the related contributions and allocations are made under the Thrift Plan, and no later than ninety (90) days after the end of the Plan Year that includes the time that the related contributions and allocations are made under the Thrift Plan.
 
5.3            Thrift Plan Excess Matching Amount
 
a. The Employer shall provide and credit a Thrift Plan Excess Matching Amount elected under this Plan with respect to each Participant making an Election thereof and eligible to be allocated matching contributions under the Thrift Plan; except that the Committee may, in its discretion, prior to any Plan Year, make a determination not to provide for the crediting of Thrift Plan Excess Matching Amounts for that Plan Year.
 
b. The Thrift Plan Excess Matching Amount under the Plan for each Participant under this Section 5.3, above, shall be credited by the Employer as soon as practicable after the time the related matching contributions are made under the Thrift Plan, and no later than ninety (90) days after the end of the Plan Year that includes the time that the related matching contributions are made under the Thrift Plan.
 
5.4            Profit Sharing Plan Excess Amount
 
a. The Employer shall provide and credit a Profit Sharing Plan Excess Amount under this Plan with respect to each Participant making an Election thereof and eligible to be allocated contributions under the Profit Sharing Plan; except that the Committee may, prior to any Plan Year, make a determination not to provide for the crediting of Profit Sharing Plan Excess Amounts for that Plan Year.
 
b. The Profit Sharing Plan Excess Amount under the Plan for each Participant under this Section 5.4, shall be credited by the Employer as soon as practicable after the time the related contributions and allocations are made under the Profit Sharing Plan, and no later than ninety (90) days after the end of the Plan Year that includes the time that the related contributions and allocations are made under the Profit Sharing Plan.
 
5.5            Retirement Plan Covered Compensation Excess Amount
 
a. The Employer shall provide and credit a Retirement Plan Covered Compensation Excess Amount elected and deferred under this Plan for each Participant making an Election thereof and
 

 
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eligible to participate in the Retirement Plan, and not participating in the ONEOK, Inc. 2005 Supplemental Executive Retirement Plan; except that the Committee may, in its discretion, prior to any Plan Year, make a determination not to provide for the election and crediting of Retirement Plan Covered Compensation Excess Amounts for that Plan Year.
 
b. The Retirement Plan   Covered Compensation Excess Amount under the Plan for a Participant under this Section 5.5 shall be credited by the Employer as soon as practicable after the time the related accruals and contributions are made under the Profit Sharing Plan, and no later than ninety (90) days after the end of the Plan Year that includes the time that the related contributions and allocations are made under the Profit Sharing Plan.
 
5.6            Supplemental Credit Amount
 
a. The Employer shall provide and credit a Supplemental Credit Amount if elected and deferred by the Corporation under this Plan for each Participant; except that the Committee may, in its discretion, prior to any Plan Year, make a determination not to provide for the election and crediting of Supplemental Credit Amounts for that Plan Year.
 
b. The Supplemental Credit Amount under the Plan for a Participant under this Section 5.6shall be credited by the Employer as soon as practicable after the beginning of the Plan Year for which an election is made, and no later than ninety (90) days after the end of the Plan Year.
 
5.7            Required Elections to Defer Excess Amounts
 
The deferral, allowance, provision of and crediting of a Qualified Employer Plan Excess Amount shall be made and administered under this Plan if and to the extent elected by a Participant in such Participant’s Election made pursuant to and in accordance with the terms and provisions of Article IV. Provided, that Retirement Plan Excess Amounts deferred under this Plan are separately provided for and made payable under the Plan pursuant to and in accordance with Section 7.13 of the Plan; and Supplemental Credit Amounts are elected and made payable as determined by the Committee in accordance with Section 4.3(b) of the Plan.
 
ARTICLE VI
BENEFIT ACCOUNTS
 
6.1            Determination of Account
 
As of each Determination Date, a Participant’s Account shall consist of the balance of the Participant’s Account as of the immediately preceding Determination Date, plus the Participant’s Deferred Compensation  credited pursuant to Article V since the immediately preceding Determination Date, plus investment return credited as of such Determination Date pursuant to Section 6.2, minus the aggregate amount of distributions, if any, made from such Account since the immediately preceding Determination Date.
 
6.2            Crediting of Investment Return; Other Items to Participant Accounts
 
The Account of each Participant shall be periodically credited and increased, or debited and reduced, as the case may be, by the amount of investment return specified under Section 6.3. The
 

 
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Account of each Participant shall also be debited and credited for any deemed purchases or sales of, or other deemed transactions involving securities provided for under the Plan. The Account,  shall be so credited and debited not less frequently than monthly in the manner established and determined from time to time by the Committee, in its sole discretion. The manner in which the Committee determines that a Participant’s Account shall be so debited or credited shall be described in written rules or procedures which shall be stated from time to time by a written description thereof which shall be attached to this Plan as Exhibit “D,” and furnished to the Participants in the Plan.
 
6.3            Investment Return; Designated Deemed Investment
 
The Investment Return shall be determined in the manner specified in Exhibit “C” attached hereto.
 
To the extent the Investment Return specified in Exhibit “C” attached hereto, applied to a Participant’s deferrals includes a rate that is to be determined from deemed investment of such  Participant’s Account in investment options specified therein, the Committee shall prescribe the manner and form in which a Participant may designate the deemed investment of deferrals and other amounts in his or her Account. A Participant will be allowed to change such designation of deemed investment monthly or with such other frequency as specified by the Committee, in its sole discretion. Provided, that notwithstanding anything to the contrary stated or implied by the Plan, including all Exhibits thereto, the use, reference to or consideration of any such deemed investments made by the Committee or Plan, or designated by Participants, the Committee and the Corporation shall not be obligated to make or cause to be made any particular type or form of investment with respect to the funding or payment of the Plan Benefits or Accounts of Participants under the Plan, and no Participant shall have the right to direct or in any manner control any actual investments, if any, made by the Employer or any other person for purposes of providing funds for paying liabilities of the Employer for benefits or otherwise under the Plan.  No Participant shall have any ownership or beneficial interest in any such actual investments made by the Employer.
 
6.4            Statement of Account
 
The Committee shall provide to each Participant a statement each calendar quarter setting forth the balance or balances of such Participant’s Account which have attributed an Investment Return as of the end of the calendar quarter showing all adjustments made thereto during such calendar quarter.
 
6.5            Vesting of Participant Account s
 
Except as provided in Sections 10.1 and 10.2, below, a Participant shall be one hundred percent (100%) vested in his or her Account,  at all times: provided that  the vesting of a Participant’s Retirement Plan Excess Account shall be determined in like manner as the vesting of the Participant’s accrued benefit under the Retirement Plan.
 

 
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ARTICLE VII
PAYMENT OF BENEFITS
 
7.1            Requirements for Distributions and Payments
 
Notwithstanding anything to the contrary expressed or implied herein, the following requirements stated in this Section 7.1 shall apply to the Plan, to all Elections or Subsequent Elections made by Participants under the Plan, and to all distributions and payments made pursuant to the Plan.
 
(a)  
Any Compensation deferred under the Plan shall not be distributed earlier than
 
(1)  
separation from Service of the Participant,
 
(2)  
the date the Participant becomes Disabled,
 
(3)  
death of the Participant,
 
(4)  
a Specified Time (or pursuant to a Fixed Schedule) specified under the Plan at the date of deferral of such Compensation,
 
(5)  
a Change in Ownership or Control, or
 
(6)  
the occurrence of an Unforeseeable Emergency.
 
(b)  
Notwithstanding the foregoing, in the case of a Participant who is a Specified Employee, no distribution shall be made before the date which is six (6) months after the date of the Participant’s Separation from Service, or, if earlier, the date of death of such Participant.
 
(c)  
No acceleration of the time or schedule of any distribution or payment under the Plan shall be permitted or allowed, except to the extent provided in Treasury Regulations issued under Code Section 409A.
 
(d)  
If the Plan, or the Committee acting pursuant to the Plan, permits under any Subsequent Election by a Participant a delay in a payment or a change in the form of payment of Compensation deferred under the Plan, such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made. In the case of a Subsequent Election related to a payment to be made upon Separation from Service of a Participant, at a Specified Time or pursuant to a Fixed Schedule, or upon a Change in Ownership or Control, the first payment with respect to which such Subsequent Election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such Subsequent Election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.
 

 
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7.2            Payment of Plan Benefit; Long-Term Deferrals
 
Subject to the requirements stated in Section 7.1, above, and Section 7.7 below, a Long-Term Deferral of Deferred Compensation shall be paid and distributed to the Participant at the Normal Specified Time of Distribution elected by a Participant (the Participant’s Separation from Service after attaining fifty (50) years of age and the completion of five (5) years of service with the Corporation). The Employer shall pay to the Participant the Plan Benefit in the form of payment specified and elected in the Participant’s Election and Participation Agreement pursuant to Section 7.5.
 
7.3            Payment of Plan Benefit; Short-Term Deferrals
 
Subject to the requirements stated in Section 7.1, above, and Section 7.7 below, a Short-Term Deferral of Compensation elected by a Participant shall be paid and distributed to a Participant at the Specified Time or pursuant to the Fixed Schedule designated and elected by the Participant in his or her Election and Participation Agreement. The Employer shall pay to the Participant the Plan Benefit in the form of benefit specified and elected in the Participant’s Election pursuant to Section 7.5; provided, that no part of a Short-Term Deferral may be paid prior to five (5) years following the Participant’s Election thereof.
 
7.4            Specified Employee Six (6) Month Required Delay in Distribution and Payment
 
In the case of any Participant who is a Specified Employee as of the date of a Separation from Service, distribution and payments of any deferred compensation and Plan Benefit may not be made before the date that is six (6) months after the date of Separation from Service (or, if earlier than the end of the six-month period, the date of death of the Specified Employee). For this purpose, a Participant who is not a Specified Employee as of the date of a Separation from Service will not be treated as subject to this requirement even if the Participant would have become a Specified Employee if the Participant had continued to provide services through the next Specified Employee Effective Date; and a Participant who is treated as a Specified Employee as of the date of a Separation from Service will be subject to this requirement even if the Participant would not have been treated as a Specified Employee after the next Specified Employee Effective Date had the Specified Employee continued in employment with the Corporation through the next Specified Employee Effective Date. The required delay in payment is met if payments to which a Specified Employee would otherwise be entitled during the first six (6) months following the date of Separation from Service are accumulated and paid on the first day of the seventh month following the date of Separation from Service, or if each payment to which a Specified Employee is otherwise entitled upon a Separation from Service is delayed by six (6) months. The Committee shall have and retain discretion to choose which method will be implemented, provided that no direct or indirect election as to the method may be provided to the Participant. For an affected Specified Employee, a date upon which the Committee or the Corporation designates that the payment will be made after the six-month delay is treated as a fixed payment date for purposes of the other requirements of the Plan once the Separation from Service has occurred.
 

 
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7.5            Form of Distribution and Payment
 
The Plan Benefit payable to a Participant for Deferred Compensation shall be distributed and paid in one of the following forms, as elected by the Participant in and at the time of his or her Election.
 
(a)  
For Participants who elect a Long-Term Deferral, the Plan Benefit shall be distributed and paid in one of the following elected forms elected by the Participant in such Election:
 
(1)  
In annual payments of the vested Account balance, on and after the payment commencement date over a period of either five (5) or fifteen (15) years (together, in the case of each annual payment, with Investment Return thereon credited after the payment commencement date pursuant to Section 6.2), with the amount of each such annual payment to be determined by multiplying the remaining principal amount and undistributed income in the Participant’s Account by a fraction, the numerator of which is one (1) and the denominator of which shall be the number of remaining annual payments, including the payment then being calculated; or
 
(2)  
A lump sum.
 
(b)  
For Participants who elect a Short-Term Deferral, the Plan Benefit shall be distributed and paid in one of the following forms elected by the Participant in such Election:
 
(1)  
Annual payments of a fixed amount which shall amortize the vested Account balance, on and after the payment commencement date over a period of from two (2) to four (4) years (together, in the case of each annual payments with Investment Return thereon credited after the payment commencement date pursuant to Section 6.2), with the amount of each such annual payment to be determined by multiplying the remaining principal amount and undistributed income in the Participant’s Account by a fraction, the numerator of which is one (1) and the denominator of which shall be the number of remaining annual payments, including the payment then being calculated; or
 
(2)  
A lump sum.
 
(c)  
For any Participant who has an Early Separation from Service, the Plan Benefit shall be distributed in a single lump sum payment, except for Short-Term Deferral installment payments that have already commenced, as provided for in Section 7.7 below.
 

 
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7.6            Distribution and Payment for Subsequent Elections
 
Subject to the provisions of Section 7.1, above, if a Subsequent Election is made pursuant to the Plan, the payment and distribution shall be made at the Subsequent Election Time of Distribution that is elected and determined in and by such Subsequent Election.
 
7.7            Distribution and Payment for Early Separation from Service
 
Subject to the requirements stated in Section 7.1, above, and notwithstanding the foregoing provisions in Sections 7.2 and 7.3, a Long-Term Deferral and/or Short-Term Deferral shall be paid and distributed to a Participant upon his/her Early S eparation from Service., The Employer shall pay to the Participant his/her Plan Benefit in a single lump sum payment equal to the balance of the Participant’s Account determined pursuant to Article VI. This lump sum payment shall be made notwithstanding any other period or time of payment that has been elected by the Participant. Provided, that any installment payments of a Short-Term Deferral to the Participant that have commenced and not been completed at such time shall continue to be paid in accordance with the existing schedule of payments.
 
7.8            Distribution and Payment of Plan Benefit Upon Disability
 
Subject to the requirements stated in Section 7.1, above, if a Participant becomes Disabled, the Employer shall distribute and pay to the Participant, or the Participant’s personal representative, a Plan Benefit. The payment and distribution shall be made upon the date the Participant is determined by the Committee to be Disabled. Notwithstanding any other provisions of the Plan, a cancellation of a Participant's Election with respect to deferral of compensation may be made by the Participant or the Committee where such cancellation occurs by the later of the end of the taxable year of the Participant or the 15th day of the third mon th following the date the Participant incurs a Disability. For purposes of this paragraph, a Disability refers to any medically determinable physical or mental impairment resulting in the Participant's inability to perform the duties of his or her position or any substantially similar position, where such impairment can be expected to result in death or can be expected to last for a continuous period of not less than six (6) months.
 
7.9            Distribution and Payment of Plan Benefit Upon Death
 
Subject to the requirements stated in Section 7.1, above, upon the death of a Participant the Participant’s Account shall be paid to the Participant’s Beneficiary. If the Participant has elected Long-Term Deferral, the Plan Benefit shall be paid to the Beneficiary over the time period elected by the Participant commencing as soon as practicable after the time of death of the Participant. If the Participant has elected a Short-Term Deferral, the Plan Benefit shall be paid to the Beneficiary in a single lump sum payment. However, the Retirement Plan Excess Amount will be paid to the same beneficiary as the Retirement Plan benefit.
 
7.10            Payment of Deferrals for Unforeseeable Emergency
 
Subject to the requirements stated in Section 7.1, above, in the case of an Unforeseeable Emergency, a Participant may apply in writing to the Corporation, or its designated agent, for the immediate distribution of all or part of his or her Plan Benefit; provided, that such a distribution
 

 
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shall not exceed the amounts necessary to satisfy the emergency involved plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participant’s assets (to the extent the liquidation of such assets would not itself cause severe financial hardship). In addition, the Participant must continue to defer Compensation subsequent to such distribution in accordance with the Participant’s Election and will not be permitted to elect to defer Compensation attributable to the calendar year subsequent to the calendar year of the distribution. The Corporation shall have the sole discretion as to whether such distribution shall be made, and its determination shall be final and conclusive. In making its determinations, the Corporation shall follow a uniform and nondiscriminatory practice.
 
7.11            Commencement of Distributions and Payments
 
Subject to the requirements stated in Section 7.1, above, and except as otherwise provided in Section 7.2, the commencement of payments under Sections 7.1 through 7.4, above, shall begin at the time specified by the Participant in his or her Election and Participation Agreement consistent with the terms and provisions of the Plan or Subsequent Election.
 
Except as otherwise expressly specified in the Plan, a distribution or payment shall be treated as made upon the date specified under the Plan if the payment is made at such date or a later date within the same taxable year of the Participant or, if later, by the 15th day of the third calendar month following the date specified under the Plan and the Participant is not permitted, directly or indirectly, to designate the taxable year of the payment. In addition, a distribution or payment shall be treated as made upon the date specified under the Plan and shall not treated as an accelerated payment if the payment is made no earlier than thirty (30) days before the designated payment date and the Participant is not permitted, directly or indirectly to designate the taxable year of the payment. For purposes of this paragraph, if the date specified is only a designated taxable year of the Participant, or a period of time during such a taxable year, the date specified under the Plan is treated as the first day of such taxable year or the first day of the period of time during such taxable year, as applicable. If calculation of the amount of the distribution or payment is not administratively practicable due to events beyond the control of the Participant (or Participant's beneficiary), the distribution or payment will be treated as made upon the date specified under the Plan if the distribution or payment is made during the first taxable year of the Participant in which the calculation of the amount of the distribution or payment is administratively practicable. For purposes of this section, the inability of a Corporation to calculate the amount or timing of a distribution or payment due to a failure of a Participant (or Participant's beneficiary) to provide reasonably available information necessary to make such calculation does not constitute an event beyond the control of the Participant.
 
7.12            No Acceleration of Distribution and Payment
 
No acceleration of the time or schedule of any payment or amount scheduled to be paid pursuant to the terms of the Plan shall be allowed, and no such accelerated payment may be made whether or not provided for under the expressed or implied terms of such Plan. Provided, that there may be an acceleration of a payment in accordance with the express provisions allowing the same under the Treasury regulations issued under Code Section 409A or the Committee may have
 

 
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discretion to permit such acceleration to be made consistent with the regulations. Provided, that a Participant shall have no discretion with respect to whether a payment will be accelerated, and the Corporation or Committee shall not provide a Participant a direct or indirect election as to whether the Corporation's or Committee's discretion to accelerate a payment will be exercised, even if such acceleration would be permitted under the regulations.
 
7.13            Retirement Plan Excess Amount
 
Subject to the requirements stated in Section 7.1, above, the Corporation shall pay to a Participant or his or her survivor Beneficiary, as the case may be, a Retirement Plan Excess Amount elected to be deferred and credited for the Participant by the Corporation that shall be equal to the amount by which such Participant’s retirement benefit under the Retirement Plan is reduced by reason of the deferred Compensation elected by the Participant under the Plan not being taken into account in the calculation of such Participant’s retirement benefit under the Retirement Plan, but only if such deferred Compensation is not taken into account in determining a retirement benefit or payment payable to such Participant under the ONEOK, Inc., 2005 Supplemental Executive Retirement Plan (SERP), nor under any other plan, arrangement or agreement of the Corporation other than this Plan
 
The Retirement Plan Excess Amount payable to a Participant, or his or her Beneficiary, under this Section 7.13 shall be paid commencing at the date of the Participant’s Normal Specified Time of Distribution under this Plan and the amount thereof shall be calculated pursuant to the Retirement Plan benefit formula in the manner it would be calculated if the Participant commenced payment of his/her Retirement Plan benefits at that time. However, if Participant is a SERP participant, the time and form of payment of the Participant’s Retirement Plan Excess Amount under this Plan shall be the time and form of payment that the Participant has made or makes under the SERP as to the time and form of payment of his/her benefits under the SERP; provided that such election under the SERP shall be considered an election by the Participant under this Plan that is subject to application of all pertinent requirements, restrictions and limitations of this Plan with respect to the time of making and effect of an Election or Subsequent Election, and/or the prohibition of an acceleration of payment of the Retirement Plan Excess Amount; and provided further, that to the extent that such an election would not comply with any of such requirements, restrictions or limitations, the time of payment shall be the Normal Specified Time of Distribution. The Retirement Plan Excess Amount shall be paid in the form of a 50% joint and survivor annuity, as defined in the Retirement Plan, if the Participant is married at the time of the Corporation’s Election, and shall be paid in the form of a single (straight) life annuity, as defined in the Retirement Plan, if the Participant is single at the time of the Corporation’s Election. The form of payment can be changed by Participant prior to commencement to another actuarially equivalent form of monthly annuity.
 
ARTICLE VII
BENEFICIARY DESIGNATION
 
8.1            Beneficiary Designation
 
Each Participant shall have the right, at any time, to designate any person or persons as his or her Beneficiary to whom payment under the Plan shall be made in the event of the Participant’s
 

 
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death prior to complete distribution to the Participant of his or her Account; provided, that the Retirement Plan Excess Amount shall be paid to the Participant’s beneficiary for Retirement Plan benefits. Any Beneficiary designation shall be made in a written instrument provided by the Committee. All Beneficiary designations must be filed with the Corporation and shall be effective only when received in writing by the Corporation.
 
8.2            Amendments
 
Any Beneficiary designation may be changed by a Participant by the filing of a new Beneficiary designation, which will cancel all the Participant’s prior Beneficiary designations filed with the Committee.
 
8.3            No Designation
 
If a Participant fails to designate a Beneficiary as provided above, or if all designated Beneficiaries predecease the Participant, then the Participant’s designated Beneficiary shall be deemed to be the Participant’s estate.
 
8.4            Effect of Payment
 
Payment to a Participant’s Beneficiary (or, upon the death of a primary Beneficiary, to the contingent Beneficiary or, if none, to the Participant’s estate) shall completely discharge the Employer’s obligations under the Plan.
 
ARTICLE IX
ADMINISTRATION
 
9.1            Plan Committee; Authority and Duties
 
(a)  
The Plan shall be administered by the Committee, which shall consist of not less than three (3) members, appointed from time to time by the Board to serve at the pleasure of the Board.
 
(b)  
Notwithstanding anything to the contrary expressed or implied herein, no member of the Committee shall have any right or authority to act, vote or decide upon any matter relating solely to such member under the Plan, or to act, vote upon or decide any issue or case in which such member's individual right to receive any Compensation under the Plan is particularly involved, or to take any action that would change or accelerate the deferral or payment of Compensation or benefits to such member in a manner or at a time not provided for under the Plan. In any case in which a member of the Committee is so disqualified to act and the remaining members cannot agree, or in any case where a majority or all of the members of the Committee are so disqualified, the Executive Compensation Committee of the Board shall appoint a substitute member or members of the Committee to exercise all powers of the disqualified member or members concerning the matter involved, or in the alternative the Executive Compensation Committee may, in its discretion, assume authority to act upon and decide the issues and case involved, with any such action and decision by it
 

 
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to be final and binding with respect to the Plan, Participants or other persons involved.
 
The Committee and its members shall have no discretion to allow or cause distribution or payment of the Account or any deferred compensation to any Participant at a time or in a form or manner that is not in accordance with the terms and provisions of the Plan, including the requirements of Section 7.1, above, and the requirements of Code Section 409A.
 
(c)  
The Committee shall supervise the administration and operation of the Plan, may from time to time adopt rules and procedures governing the Plan and shall have authority to give interpretive rulings with respect to the Plan. The Committee shall have such other powers and duties as are specified in this Plan as the same may from time to time be constituted, and not in limitation but in amplification of the foregoing, the Committee shall have power, in its discretion to the exclusion of all other persons, to interpret the provisions of this instrument, to decide any disputes which may arise hereunder; to construe and determine the effect of Participant Agreements, Elections, beneficiary designations, and other actions and documents; to determine, in its discretion, all questions that shall arise under the Plan, including questions as to the rights of Employees to become Participants, as to the rights of Participants, any Beneficiary or other person with respect to the Plan, and including questions submitted by the trustee of a Trust created under Section 11.2 on all matters necessary for it properly to discharge its duties, powers, and obligations; to employ legal counsel, accountants, consultants and agents; to establish and modify such rules, procedures and regulations for carrying out the provisions of the Plan not inconsistent with the terms and provisions hereof, as the Committee, in its discretion, may determine; and in all things and respects whatsoever, without limitation, to direct the administration of the Plan and any such Trust with the trustee being subject to the direction of the Committee.
 
(d)  
The Committee may supply any omission or reconcile any inconsistency in this instrument in such manner and to such extent as it shall deem expedient to carry the same into effect and it shall be the sole and final judge of such expediency.
 
(e)  
The Committee may adopt such rules and regulations with respect to the signature by an Employee, Participant and/or Beneficiary as to any agreements, Elections or other papers to be signed by Employees or Participants or Beneficiaries and similar matters as the Committee shall determine in view of the laws of any state or states.
 
(f)  
The Committee shall maintain or cause to be maintained complete and adequate records pertaining to the Plan, including but not limited to the Accounts of Participants, all matters involving any Trust of the Plan, and all other records which the Committee in its discretion determines are necessary or desirable in the administration of the Plan.
 

 
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(g)  
Any act which the Plan authorizes or requires the Committee to do may be done by a majority of the then members of the Committee. The action of such majority of the members expressed either by a vote at a meeting or in writing without a meeting, shall constitute the action of the Committee and shall have the same effect for all purposes as if assented to by all of the members of the Committee at the time in office, provided, however, that the Committee may, in specific instances, authorize one (1) of its members to act for the Committee when and if it is found desirable and convenient to do so.
 
9.2            Agents
 
The Committee may appoint an individual, who may be an employee of the Corporation, to be the Committee’s agent with respect to the day-to-day administration of the Plan. In addition, the Committee may, from time to time, employ other agents and delegate to them such administrative duties as it sees fit, and may from time to time consult with counsel who may be counsel to the Corporation.
 
9.3            Binding Effect of Decisions
 
Any decision or action of the Committee with respect to any question arising out of or in connection with the administration, interpretation and application of the Plan shall be final and binding upon all persons having any interest in the Plan.
 
9.4            Indemnity of Committee
 
The Corporation shall indemnify and hold harmless the members of the Committee and their agents duly appointed under Section 9.2 against any and all claims, loss, damage, expense or liability arising from any action or failure to act with respect to the Plan, except in the case of gross negligence or willful misconduct by any such member or agent of the Committee.
 
ARTICLE X
AMENDMENT AND TERMINATION OF PLAN
 
10.1            Amendment
 
(a)  
The Corporation, on behalf of itself and of each Subsidiary may by action of the Board at any time amend, modify, suspend or reinstate any or all of the provisions of the Plan, except that no such amendment, modification, suspension or reinstatement may adversely affect any Participant’s Account, as it existed as of the day before the effective date of such amendment, modification, suspension or reinstatement, without such Participant’s prior written consent.
 
(b)  
The Plan may also be so amended or modified by resolution of the Committee or by the Committee executing a written instrument containing such amendment or modification (pursuant to authority which has been duly delegated to the Committee by the Board and is hereby acknowledged and recognized); provided, that no amendment or modification of the Plan to increase any compensation of or benefits provided to Participants under the Plan, and no termination of the
 

 
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Plan shall be made unless such amendment or modification, or termination, is authorized pursuant to a resolution duly adopted by the Board. Any action by resolution or a written instrument by the Committee shall be presumed to be effective without necessity of further action or approval of the Board. In the event any issue should arise with respect to respective authority of the Committee, or of the Board, and amendments or modifications of the Plan made by them that are or appear to be inconsistent, final authority shall be reserved to and exercisable by the Board and its action to amend or modify the Plan shall take precedence.
 
Written notice of any amendment or other action with respect to the Plan shall be given to each Participant.
 
10.2            Termination
 
The Corporation, on behalf of itself and of each Subsidiary, in its sole discretion, may by action pursuant to a resolution adopted by the Board terminate this Plan at any time and for any reason whatsoever. Upon termination of the Plan, the Committee shall take those actions necessary to administer any Participant Accounts existing prior to the effective date of such termination; provided, however, that a termination of the Plan shall not adversely affect the value of a Participant’s Account, the crediting of investment return under Section 6.2, or the timing or method of distribution of a Participant’s Account, without the Participant’s prior written consent.
 
ARTICLE XI
PLAN EFFECT, LIMITATIONS,
MISCELLANEOUS PROVISIONS
 
11.1            Nature of Employer Obligation; Funding
 
Participants, their Beneficiaries, and their heirs, successors and assigns, shall have no secured interest or claim in any property or assets of the Employer. The Employer’s obligation under the Plan shall be merely that of an unfunded and unsecured promise of the Employer to pay money in the future.
 
11.2            Trusts; Transfers of Assets, Property
 
(a)  
Notwithstanding the foregoing, in the event of a Change in Ownership or Control, the Corporation shall create an irrevocable Trust, or before such time the Corporation may create an irrevocable or revocable Trust, to hold funds to be used in payment of the obligations of Employers under the Plan.
 
(b)  
Notwithstanding anything otherwise expressed or implied herein, in the case of any assets set aside (directly or indirectly) in a such a Trust (or other arrangement determined by Treasury Regulations or otherwise pursuant to Code Section 409A) for purposes of paying deferred compensation under the Plan, no such assets (or such a Trust or other arrangement) shall ever be located or transferred outside the United States.
 

 
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(c)  
In the event of a Change in Ownership or Control or prior thereto, the Employers shall fund such Trust in an amount equal to not less than the total value of the Participants’ Accounts under the Plan as of the Determination Date immediately preceding the Change in Ownership or Control, provided that any funds contained therein shall remain liable for the claims of the general creditors of the respective Employers.
 
(d)  
Pursuant to this Section 11.2, the Corporation may, without further reference to or action by any Employee, Participant, or any Beneficiary from time to time enter into such further agreements with a trustee or other parties, and make such amendments to said trust agreement or such further agreements, as the Corporation may deem necessary or desirable to carry out the Plan; from time to time designate successor trustees of such a Trust; and from time to time take such other steps and execute such other instruments as the Corporation may deem necessary or desirable to carry out the Plan. The Committee shall advise the trustee of any such Trust in writing with respect to all Plan Benefits which become payable under the terms of the Plan and shall direct the trustee to pay such Plan Benefits from the respective Participants’ Accounts, and the Committee shall have authority to otherwise deal with and direct the trustee of such a Trust in matters pertinent to the Plan.
 
(e)  
It is intended that any Trust created hereunder is to be treated as a “grantor” trust under the Code, and the establishment of such a Trust is not intended to cause a Participant to realize current income on amounts contributed thereto, such a Trust is not intended to cause the Plan to be “funded” under ERISA and the Code, and any such Trust shall be so interpreted, and such Trust shall be funded in a manner that assets set aside or transferred to such Trust shall not be treated under Code Section 409A as property transferred in connection with the performance of services by reason of such assets being located or transferred outside the United States.
 
(f)  
Notwithstanding anything to the contrary expressed or implied herein, no transfer of assets shall be made under or in connection with the Plan or Compensation deferred under the Plan that would constitute a transfer of property within the meaning of Code Section 83 with respect to such Compensation by reason of such assets becoming restricted to the provision of benefits under the Plan in connection with a change in the Corporation’s financial health, as provided for under Code Section 409A, and Treasury Regulations issued thereunder.
 
11.3            Nonassignability
 
No right or interest under the Plan of a Participant or his or her Beneficiary (or any person claiming through or under any of them), shall be assignable or transferable in any manner or be subject to alienation, anticipation, sale, pledge, encumbrance or other legal process or in any manner be liable for or subject to the debts or liabilities of any such Participant or Beneficiary.  If any Participant or Beneficiary shall attempt to or shall transfer, assign, alienate, anticipate,
 

 
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sell, pledge or otherwise encumber his or her benefits hereunder or any part thereof, or if by reason of his or her bankruptcy or other event happening at any time such benefits would devolve upon anyone else or would not be enjoyed by him or her, then the Committee, in its discretion, may terminate such Participant’s or Beneficiary’s interest in any such benefit (including the Account) to the extent the Committee considers necessary or advisable to prevent or limit the effects of such occurrence. Termination shall be effected by filing a written instrument with the Secretary of the Corporation and making reasonable efforts to deliver a copy to the Participant or Beneficiary whose interest is adversely affected (the “Terminated Participant”).
 
As long as the Terminated Participant is alive, any benefits affected by the termination shall be retained by the Employer and, in the Committee’s sole and absolute judgment, may be paid to or expended for the benefit of the Terminated Participant, his or her spouse, his or her children or any other person or persons in fact dependent upon him or her in such a manner as the Committee shall deem proper. Upon the death of the Terminated Participant, all benefits withheld from him or her and not paid to others in accordance with the preceding sentence shall be disposed of according to the provisions of the Plan that would apply if he or she died prior to the time that all benefits to which he or she was entitled were paid to him or her.
 
11.4            Captions
 
The captions contained herein are for convenience only and shall not control or affect the meaning or construction hereof.
 
11.5            Governing Law
 
The provisions of the Plan shall be construed and interpreted according to the laws of the State of Oklahoma.
 
11.6            Successors
 
The provisions of the Plan shall bind and inure to the benefit of the Corporation, its Subsidiaries, and their respective successors and assigns. The term “successors” as used herein shall include any corporate or other business entity which shall, whether by merger, consolidation, purchase or otherwise, acquire all or substantially all of the business and assets of the Corporation or a Subsidiary and successors of any such corporation or other business entity.
 
11.7            No Right to Continued Service
 
Nothing contained herein shall be construed to confer upon any Eligible Employee the right to continue to serve as an Eligible Employee of the Employer or in any other capacity.
 
 
ONEOK, Inc.
 

 
By: 
                                                            

 
- 33 -

 

 
 
EXHIBIT A
 
ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
 
Re:
Section 3.1 – Eligible Employees
 
 
Effective Date:  December 18, 2008
 
Except as otherwise specifically determined by the Committee, the Committee has determined that the Chief Executive Officer of the Corporation is and shall in all cases be an Eligible Employee, and other Eligible Employees who may participate in the Plan shall be designated in writing by the Chief Executive Officer, or his designee, each Plan Year during the period after November 1 and prior to the next January 1 (“Designation Period”), with such designation to indicate the Eligible Employees for the Plan Year next following such Designation Period who shall be each Employee who (i) had Base Salary on November 1 of that Plan Year, which places such Employee in the group of Employees consisting of the top two percent (2%) of the Employees when ranked on the basis of Base Salary, (ii) is either an Officer of the Corporation or a highly compensated employee as defined in Code section 414(q), and (iii) is so designated by name in writing in an instrument signed by the Chief Executive Officer of the Corporation, or his designee. The designation of Eligible Employees for a Plan Year shall be reported to the Committee and Board in accordance with their directions.
 
An Employee must be an Eligible Employee prior to the beginning of a Plan Year in order to participate in the Plan for such Plan Year, unless otherwise determined by the Committee.
 
A list of the Eligible Employees who are so designated and approved for a Plan Year shall be made by the Chief Executive Officer, or his designee, the Committee, or by a duly authorized representative of the Committee, and be maintained with the Plan in the records of the Corporation.
 

 
- 34 -

 

 
 
EXHIBIT B
 
ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
 
Re:
Section 4.1 – Amount of Deferral
 
 
Effective Date: December 18, 2008
 
As of the date above, and effective until this Exhibit is modified by the Committee and Board, the table below indicates the types of compensation that are eligible for deferral by and in an Election of a Participant or the Corporation at the designated percentages stated:
 
Type of Compensation
Minimum Percentage
That Must Be Deferred
Maximum Percentage That May Be Deferred
Base Salary
2%
*90%
Bonus (or the portion above a specified threshold)
10%
*90%
 
Type of Compensation
Percentage That
Must Be Deferred
 
Qualified Employer Plan Amounts
100%
 
Supplemental Credit Amounts
100%
 
     
     
     
     
A Participant may defer Base Salary or Bonus only in 1% increments thereof.
 
*The Participant’s deferral shall be after deductions and withholding of amounts applicable to deferrals made by the Participant pursuant to other employee benefit plans of the Employer under Code Sections 125 and 401(k), and after deduction and withholding of all income and employment taxes required, as determined by the Committee and Employer, under uniform rules and procedures.
 

 
- 35 -

 

 
 
EXHIBIT C
 
ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
 
Re:
Section 2.1 – Investment Return
 
 
Date: December 18, 2008
 
A.  
Long-Term Deferrals
 
The Investment Return on a Participant’s Account for Long-Term Deferrals  shall be the rate determined pursuant to the following:
 
1.  
A Participant shall designate in writing to the Committee or its designee such deemed investments of the amount or amounts of his/her Account that are Long-Term Deferrals in the manner and form, and at such times as prescribed by the Committee.
 
2.  
Unless otherwise determined in written action of the Committee that is described in a written explanation furnished to Participants prior to it becoming effective, the Plan shall provide for an Investment Return on Long-Term Deferrals based upon the notional or deemed investments directed from time to time by the Participant of his or her Long-Term Deferrals in one or more of the investment options then being provided for participant directed investments under the Thrift Plan and Profit Sharing Plan. The Committee and its designees shall establish administrative procedures for allowing Participant direction of deemed investment and the determination of the Investment Return thereon for Long-Term Deferrals of Participants.
 
3.  
A Participant shall be allowed to change such designation at least once each calendar quarter, or more frequently as determined by the Committee, in its sole discretion. Such Investment Return shall be determined and calculated in the manner determined by the Committee, in its sole discretion, and added to or deducted from the amount or amounts of his/her Account that are Long-Term Deferrals periodically, not less frequently than annually. Such Investment Return Rate shall be so credited to or deducted from the amount or amounts of a Participant’s Account that are Long-Term Deferrals until all payments with respect thereto have been made to the Participant, or to the Participant’s designated Beneficiary pursuant to the Plan. The Employer shall not be liable or otherwise responsible for any decrease in a Participant’s Account because of the investment performance resulting from application of the foregoing provisions which make the Investment Return on the amount or amounts of a Participant’s Long-Term Deferrals under the Plan equivalent to the investment return that is realized by deemed investment of the Participant’s Long-Term Deferrals in his or her Account in Thrift Plan or Profit Sharing Plan investment options designated by the Participant.
 

 
- 36 -

 

Notwithstanding the foregoing, the Employer shall not be required to actually invest amounts deferred by a Participant nor the Account of any Participant in any particular form, type or amount of investment, and no Participant shall have the right to direct or in any manner control the actual investments, if any, made by the Employer or any other person for purposes of providing funds for paying the liabilities of the Employer for benefits or otherwise under the Plan; and a Participant shall not have any ownership or beneficial interest in any such actual investments that may be made by the Employer. In no event shall any Participant or Beneficiary have a right to receive an amount under the Plan other than that of a general unsecured creditor of the Employer notwithstanding the foregoing provisions with respect to the measurement and determination of a Participant’s Investment Return on his/her Long-Term Deferrals in his or her Account by reference to the performance of deemed investments in Thrift Plan or Profit Sharing Plan investment options designated by the Participant.
 
4.  
A Participant shall be entitled to elect to have the Investment Return credited to and deducted from Long-Term Deferrals in his or her Accounts under the Plan.  A Participant shall make an Election of such Investment Return at the time and in the manner prescribed by the Committee.
 
B.  
Short-Term Deferrals
 
For amounts deferred by a Participant as a Short-Term Deferral, the Investment Return will be the Five-Year Treasury Bond Rate as of the first business day of January of the Plan Year; provided, that the Corporation may determine such other Investment Return as it selects from time to time, in its discretion.
 

 
- 37 -

 

 
EXHIBIT D
 
ONEOK, Inc.
2005 NONQUALIFIED DEFERRED COMPENSATION PLAN
 
 
 
Re:
Section 6.2 – Crediting and Debiting of Investment Return,
 
Other Items To Participant Accounts
 
Date: December 18, 2008
 
A.  
The Account of each Participant shall be periodically credited and increased, or debited and reduced, as the case may be, by the amount of Investment Return specified under Section 6.3 of the Plan.
 
B.  
Except as otherwise provided herein, the Account shall be credited and debited with Investment Return and losses, if any, not less frequently than on a monthly basis after such Accounts have been adjusted for any deferrals, credits, debits, distributions and payments.
 
C.  
A Participant’s Accounts will be charged with cost of any deemed purchases of securities and credited with proceeds of any deemed sales of securities which may be considered as made in respect to the Investment Return specified in Exhibit “C” of the Plan by reason of changes in deemed investments designated by such Participant, in substantially the same manner as would occur if such securities were being purchased or sold by a Participant under the Thrift Plan and/or Profit Sharing Plan. The Committee may, in its sole discretion, allocate, charge and credit other items and amounts to such deemed purchases and sales in a manner comparable to the administration of such items under the Thrift Plan and/or Profit Sharing Plan, as determined applicable.
 
D.  
All of a Participant’s deferrals of Base Salary in a calendar month shall be deemed to be made as of the date it otherwise would have been paid to the Participant.
 
E.  
A Participant deferral of Bonus will be credited and debited with Investment Return from the date of deferral.
 
F.  
Until a Participant or his or her Beneficiary receives his or her entire account, the unpaid balance thereof shall be credited and debited with Investment Return as provided in Section 6.2 of the Plan.
 
G.  
A Retirement Plan Excess Amount shall be determined, taken into account and made payable to a Participant as determined by the Committee in accordance with Section 7.13 of the Plan.
 

 
- 38 -

Exhibit 10.9

 
 
ONEOK, INC.

DEFERRED COMPENSATION PLAN

FOR

NON-EMPLOYEE DIRECTORS

Amended and Restated as of December 18, 2008

ARTICLE I
ESTABLISHMENT OF PLAN

The Board of Directors of ONEOK, Inc., an Oklahoma corporation  (the "Company"), on January 15, 1998, established this ONEOK, Inc. Deferred Compensation Plan for Non-Employee Directors (the "Plan), a non-qualified deferred compensation plan pursuant to which any Director of the Company who is not an officer or present employee of the Company, and who is in a position to contribute to its continued growth, development and future financial success, may be offered an opportunity to defer all or a portion of his/her compensation under terms and conditions that will represent a meaningful benefit to such Director.

The Plan is amended and restated according to the terms stated herein, effective December 18, 2008, and all deferred amounts shall be subject to the terms hereof.

ARTICLE II
PURPOSE

The purpose of the Plan is to improve the Company's ability to attract and retain Non-Employee Directors who will contribute to the overall success of the Company.

ARTICLE III
  DEFINITIONS

"Beneficiary" shall mean any person designated by a Participant on a form furnished by the Plan Administrator.

"Board" shall mean the Board of Directors of the Company.
"Cash Deferral Option" shall mean the deferral option specified in Article IX of the Plan.

"Code" shall mean the Internal Revenue Code of 1986, as amended.

"Committee" shall mean the Executive Compensation Committee of the Board of Directors of the Company.

"Common Stock" shall mean the $0.01 par value Common Stock of the Company.

"Company" shall mean ONEOK, Inc., an Oklahoma corporation, or any successor thereto.

 

 


"Deferred Compensation" shall mean Director Compensation that is deferred by a Non-Employee Director pursuant to this Plan.

"Deferred Compensation Account" shall mean the deferred compensation account created by the Company which is payable to a participating Non-Employee Director under the Plan.

"Deferred Compensation Agreement" shall mean a written agreement to defer compensation as described in Article VII of the Plan.

"Determination Date" shall mean the last day of a Participant's term of service as a Non-Employee Director.

"Director" shall mean a member of the Board of Directors of the Company.

"Director Annual Cash Retainer Fee" shall mean an annual retainer fee paid in cash by the Company to a Non-Employee Director for service in or for a Plan Year.

"Director Annual Stock Retainer Fee" shall mean an annual retainer fee paid in Common Stock by Company to a Non-Employee Director for service in or for a Plan Year.

"Director Board Meeting Fee" shall mean a per meeting fee paid by the Company to a Non-Employee Director for service and attendance at a Board meeting.

"Director Committee Chair Fee" shall mean a fee paid by the Company to a Non-Employee Director for service as the chairperson of a committee of the Board in or for a Plan Year.

"Director Compensation" shall mean the compensation paid or payable to an individual for his/her services as a Non-Employee Director.

“Director Retainer Fees” means the Director Annual Cash Retainer Fee and Director Annual Stock Retainer Fee.

"Director Services Fee" shall mean such other fees or compensation as the Company may pay to a Non-Employer Director in lieu of or in addition to Director Retainer Fees, Director Committee Chair Fees and Director Board Meeting Fees.

"Disabled" and/or "Disability" shall mean that a Participant is unable to engage in substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident or health plan covering employees of any employer by whom such participant is employed.  A Participant will be deemed to be

 
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Disabled if such Participant is determined to be totally disabled by the Social Security Administration.

"Distributable Balance" shall mean the balance of a Participant's Deferred Compensation Account on the Determination Date as provided in paragraph XI of the Plan.

"Distribution Date" shall mean the date on which distribution of amounts distributable to a Participant under the Plan and Deferred Compensation Agreement is to be made and/or commenced.

"Dividend Reinvestment Plan" means the dividend reinvestment plan established and maintained by or for the Company with respect to Common Stock.

"Election" shall mean an irrevocable written election to defer compensation made by a Non-Employee Director pursuant to the Plan that shall specify the Specified Time of Distribution and Specified Form of Distribution of Deferred Compensation.

"Employee" shall mean an individual who is employed by the Company or any subsidiary or affiliate thereof.

"Equity Compensation Plan" shall mean the ONEOK, Inc. Equity Compensation Plan.

"Fair Market Value" shall mean on a particular date the average of the high and low sale prices of a share of Common Stock in consolidated trading on the date in question as reported by The Wall Street Journal or another reputable source designated by the Committee; provided that if there were no sales on such date reported as provided above, the respective prices on the most recent prior day for which a sale was so reported.

"Fixed Schedule" shall mean the distribution or payment of Deferred Compensation deferred under the Plan in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such compensation is first elected by the Participant or Company under the Plan.

"Investment Return Rate" shall mean the deemed investment rate of return to be credited to a Participant's Deferred Compensation Account pursuant to Articles  X and XI of the Plan.

"Long-Term Incentive Plan" shall mean the Long-Term Incentive Plan of the Company.

"Non-Employee Director" shall mean any director of the Company who is not also an employee of the Company.

"Participant" shall mean any Non-Employee Director of the Company who elects to defer compensation under the Plan.

"Phantom Stock Option" shall mean the deferral option specified in Article  IX of the Plan.

 
3

 

"Plan" shall mean this ONEOK, Inc. Deferred Compensation Plan for Non-Employee Directors as set forth in its entirety in this document as it may be amended from time to time.

"Plan Administrator" shall mean the Executive Compensation Committee of the Company's Board of Directors or any other committee appointed by the Board of Directors to act in that capacity.

"Plan Year" shall mean the calendar year.

"Section 409A" shall mean section 409A of the Internal Revenue Code of 1986, as amended.

"Specified Employee" shall mean an Employee who, as of the date of the Employee's separation from service, is a key employee of the Company if any stock of the Company is then publicly traded on an established securities market or otherwise; and for purposes of this definition, an Employee is a key employee if the Employee meets the requirements of Code Section 416(i)(1)(A)(i), (ii), or (iii) (applied in accordance with the regulations thereunder and disregarding section 416(i)(5)) at any time during the 12-month period ending on a Specified Employee Identification Date. If an Employee is a key employee as of a Specified Employee Identification Date, the Employee shall be treated as a key employee for purposes of the Plan for the entire 12-month period beginning on the Specified Employee Effective Date. For purposes of identifying a Specified Employee by applying the requirements of section 416(i)(1)(A)(i), (ii), and (iii), the definition of compensation under §1.415(c)-2(a) shall be used, applied as if the Company were not using any safe harbor provided in §1.415(c)-2(d), were not using any of the elective special timing rules provided in §1.415(c)-2(e), and were not using any of the elective special rules provided in §1.415(c)-2(g).

"Specified Employee Effective Date" shall mean the first day of the fourth month following the Specified Employee Identification Date.

"Specified Employee Identification Date" shall mean December 31.

“Specified Form of Distribution” shall mean a specified form of distribution of Compensation deferred that is deferred by a Participant’s Election and Deferred Compensation Agreement.

"Specified Time" shall mean a date or dates that are not discretionary and objectively determinable at the time an amount of compensation is deferred and at which objectively determinable deferred amounts are to be payable.

"Specified Time of Distribution" shall mean a Specified Time at which Deferred Compensation that is deferred by a Participant’s Election and Deferred Compensation Agreement pursuant to the Plan is required to be distributed or paid and which is specified in writing by the Participant in and at the time the deferral of such Deferred Compensation is elected by the Election of a Participant.

 
4

 

"Subsequent Election" shall mean an election made by a Participant with respect to the time of distribution or payment of Deferred Compensation under the Plan that is made at any time after the Election and Deferred Compensation Agreement that is made by the Participant and/or the Company with respect to such Deferred Compensation, an election made by a Participant with respect to the time of distribution or payment of Deferred Compensation under the Plan that is made at any time after the next preceding Subsequent Election, if any, that has been made by the Participant and/or the Company with regard to such Deferred Compensation.

"Subsequent Election Specified Date" shall mean a specified fixed date in a calendar year that must be specified in writing by the Participant in a Subsequent Election that is not less than five (5) years from the date payment would otherwise have been made to the Participant under the Plan if such Subsequent Election was not made by the Participant. The written specification of the Subsequent Election Specified Date shall in all cases specify and fix a Specified Time that is not less than five (5) years from the date payment would otherwise have been made to the Participant.

"Subsequent Election Specified Time of Distribution" shall mean a Specified Time that a Participant is allowed by the Committee to elect in a Subsequent Election and that is on a Subsequent Election Specified Date.

"Taxable Year" shall mean the Plan Year commencing January 1 and ending the following December 31.

"Unforeseeable Emergency" shall mean a severe financial hardship to the Participant resulting from illness or accident of the Participant, the Participant’s spouse, or a dependent (as defined in Code Section 152(a)) of the Participant, loss of the Participant’s property due to casualty, or other similar extraordinary circumstances arising as a result of events beyond the control of the Participant, including such events and circumstances as are described and considered to be an unforeseeable emergency under Code section 409A and the regulations thereunder. It is intended and directed with respect to any such unforeseeable emergency that any amounts distributed under the Plan by reason thereof shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participant’s assets (to the extent the liquidation of such assets would not itself cause severe financial hardship).

ARTICLE IV
EFFECTIVE DATE

The Plan was adopted, established and initially effective January 15, 1998, and is  amended and restated in its entirety in this Plan document, effective December 18, 2008.

ARTICLE V
ELIGIBILITY

All Non-Employee Directors of the Company shall be eligible to participate in the Plan.

 
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ARTICLE VI
NON-EMPLOYEE DIRECTOR COMPENSATION DEFERRAL

Non-Employee Directors of the Company are customarily paid an annual Director Compensation by the Company in the form of a Director Annual Retainer Fee and a per meeting fee.  Non-Employee Directors who chair a committee of the Board customarily also receive an additional annual retainer for that position.  The Company may from time to time pay other kinds or amounts of compensation to Non-Employee Directors of the Company.  The Plan allows the Non-Employee Directors to elect to defer all, part, or none of their Director Compensation, and to have two (2) deemed investment options, either the Cash Deferral Option or the Phantom Stock Option, from which to choose as more specifically provided below.

ARTICLE VII
ELECTION TO DEFER DIRECTOR COMPENSATION

A.            Participant Elections .  The Plan is a voluntary participation plan, pursuant to which a Non-Employee Director may make an Election to irrevocably defer the designated portion of his/her Director Compensation for a Plan Year.

1.           An Election by a Non-Employee Director to his/her Director Compensation shall be  made for a Plan Year by executing and entering into an irrevocable written Election and Deferred Compensation Agreement with the Company on or before December 31 of the calendar year next preceding the Plan Year for which the Non-Employee Director elects to defer Director Compensation.

2.           A separate irrevocable Election and Deferred Compensation Agreement shall be made for each Plan Year a Non-Employee Director elects to defer his/her Director Compensation under the Plan; provided, however, if a Non-Employee Director has made an irrevocable Election to defer Director Compensation under the Plan for a Plan Year, such Election and Deferred Compensation Agreement shall remain in effect and be applicable and irrevocable for the next following Plan Year if a new and separate Election and Deferred Compensation Agreement is not made and entered into on or before December 31 of the current Plan Year.

3.           Notwithstanding the foregoing, in the initial 1998 Plan Year of the Plan, each Non-Employee Director may elect to defer Director Compensation payable to him/her for that Plan Year by entering into a Deferred Compensation Agreement before the earlier of the date of his receipt of payment of the compensation elected to be deferred, or February 1, 1998.

4.           Any Non-Employee Director otherwise elected or appointed for the first time to the Board may elect to defer Director Compensation by making and entering into an irrevocable written Election and Deferred Compensation Agreement within thirty (30) days after his/her initial election or appointment to the Board that shall apply to his/her Director Compensation payable after the date of such Election and Deferred Compensation Agreement.  Any such initial Election shall be effective for the Plan Year in which it is made, and thereafter such new Non-Employee Director shall make his/her Election to defer for subsequent Plan Years pursuant to the first grammatical paragraph of this Article  VII.

 
6

 


5.           A Non-Employee Director who is to participate in the Plan and defer Director Compensation must elect the amount, if any, to be deferred, the type of Deferral Option, and the time and form of payment, all of which are more specifically described below.

B.            Company Elections .  Notwithstanding the foregoing or other provisions of the Plan, the Company shall be authorized to determine and separately determine and elect the time and the form of payment of all of certain types of Director Deferred Compensation.  The Company determination and election in such case shall be made by written action of the Committee or its designee, which shall be taken and made no later than the Participant becomes entitled to the amount thereof by such designation and election, or if later, the time the Participant would be required to make an election if the Participant were provided such election.  The Company or Committee may in any such case provide that a Participant shall have no right or opportunity to make any election with respect to the amount of deferral and time and form of payment.

C.            Participant Subsequent Elections .  If the Plan, Company or Committee acting pursuant to and in accordance with the Plan permits a Subsequent Election under which a delay in a time of payment or a change in form of payment of Director Compensation deferred by a Non-Employee Director by his/her Election and Participation Agreement under the Plan, such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made.  In the case of a Subsequent Election related to a payment to be made as elected in an Election or any prior Subsequent Election, the first payment with respect to which such Subsequent Election is made shall be deferred for a period of at least five (5) years from the date such payment would otherwise have been made.  Any Subsequent Election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date the first scheduled payment to which it relates.

ARTICLE VIII
AMOUNT OF DEFERRAL; DIRECTOR COMPENSATION DEFERRALS

A.            Deferral Amounts .  A Non-Employee Director who elects to participate in the Plan as a Participant thereof, may defer all, a portion or none of the following types of Director Compensation for a Plan Year, as applicable:

1.           Director Annual Stock Retainer Fee

2.           Director Annual Cash Retainer Fee

3.           Director Chair Retainer Fee

4.           Director Board Chair Retainer Fee

5.           Director Board Meeting Fee

6.           Any other Director Services Fees

 
7

 

B.            Designation .  The deferral shall be designated in the Non-Employee Director’s Election and Participation Agreement as a percentage of the form and amount of the type of Director Compensation to which it applies.

ARTICLE IX
DEFERRAL OPTIONS

A.            Deferral Options .  A Non-Employee Director who makes an Election to defer his/her Director Compensation for a Plan Year may elect either:

1.           A Cash Deferral Option; or

2.           A Phantom Stock Option.

All amounts deferred are subject to the terms of the option elected.  The Election shall be  made as part of the Election procedure described in paragraph VII, above.

B.            Cash Deferral Option .  Under the Cash Deferral Option, a participating Non-Employee Director may elect to defer the receipt of the cash part of all or a portion of such Non-Employee Director's annual retainer and/or meeting fee.  Interest will accrue at the rate defined in paragraph X, below.


C.            Phantom Stock Option

1.           Under the Phantom Stock Option, prior to November 19, 1998, a participating Non-Employee Director may elect to defer all or a portion of such Non-Employee Director's annual retainer and/or meeting fee; and/or after November 19, 1998, a participating Non-Employee Director may elect to defer all or a portion of such fees the Director has elected to receive in shares of Common Stock under the Company's Long-Term Incentive Plan, or Equity Compensation Plan, as applicable.

2.           The electing Non-Employee Director shall receive credit for phantom "stock units" that are deemed to represent shares of Common Stock equivalent in value to the amount deferred.  The phantom "stock units" will be initially measured and calculated based upon the Fair Market Value of the Common Stock on the date of the Non-Employee Director's Election, , or next preceding date of an available Fair Market Value, if applicable.

3.           The number of phantom "stock units" received in lieu of cash is dependent on the Fair Market Value of Common Stock on the measurement date.  The number of phantom "stock units" received in lieu of shares of Common Stock shall be equal to the number of shares deferred.

4.           "Fractional stock units" will be accounted for as non-interest bearing cash.

5.           The measurement date is the regular payment date of the annual retainer, committee chair annual retainer, if applicable, and/or meeting fee.

 
8

 


6.           Dividend reinvestment attributable to such phantom "stock units" shall be credited as provided in Article X, below.

 ARTICLE X
DEFERRED COMPENSATION ACCOUNT

A.            General .  The Company shall establish a separate "Deferred Compensation Account" for each Non-Employee Director who becomes a Participant in the Plan and elects to defer Director Compensation under the Plan and shall credit such Deferred Compensation Account with the Director Compensation deferred by the Non-Employee Director.

B.            Interest Rate .  The amount deferred under the Cash Deferral Option (including interest earned thereon) will earn interest at the Investment Return Rate determined annually by the Committee which shall be the Moody's AAA 30-Year Bond Index on the first business day of the Plan Year, plus 100 basis points.  Interest will be credited quarterly (on the 1st day of April, July, October and January) at the applicable Investment Return Rate.

C.            Deemed Dividends .  The Deferred Compensation Account of a Non-Employee Director who has elected the Phantom Stock Option, shall have phantom or deemed "dividends" on the phantom "stock units" in his/her Deferred Compensation Account credited to such Account in an amount equal to the dividends paid on  Common Stock.  The deemed dividend equivalent received will be treated in a manner similar to the treatment of dividends under the Dividend Reinvestment Plan when a Participant therein elects to have dividends reinvested in Common Stock, and will be deemed to be used to purchase additional phantom "stock units" representing Company's Common Stock at the closing price of the stock on the date the Common Stock dividend is paid.  Any fractional stock units will be accounted for as non-interest bearing cash.  The Deferred Compensation Account shall also be adjusted for any stock dividends, stock splits, etc.  In the event the Dividend Reinvestment Plan is modified in any way, such deemed dividends credited through this Plan will be handled in accordance with said modification.  If the Dividend Reinvestment Plan is terminated, such deemed dividends credited through this Plan will continue to be reinvested in accordance with the provisions of the terminated Dividend Reinvestment Plan.

D.            Amount of Account .  The amount equal to the balance in the Deferred Compensation Account of the Participant, taking into account all credits, shall be the amount a Participant shall be entitled to receive under the terms of the Plan; provided, that with respect to all deferrals into phantom "stock units," including those deferrals made prior to November 19, 1998 the phantom "stock units" will be settled in shares of Common Stock made available under the Long-Term Incentive Plan, or Equity Compensation Plan.

E.            Statement of Account .  The Company shall furnish or cause to be furnished to each Participant in the Plan an annual statement of his/her Deferred Compensation Account.

 
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ARTICLE XI
DISTRIBUTIONS AND PAYMENTS

           A.            Requirements for Distributions and Payments .  Notwithstanding anything to the contrary expressed or implied herein, the following requirements shall apply to the Plan, to all Elections or Subsequent Elections made by Participants under the Plan, and to all distributions and payments made pursuant to the Plan.

1.           Any compensation deferred under the Plan shall not be distributed earlier than:

a.           Separation from Service of the Participant,

b.           the date the Participant becomes Disabled,

c.           death of the Participant,

d.           a Specified Time (or pursuant to a Fixed Schedule) specified under the Plan at the date of deferral of such compensation,

e.           a change in ownership or control, or

f.           the occurrence of an Unforeseeable Emergency.

2.           Notwithstanding the foregoing, in the case of any Participant who is a Specified Employee, no distribution shall be made before the date which is six (6) months after the date of the Participant’s Separation from Service, or, if earlier, the date of death of such Participant.

3.           No acceleration of the time or schedule of any distribution or payment under the Plan shall be permitted or allowed, except to the extent provided in Treasury Regulations issued under Code Section 409A.

4.           If the Plan, or the Committee acting pursuant to the Plan, permits under any Subsequent Election by a Participant a delay in a payment or a change in the form of payment of Compensation deferred under the Plan, such Subsequent Election shall not take effect until at least twelve (12) months after the date on which it is made.  In the case of a Subsequent Election related to a payment to be made upon Separation from Service of a Participant, at a Specified Time or pursuant to a Fixed Schedule, or upon a change in ownership or control, the first payment with respect to which such Subsequent Election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such Subsequent Election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.

B.            Distribution Options .  By the written irrevocable Election of the Non-Employee Director t and Deferred Compensation Agreement he/she must select one of the following forms  of payment of the amount of Director Compensation deferred (and interest or deemed dividends credited thereto) from his/her Deferred Compensation Account:

 
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1.           A payment in a single distribution immediately upon his/her Determination Date; or

2.           Payment amounts of cash deferred in monthly installments over a specified number of years, and commencing at a time on or after his/her Determination Date as designated by the Participant's irrevocable election; or

3.           A payment of phantom stock units deferred in a single distribution of Common Stock on a Distribution Date elected by him/her in accordance with the Plan.

C.            Determination Date .  The Distributable Balance in the Deferred Compensation Account with respect to any Plan Year shall become fixed and determined at a Participant's Determination Date.

D.            Distributable Balance .  The Distributable Balance in the Deferred Compensation Account of a Participant for any deferrals under the Cash Deferral Option is the cash balance of such Deferred Compensation Account at the Participant's Determination Date.

E.            Determination of Distributable Balance .  The Distributable Balance in the Deferred Compensation Account of a Participant for any deferrals under the Phantom Stock Option shall be , prior to the effective date of this amendment and restatement, an amount equal to the Fair Market Value of the phantom "stock units" in such Deferred Compensation Account at Participant's Determination Date and on or after the effective date of this amendment and restatement, the number of shares of Common Stock equal to the number of phantom "stock units" plus any cash amounts held in respect of fractional "stock units."

F.            Valuation .  At the Determination Date of a Participant, such Participant's Deferred Compensation Account Distributable Balance for all Plan Years shall be valued.  From that Determination Date forward, any remaining cash balance in the Account (i.e., balance during the time of installment payments) shall bear interest at the Investment Return Rate and any remaining phantom "stock unit" balance shall continue to be credited with "dividends" as provided in paragraph X above.  In the event a Participant elects payment of the cash balance of the Participant's Deferred Compensation Account Distributable Balance in installments, each installment shall be calculated by dividing the then value of that portion of the Deferred Compensation Account which is in cash by the number of installments remaining as of such date.  To the extent the Distributable Balance is payable and distributable in shares of Common Stock of the Company, that part of the Participant's Deferred Compensation Account that consists of phantom stock units and phantom dividends shall be payable in shares of Common Stock which shall be issued in a single distribution to the Participants under the Company's Long-Term Incentive Plan or Equity Compensation Plan on the Distribution Date elected by the Participant.

G.            Distribution; Disability or Death of Participant .  Distribution of a Participant's Distributable Balance shall commence immediately upon the occurrence of the Disability or death of the Participant, if such event occurs prior to the Distribution Date elected by the Participant, and such distribution shall be made in the form elected by the Participant.  In such a case, the Distributable Balance in the Deferred Compensation Account of the Participant shall be

 
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determined as of the date of such event in like manner as if such event was a Determination Date for such Participant.

H.            Distributions Continued .  Distribution of the Distributable Balance in the form elected by the Participant shall continue in the event of Disability or death of the Participant on or after the Distribution Date.

I.            Form of Distribution; Disability .  Distribution of the Distributable Balance in the form elected by the Participant shall be made to the Participant in the event of Disability of such Participant; provided, that the Committee may, in its sole discretion, direct that such distribution instead be made to a guardian or other representative of a Participant who is disabled.

J.            Form of Distribution; Death of Participant .  Each Non-Employee Director who is a Participant shall also designate a Beneficiary to receive the unpaid balance of the value of the Participant's Deferred Compensation Account in the event of the Participant's death prior to complete distribution of such unpaid balance of the Account.  The unpaid balance shall be received in the form elected by the Participant.  If no Beneficiary is designated, then the Participant's Deferred Compensation Account shall be distributed to the estate of the deceased Participant.

K.            No Acceleration of Distribution and Payment .  No acceleration of the time or schedule of any payment or amount scheduled to be paid pursuant to the terms of the Plan shall be allowed, and no such accelerated payment may be made whether or not provided for under the expressed or implied terms of such Plan.  Provided, that there may be an acceleration of a payment in accordance with the express provisions allowing the same under the Treasury regulations issued under Code Section 409A or the Committee may have discretion to permit such acceleration to be made consistent with the regulations.  Provided, that a Participant shall have no discretion with respect to whether a payment will be accelerated, and the Corporation or Committee shall not provide a Participant a direct or indirect election as to whether the Corporation’s or Committee’s discretion to accelerate a payment will be exercised, even if such acceleration would be permitted under the regulations.

 ARTICLE XII
NON-ASSIGNABILITY

The right of a Non-Employee Director or Beneficiary to receive payments under this Plan shall not be pledged, assigned, transferred or subject to garnishment attachment or other legal process by creditors of such Non-Employee Director or Beneficiary.

 ARTICLE XIII
ADMINISTRATION OF THE PLAN

The Plan shall be administered by the Executive Compensation Committee of the Board, or by such other Committee as may be appointed and designated by the Board to administer the Plan from time to time.  The Executive Compensation Committee shall supervise and direct the administration and operation of the Plan, and shall have such powers and duties as are specified in the Plan, or are otherwise necessary and appropriate thereto.  The Committee, in its sole

 
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discretion, may establish rules and procedures governing the administration of the Plan, and shall have the power to interpret provisions of the Plan, and construe and determine the effect of Participant Deferred Agreements and other instruments pertaining to the Plan, and all actions taken by the Executive Compensation Committee pursuant to the foregoing shall be binding on all Participants, Beneficiaries and other persons.

ARTICLE XIV
FUNDING

A.            Company Obligation .  The amounts of compensation deferred by any Non-Employee Director under this Plan shall constitute an unfunded and unsecured promise by the Company to pay such Non-Employee Director the deferred compensation from the general assets of the Company in the future.

B.            Nonqualified Trust .  Although the Company may make, in its sole discretion, investments for the purpose of providing funds to pay such unsecured obligations made by it to the Plan, any such investments shall remain the sole and exclusive property of the Company subject to claims of its creditors generally; provided, that the Company may, at its option, create a grantor or rabbi trust to pay part or all of its obligations under the Plan as it determines to the extent permissible without changing the unfunded and unsecured nature of its deferred compensation obligations to Participants under the Plan.

ARTICLE XV
STATE LAWS GOVERNING PLAN

This Plan shall be governed by the laws of the State of Oklahoma.

ARTICLE XVI
AMENDMENT OR TERMINATION OF PLAN

This Plan shall continue in effect until amended or terminated by the Board of Directors.  Any such amendment or termination shall not adversely affect any Deferred Compensation Account of a Participant then in existence under the Plan or any rights of a Participant under a Deferred Compensation Agreement entered into with a Participant prior to such amendment or termination.

Amended and Restated the 18 th day of December, 2008.


ONEOK, Inc. 








 
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Exhibit 10.44
 

ONEOK, INC.
 
EQUITY COMPENSATION PLAN
 
Amended and Restated December 18, 2008
 
1.  
General
 
1.1   Purposes . The purposes of this Plan are (a) to provide competitive incentives that will enable the Company to attract, retain, motivate, and reward eligible Employees and Non-Employee Directors of the Company, and (b) to give the Company’s eligible Employees and Non-Employee Directors an interest parallel to the interests of the Company’s shareholders generally.
 
1.2   Duration of Plan . The date of adoption and term of the Plan are as follows:
 
(a)   The Plan was initially adopted and effective on February 17, 2005, the date of its first adoption and approval by the Board of Directors, such adoption of the Plan having been approved by the shareholders of the Company within one (1) year of that date, on May 19, 2005.  The term of the Plan as so initially adopted and approved was until a termination date of February 17, 2015, or until sooner terminated by the Board of Directors.
 
(b)   The Plan, as amended and restated in and by this instrument, is effective on an Effective Date of February 21, 2008, the date of its adoption and approval by the Board of Directors, provided that the shareholders of the Company thereafter approve it within one (1) year of that date.  If the Plan, as so amended and restated, is so approved by the shareholders of the Company, it shall have an extended term and shall terminate on a termination date of February 21, 2018, or until sooner terminated by the Board of Directors.
 
(c)   If the Plan, as so amended and restated in and by this instrument, is not so approved by the shareholders of the Company, the amendments thereto and this instrument shall not become effective and shall be of no force and effect, and the Plan shall remain in effect in accordance with its written terms and provisions as initially adopted and approved.
 
(d)   The Plan shall remain in effect until its termination date, or until the Plan is sooner terminated by the Board of Directors, and upon its termination shall continue to be administered thereafter with respect to any Stock Incentive granted prior to the date of such termination.
 
(e)   In no event shall a Stock Incentive be granted under the Plan more than ten (10) years from February 21, 2008, the date the Plan, as amended and restated in and by this instrument, is adopted.
 

 
 

 

1.3           The Company intends that Stock Incentives and Awards granted pursuant to the Plan be exempt from or comply with Section 409A and Treasury Regulations thereunder and the Plan shall be so construed.
 
1.4            Amended and Restated Plan Document .  The Plan is amended and restated in the form of this instrument effective December 18, 2008.
 
2.  
Definitions
 
Unless otherwise required by the context, the following terms, when and wherever used in this Plan, shall have the meanings set forth in this Section 2.
 
2.1   “Award” means an award of a Stock Incentive that is made under the Plan.
 
2.2   “Award Agreement” means a written instrument that is an agreement that evidences an Award and terms and provisions of a Stock Incentive granted under the Plan, pursuant to Section 15.4 or other provisions of the Plan.
 
2.3   “Beneficiary” means a person or entity (including a trust or estate), designated in writing by a Participant on such forms and in accordance with such terms and conditions as the Committee may prescribe, to whom the Participant’s rights under the Plan shall pass in the event of the death of the Participant.
 
2.4   “Board” or a “Board of Directors” means the Board of Directors of the Company, as constituted from time to time.
 
2.5   A “Change in Control” shall mean the occurrence of any of the following:
 
(a)   An acquisition (other than directly from the Company) of any voting securities of the Company (the “Voting Securities”) by any “Person” (as the term person is used for purposes of Section 13(d) or 14(d) of the Exchange Act), immediately after which such Person has “Beneficial Ownership” (within the meaning of Rule 13d-3 promulgated under the Exchange Act) of twenty percent (20%) or more of the then outstanding Shares or the combined voting power of the Company’s then outstanding Voting Securities; provided, however , in determining whether a Change in Control has occurred pursuant to this Section 2(c), Shares or Voting Securities which are acquired in a “Non-Control Acquisition” (as hereinafter defined) shall not constitute an acquisition which would cause a Change in Control.  A “Non-Control Acquisition” shall mean an acquisition by (i) an employee benefit plan (or a trust forming a part thereof) maintained by (A) the Company or (B) any company or other Person of which a majority of its voting power or its voting equity securities or equity interest is owned or controlled, directly or indirectly, by the Company (for purposes of this definition, a “Related Entity”), (ii) the Company or any Related Entity, or (iii) any Person in connection with a “Non-Control Transaction” (as hereinafter defined);
 
(b)   The individuals who, as of February 15, 2001, are members of the Board of Directors (the “Incumbent Board”), cease for any reason to constitute at least a majority of the members of the Board of Directors; or, following a Merger which results
 

 
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in a Parent Company, the board of directors of the ultimate Parent Company; provided, however, that if the election, or nomination for election by the Company’s common stockholders, of any new director was approved by a vote of at least two-thirds of the Incumbent Board, such new director shall, for purposes of this Plan, be considered as a member of the Incumbent Board; provided further, however, that no individual shall be considered a member of the Incumbent Board if such individual initially assumed office as a result of either an actual or threatened “Election Contest” (as described in Rule 14a-11 promulgated under the Exchange Act) or other actual or threatened solicitation of proxies or consents by or on behalf of a Person other than the Board of Directors (a “Proxy Contest”), including by reason of any agreement intended to avoid or settle any Election Contest or Proxy Contest; or
 
(c)   The consummation of:
 
(1)   A merger, consolidation or reorganization with or into the Company or in which securities of the Company are issued (a “Merger”), unless such Merger is a “Non-Control Transaction.” A “Non-Control Transaction” shall mean a Merger where:
 
(A)   the stockholders of the Company, immediately before such Merger, own directly or indirectly immediately following such Merger at least fifty percent (50%) of the combined voting power of the outstanding voting securities of (x) the company resulting from such Merger (the “Surviving Company”) if fifty percent (50%) or more of the combined voting power of the then outstanding voting securities of the Surviving Company is not Beneficially Owned, directly or indirectly by another Person (a “Parent Company”), or (y) if there is one or more Parent Companies, the ultimate Parent Company;
 
(B)   the individuals who were members of the Incumbent Board immediately prior to the execution of the agreement providing for such Merger constitute at least a majority of the members of the board of directors of (i) the Surviving Company, if there is no Parent Company, or (ii) if there is one or more Parent Companies, the ultimate Parent Company; and
 
(C)   no Person other than (1) the Company, (2) any Related Entity, (3) any employee benefit plan (or any trust forming a part thereof) that, immediately prior to such Merger was maintained by the Company or any Related Entity, or (4) any Person who, immediately prior to such Merger had Beneficial Ownership of thirty percent (30%) or more of the then outstanding Voting Securities or Shares, has Beneficial Ownership of thirty percent (30%) or more of the combined voting power of the outstanding voting securities or common stock of (i) the Surviving Company if there is no Parent Company, or (ii) if there is one or more Parent Companies, the ultimate Parent Company.
 

 
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(2)           A complete liquidation or dissolution of the Company; or
 
(3)           The sale or other disposition of all or substantially all of the assets of the Company to any Person (other than a transfer to a Related Entity or under conditions that would constitute a Non-Control Transaction with the disposition of assets being regarded as a Merger for this purpose or the distribution to the Company’s stockholders of the stock of a Related Entity or any other assets).
 
Notwithstanding the foregoing, a Change in Control shall not be deemed to occur solely because any Person (the “Subject Person”) acquired Beneficial Ownership of more than the permitted amount of the then outstanding Shares or Voting Securities if: (1) such acquisition occurs as a result of the acquisition of Shares or Voting Securities by the Company which, by reducing the number of Shares or Voting Securities then outstanding, increases the proportional number of shares Beneficially Owned by the Subject Person, provided that if a Change in Control would occur (but for the operation of this subparagraph) as a result of the acquisition of Shares or Voting Securities by the Company, and after such share acquisition by the Company, the Subject Person becomes the Beneficial Owner of any additional Shares or Voting Securities which increases the percentage of the then outstanding Shares or Voting Securities Beneficially Owned by the Subject Person, then a Change in Control shall occur, or (2) (A) within five business days after a Change in Control would have occurred (but for the operation of this subparagraph), or if the Subject Person acquired Beneficial Ownership of twenty percent (20%) or more of the then outstanding Shares or the combined voting power of the Company’s then outstanding Voting Securities inadvertently, then after the Subject Person discovers or is notified by the Company that such acquisition would have triggered a Change in Control (but for the operation of this subparagraph), the Subject Person notifies the Board of Directors that it did so inadvertently, and (B) within two business days after such notification, the Subject Person divests itself of a sufficient number of Shares or Voting Securities so that the Subject Person is the Beneficial Owner of less than twenty percent (20%) of the then outstanding Shares or the combined voting power of the Company’s then outstanding Voting Securities.
 
Notwithstanding anything in this Plan to the contrary, if an eligible Employee’s employment is terminated by the Company without Just Cause prior to the date of a Change in Control but the eligible Employee reasonably demonstrates that the termination (1) was at the request of a third party who has indicated an intention or taken steps reasonably calculated to effect a Change in Control or (2) otherwise arose in connection with, or in anticipation of, a Change in Control which has been threatened or proposed, such termination shall be deemed to have occurred after a Change in Control for purposes of this Plan, provided a Change in Control shall actually have occurred.
 
Notwithstanding the foregoing, the Committee may from time to time provide in the written terms and provisions of a Stock Incentive instrument, Award or Award Agreement that a different definition of the terms Change in Ownership or Control shall apply and determine the time of settlement, distribution and payment of an Award for purposes of Section 409A and any deferral of compensation subject to the requirements of Section 409A under the Plan.
 

 
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2.6           “Code” means the Internal Revenue Code of 1986, as amended and in effect from time to time.  References to a particular section of the Code shall include references to any related Treasury Regulations and to successor provisions.
 
2.7   “Committee” means the Committee appointed by the Board of Directors to administer the Plan pursuant to the provisions of section 14.1 below.
 
2.8   “Common Stock” means common stock, $0.01 par value, of the Company.
 
2.9   “Company” means ONEOK, Inc., an Oklahoma corporation, its successors and assigns, or any division or Subsidiary thereof.
 
2.10   “Deferred Compensation Program” means a program established by the Committee providing for the deferral of compensation with respect to Awards pursuant to sections 10 and 11.
 
2.11   “Director Fees” means all compensation and fees paid to a Non-Employee Director by the Company for his or her services as a member of the Board of Directors.
 
2.12   “Director Stock Award” means an award of ONEOK, Inc. Common Stock granted to a Non-Employee Director.
 
2.13   “Effective Date” means February 21, 2008, the date the Plan, as now amended and restated in and by this instrument, was adopted, as described in Section 1.2, above.
 
2.14   “Employee” means an employee of the Company, including an officer or director who is such an employee.
 
2.15   “Exchange Act” means the Securities Exchange Act of 1934, as amended from time to time.
 
2.16   “Fair Market Value” on a particular date means the average of the high and low sale prices of a share of Common Stock in consolidated trading on the date in question as reported by The Wall Street Journal or another reputable source designated by the Committee; provided that if there were no sales on such date reported as provided above, the respective prices on the most recent prior day for which a sale was so reported.  In the case of an Incentive Stock Option, if the foregoing method of determining Fair Market Value should be inconsistent with section 422 of the Code, or in the case of any other type of Stock Incentive the foregoing method is determined by the Committee, in its discretion, to not be applicable, a “Fair Market Value” shall be determined by the Committee in a manner consistent with such section of the Code, or in such other manner as the Committee, in its discretion, determines to be appropriate, and shall mean the value as so determined.
 
Notwithstanding the foregoing, the Committee may, in its discretion, determine the Fair Market Value of a share of Stock on the basis of the opening, closing, or average of the high and low sale prices of a share of Stock on such date or the preceding trading day, the actual sale price of a share of Stock received by a Participant, any other reasonable basis using actual transactions in the Stock as reported on a national or regional securities exchange or market
 

 
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system and consistently applied, or on any other basis consistent with the requirements of Section 409A.  The Committee may vary its method of determination of the Fair Market Value as provided in this Section for different purposes under the Plan to the extent consistent with the requirements of Section 409A.
 
2.17   “General Counsel” means the General Counsel of the Company serving from time to time.
 
2.18   “Incentive Stock Option” means an option, including an Option as the context may require, intended to qualify for the tax treatment applicable to incentive stock options under section 422 of the Code.
 
2.19   “Just Cause” shall mean the Employee’s conviction in a court of law of a felony, or any crime or offense in a court of law of a felony, or any crime or offense involving misuse or misappropriation of money or property, the Employee’s violation of any covenant, agreement or obligation not to disclose confidential information regarding the business of the Company (or a division or Subsidiary); any violation by the Employee of any covenant not to compete with the Company (or a division or Subsidiary); any act of dishonesty by the Employee which adversely affects the business of the Company (or a division or subsidiary); any willful or intentional act of the Employee which adversely affects the business of, or reflects unfavorably on the reputation of the Company (or a division or Subsidiary); the Employee’s use of alcohol or drugs which interferes with the Employee’s performance of duties as an employee of the Company (or a division or Subsidiary); or the Employee’s failure or refusal to perform the specific directives of the Company’s Board of Directors, or its officers which directives are consistent with the scope and nature of the Employee’s duties and responsibilities with the existence and occurrence of all of such causes to be determined by the Company in its sole discretion; provided, that nothing contained in the foregoing provisions of this paragraph shall be deemed to interfere in any way with the right of the Company (or a division or Subsidiary), which is hereby acknowledged, to terminate the Employee’s employment at any time without cause.
 
2.20   “Non-Employee Director” means a member of the Board of Directors of the Company who is not an employee of the Company, and who qualifies as a “Non-Employee Director” under the definition of that term in SEC Rule 16b-3.
 
2.21   “Non-Qualified Performance Stock Incentive” means a Performance Stock Incentive granted under the Plan that is not intended to qualify as qualified performance based compensation under Section 162(m) of the Code, as described in Section 15.9.
 
2.22   “Non-Statutory Stock Option” means an option, including an Option as the context may require, which is not intended to qualify for the tax treatment applicable to incentive stock options under section 422 of the Code.
 
2.23   “Option” means an option granted under this Plan to purchase shares of Common Stock.  Options may be Incentive Stock Options or Non-Statutory Stock Options.
 
2.24   “Participant” means an Employee who the Committee determines is in a position to contribute significantly to the growth and profitability of, or to perform services of major importance to the Company, its divisions and subsidiaries, or Non-Employee Director, who is
 
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selected by the Committee to be a Participant in the Plan and to be granted a Stock Incentive under the Plan.
 
2.25   “Performance Goal” means one or more criteria or standards established by the Committee to determine, in whole or in part, whether a Performance Stock Incentive shall be awarded or earned, which may include the criteria and standards established pursuant to Section 13.9.
 
2.26   “Performance Period” means the time period designated by the Committee during which Performance Goals must be met.
 
2.27   “Performance Stock Award” means a Stock Incentive providing for a grant of shares of Common Stock the award or delivery of which is subject to specified Performance Goals.
 
2.28   “Performance Stock Incentive” means a Stock Incentive, including without limitation, a Performance Stock Award, Performance Unit Award, Restricted Stock Award, or Restricted Unit Award providing for the award, delivery or payment of shares of Common Stock or cash, or a combination of each, that is subject to specified Performance Goals.
 
2.29   “Performance Unit Award” means a Stock Incentive providing for a grant of a unit or units representing an amount of cash or shares of Common Stock (including a Stock Unit as defined in Section 2.45), or a combination of each, that will be distributed in the future if continued employment and/or other specified Performance Goals or other performance criteria specified by the Committee are attained; and which Performance Goals or other performance criteria may include, without limitation, corporate, divisional or business unit financial or operating performance measures, as more particularly described in Section 15.9; and which other contingencies may include the Participant’s depositing with the Company, acquiring or retaining for stipulated time periods specified amounts of Common Stock; and the amount of Stock Incentive may, but need not be determined by reference to the market value of Common Stock.
 
2.30   “Plan” means the ONEOK, Inc. Equity Compensation Plan set forth in these pages, as amended from time to time.
 
2.31   “Plan Year” means the calendar year beginning on January 1 and ending the next December 31.
 
2.32   “Qualified Performance Stock Incentive” means a Performance Stock Incentive granted under the Plan that is intended to qualify as qualified performance based compensation under Section 162(m) of the Code, as described in Section 15.9.
 
2.33   “Restricted Stock Award” means shares of Common Stock which are issued or transferred to a Participant under Section 6, below, and which will become free of restrictions specified by the Committee if continued employment and/or Performance Goals or other performance criteria specified by the Committee are attained; and which Performance Goals or other criteria, circumstances or conditions arise, exist or are satisfied; and which may but need not include, without limitation, corporate, divisional or business unit financial or operating performance measures, as more particularly described in Section 15.9
 

 
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2.34   “Restricted Unit Award” means a Stock Incentive providing for a grant of a unit or units representing an amount of cash or shares of Common Stock or a combination of each, which become free of restrictions specified by the Committee if continued employment and/or Performance Goals or other criteria, circumstances or conditions arise, exist or are attained; and which may but need not include, without limitation, corporate, divisional or business unit financial or operating performance measures, as more particularly described in Section 13.9.
 
2.35   “SEC Rule 16b-3” means Rule 16b-3 of the Securities and Exchange Commission promulgated under the Exchange Act, as such rule or any successor rule may be in effect from time to time.
 
2.36   “Secretary” means the Secretary of the Company.
 
2.37   “Section 16 Person” means a person subject to Section 16(b) of the Exchange Act with respect to transactions involving equity securities of the Company.
 
2.38   “Section 409A” means Section 409A of the Code, and unless otherwise expressly indicated herein, all Treasury Regulations issued under Section 409A of the Code.
 
2.39   “Section 409A Deferred Compensation” means compensation provided pursuant to the Plan that constitutes deferred compensation subject to and not exempted from the requirements of Section 409A.
 
2.40   “Share” or “shares” means a share or shares of Common Stock, par value $.01 per share of the Company.
 
2.41    “Stock” means Common Stock of the Company.
 
2.42   “Stock Appreciation Right” means a right granted to a Participant denominated in shares of Common Stock, to receive, upon exercise of the right (or both the right and a related Option, if applicable in the case of issuance in tandem with an Option), an amount, payable in shares of Common Stock, in cash, or a combination thereof that does not exceed the excess of the Fair Market Value of the share or shares of Common Stock on the date such right is exercised over the base price of such share or shares provided in and for such right on the date such right is granted, as determined by the Committee.
 
2.43   “Stock Bonus Award” means an amount of cash or shares of Common Stock which is distributed to a Participant or which the Committee agrees to distribute in the future to a Participant in lieu of, or as a supplement to, any other compensation that may have been earned by services rendered prior to the date the distribution is made.  Unless otherwise determined by the Committee, the amount of the award shall be determined by reference to the Fair Market Value of Common Stock.  Performance Stock Awards, Performance Unit Awards, Restricted Stock Awards and Restricted Unit Awards are specific types of Stock Bonus Awards.
 
2.44   “Stock Incentive” means rights and incentive compensation granted under this Plan in one of the forms referred to and provided for in Section 3.
 

 
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2.45   “Stock Unit” means a unit evidencing the right to receive under certain conditions or in specified circumstances one (1) share of Common Stock or equivalent value, as determined by the Committee.
 
2.46   “Subsidiary” means a corporation or other form of business association of which shares (or other ownership interest) having more than fifty percent (50%) of the voting power are or in the future become owned or controlled, directly or indirectly, by the Company; provided, however, that in the case of an Incentive Stock Option, the term “Subsidiary” shall mean a Subsidiary (as defined by the preceding clause) which is also a “subsidiary corporation” as defined in Section 424(f) of the Code.
 
2.47   “Time-Lapse Restricted Stock Incentive” means a Restricted Stock Award, Restricted Unit Award, or any other Stock Incentive the award of which is based solely on continued employment with the Company for a specified period of time.
 
3.  
Grants of Stock Incentives
 
3.1   Stock Incentives to Employees/Participants . Subject to the provisions of the Plan, the Committee may at any time, or from time to time, grant Stock Incentives to one or more Employees that the Committee selects to be a Participant in the Plan, which may be (i) Stock Bonus Awards, which may, but need not be Performance Stock Awards, Performance Unit Awards or Restricted Stock Awards, Restricted Unit Awards and/or (ii) Options, which may be Incentive Stock Options or Non-Statutory Stock Options, and/or (iii) Stock Appreciation Rights.
 
3.2   Non-Employee Director Awards .  Subject to the provisions of the Plan, the Committee shall grant Director Stock Awards to Non-Employee Directors in accordance with Section 9 of the Plan.  Notwithstanding anything else otherwise expressed or implied in the Plan, no other form of Stock Incentive shall be granted to Non-Employee Directors under the Plan, and in no event shall any grant of an Incentive Stock Option be made to a Non-Employee Director.
 
3.3   Modifications . After a Stock Incentive has been granted,
 
(a)   the Committee may waive any term or condition thereof that could have been excluded from such Stock Incentive when it was granted, and
 
(b)   with the written consent of the affected Participant, may amend any Stock Incentive after it has been granted to include (or exclude) any provision which could have been included in (or excluded from) such Stock Incentive when it was granted, and no additional consideration need be received by the Company in exchange for such waiver or amendment;
 
(c)   provided, that modification of any Option granted under the Plan shall be subject to the prohibition of repricing of Options stated in Section 7.9; and
 
(d)   the modification of any Option or other Stock Incentive that provides for, or in order to provide for, deferral of compensation subject to Section 409A must meet all requirements under Section 409A and Treasury Regulations, including requirements
 
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applicable to Subsequent Elections and the requirement that acceleration of payment of deferred compensation shall not be permissible.
 
3.4   Forms of Stock Incentives . A particular form of Stock Incentive may be granted to a Participant either alone or in addition to other Stock Incentives hereunder.  The provisions of particular forms of Stock Incentives need not be the same for each Participant.
 
4.  
Stock Subject to the Plan
 
4.1   Shares Authorized .  The maximum number of shares of Common Stock authorized to be issued or transferred pursuant to all Stock Incentives granted under the Plan shall be five million (5,000,000) shares, subject to the provisions governing restoration of shares stated below in Section 4.4 and the provisions for adjustment in Section 13.  The maximum number of five million (5,000,000) shares authorized consists of the three million (3,000,000) shares authorized to be issued or transferred on and after the date of initial adoption of the Plan on February 17, 2005, as approved by shareholders of the Company on May 19, 2005, and an additional two million (2,000,000) shares authorized to be issued and transferred by amendment of the Plan and this Section 4.1, adopted and approved by the Board of Directors on February 21, 2008, and approved by shareholders of the Company on May 15, 2008.
 
4.2   Grant, Award Limitations .  Notwithstanding the foregoing, in addition to the overall maximum limitation in Section 4.1,
 
(a)   The maximum number of shares of Common Stock with respect to which Options or Stock Appreciation Rights may be granted or issued to any one (1) Employee or Participant in any Plan Year is five hundred thousand (500,000);
 
(b)   The maximum number of shares of Common Stock with respect to which Stock Incentives other than Options or Stock Appreciation Rights may be granted or issued to any one (1) Employee or Participant in any Plan Year is five hundred thousand (500,000);
 
(c)   The maximum aggregate number of shares of Common Stock and the maximum dollar amount that may be issued or paid as Performance Stock Incentives to any one (1) Employee or Participant in any Plan Year are five hundred thousand (500,000) shares of Common Stock, and Ten Million Dollars ($10,000,000), respectively;
 
(d)   The maximum aggregate number shares of Common Stock that may be issued under the Plan through the granting of Time-Lapse Restricted Stock Incentives is two million (2,000,000);
 
(e)   The maximum aggregate number of shares of Common Stock that may be issued under the Plan through the granting of Incentive Stock Options is one million seven hundred thousand (1,700,000); and
 
(f)   The exercise of Incentive Stock Options is also subject to the calendar year dollar limitation provided in Section 422(d) of the Code and Section 7.6.
 

 
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4.3            Source of Shares .  Such shares may be authorized but unissued shares of Common Stock, shares of Common Stock held in treasury, whether acquired by the Company specifically for use under this Plan or otherwise, or shares issued or transferred to, or otherwise acquired by, a trust pursuant to Section 15.5, as the Committee may from time to time determine, provided, however, that any shares acquired or held by the Company for the purposes of this Plan shall, unless and until issued or transferred to a trust pursuant to Section 15.5, or to a Participant in accordance with the terms and conditions of a Stock Incentive, be and at all times remain authorized but unissued shares or treasury shares (as the case may be), irrespective of whether such shares are entered in a special account for purposes of this Plan, and shall be available for any corporate purpose.
 
4.4   Restoration and Retention of Shares .  If any shares of Common Stock subject to a Stock Incentive shall not be issued or transferred to a Participant and shall cease to be issuable or transferable to a Participant because of the termination, expiration or cancellation, in whole or in part, of such Stock Incentive or for any other reason, or if any such shares shall, after issuance or transfer, be reacquired by the Company because of the Participant’s failure to comply with the terms and conditions of a Stock Incentive or for any other reason, the shares not so issued or transferred, or the shares so reacquired by the Company, as the case may be, shall no longer be charged against the limitation provided for in Section 4.1 and may be used thereafter for additional Stock Incentives under the Plan; to the extent a Stock Incentive under the Plan is settled or paid in cash, shares subject to such Stock Incentive will not be considered to have been issued and will not be applied against the maximum number of shares of Common Stock provided for in Section 4.1.  If a Stock Incentive may be settled in shares of Common Stock or cash, such shares shall be deemed issued only when and to the extent that settlement or payment is actually made in shares of Common Stock; to the extent a Stock Incentive is settled or paid in cash, and not shares of Common Stock, any shares previously reserved for issuance or transfer pursuant to such Stock Incentive will again be deemed available for issuance or transfer under the Plan; and the maximum number of shares of Common Stock that may be issued or transferred under the Plan shall be reduced only by the number of shares actually issued and transferred to the Participant.  If a Participant pays the purchase price of shares subject to an Option or applicable taxes by surrendering shares of Common Stock in accordance with the provisions of 7.2, the number of shares surrendered shall be added back to the number of shares available for issuance or transfer under the Plan so that the maximum number of shares that may be issued or transferred under the Plan pursuant to Section 4.1 shall have been charged only for the net number of shares issued or transferred pursuant to the Option exercise.
 
5.  
Eligibility
 
An Employee who the Committee determines is in a position to contribute significantly to the growth and profitability of, or to perform services of major importance to, the Company, its divisions and Subsidiaries shall be eligible and may be designated by the Committee to participate in the Plan and be granted Stock Incentives as determined by the Committee, in its sole discretion, under the Plan.  Subject to the provisions of the Plan, the Committee shall from time to time, in its sole discretion, select from such eligible Employees those to whom Stock Incentives shall be granted and determine the number of Shares to be granted and the form and terms of the such Stock Incentives.  Non-Employee Directors shall be eligible to be granted
 

 
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Stock Incentives and to become Participants in the Plan to the extent provided in Sections 3.2 and 9 of the Plan.
 
6.  
Stock Bonus Awards, Performance Stock Awards, Performance Unit Awards, Restricted Stock Awards and Restricted Unit Awards
 
Stock Bonus Awards, Performance Stock Awards, Performance Unit Awards, Restricted Stock Awards and Restricted Unit Awards shall be subject to the following provisions:
 
6.1   Grants .  An eligible Employee may be granted a Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award, or Restricted Unit Award, and a Non-Employee Director may be granted a Director Stock Award, whether or not he or she is eligible to receive similar or dissimilar incentive compensation under any other plan or arrangement of the Company.
 
6.2   Issuance of Shares .  Shares of Common Stock subject to a Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award or Restricted Unit Award, may be issued or transferred to a Participant at the time such Award is granted, or at any time subsequent thereto, or in installments from time to time, and subject to such terms and conditions, as the Committee shall determine.  In the event that any such issuance or transfer shall not be made to the Participant at the time such Award is granted, the Committee may but need not provide for payment to such Participant, either in cash or shares of Common Stock, from time to time or at the time or times such shares shall be issued or transferred to such Participant, of amounts not exceeding the dividends which would have been payable to such Participant in respect of such shares (as adjusted under Section 13) if such shares had been issued or transferred to such Participant at the time such Award was granted.
 
6.3   Cash Settlement .  Any Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award, or Restricted Unit Award may, in the discretion of the Committee, be settled or paid in cash, or shares of Common Stock, or in either cash or shares of Common Stock.  If a Stock Incentive is settled or paid in cash, such settlement and/or payment shall be made on each date on which shares would otherwise have been delivered or become unrestricted, in an amount equal to the Fair Market Value on such date of the shares which would otherwise have been delivered or become unrestricted and the number of shares for which such cash payment is made shall be added back to the maximum number of shares available for use under the Plan.  Shares of Common Stock shall be deemed to be issued only when and to the extent that a Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award, Restricted Unit Award or other Stock Incentive under the Plan is actually settled or paid in shares of Common Stock; and to the extent a Stock Incentive is settled or paid in cash, and not shares of Common Stock, any shares previously reserved for issuance or transfer pursuant to such Stock Incentive will again be deemed available for issuance or transfer under the Plan.
 
6.4   Terms of Awards .  Stock Bonus Awards, Performance Stock Awards, Performance Unit Awards, Restricted Stock Awards and Restricted Unit Awards, shall be subject to such terms and conditions, including, without limitation, restrictions on the sale or other disposition of the shares issued or transferred pursuant to such Award, and conditions calling for
 
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forfeiture of the Award or the shares issued or transferred pursuant thereto in designated circumstances, as the Committee shall determine; provided, however, that upon the issuance or transfer of shares to a Participant pursuant to any such Award, the recipient shall, with respect to such shares, be and become a shareholder of the Company fully entitled to receive dividends, to vote and to exercise all other rights of a shareholder except to the extent otherwise provided in the Award.  All or any portion of a Stock Bonus Award may but need not be made in the form of a Performance Stock Award, a Performance Unit Award, a Restricted Stock Award or a Restricted Unit Award.
 
6.5   Distribution, Payment and Transfer .  The terms of each Stock Incentive and Award under the Plan shall provide that distribution, payment and transfer of Common Stock, cash or any other compensation shall not be subject to any feature or provision that would constitute a deferral of compensation, and transfer to the Participant shall be made so that the Participant actually receives such payment and transfer on or as soon as reasonably practicable after the end of the period during which such Stock Incentive or Award is subject to a substantial risk of forfeiture, and in no event later than a date within the same taxable year of the Participant in which such period ends, or, if later, by the 15 th day of the third calendar month following the date specified for payment under the  Award and the Plan, and with respect to which the Participant shall not be permitted, directly or indirectly, to designate the taxable year of payment.  Provided, that distribution, payment and transfer under an Award with a feature or provision that constitutes a deferral of compensation may be made under and pursuant to a Deferred Compensation Program, if established by the Committee pursuant to Section 10, at a specified time that is elected and provided for therein and subject to the provisions of such Award, and the terms and requirements of such Program and Section 409A, as provided for in Sections 10 and 11.
 
6.6   Loans Prohibited .  The Committee shall not, without prior approval of the Company’s shareholders, grant any Stock Incentive that provides for the making of a loan or other extension of credit, directly or indirectly, by the Company or Plan to an Employee, Participant, officer of the Company or any other person in connection with the grant, award or payment of such Stock Incentive.
 
6.7   Written Instrument .  Each Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award and Restricted Unit Award shall be evidenced in writing as authorized and provided for in Section 15.4.
 
6.8   Director Awards .  Director Stock Awards shall be granted as determined by the Committee in accordance with the provisions of Section 9, and as otherwise provided by this Plan.
 
7.  
Options
 
Options shall be subject to the following provisions:
 
7.1   Option Price .  Subject to the provisions of Section 12, the purchase price per share shall be, in the case of an Incentive Stock Option, a Non-Statutory Stock Option, or any other Option granted under the Plan, not less than one hundred percent (100%) of the Fair
 
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Market Value of a share of Common Stock on the date the Option is granted (or in the case of any optionee who, at the time an Incentive Stock Option is granted, owns stock possessing more than ten percent (10%) of the total combined voting power of all classes of stock of his or her employer corporation or of its parent or subsidiary corporation, not less than one hundred ten percent (110%) of the Fair Market Value of a share of Common Stock on the date the Incentive Stock Option is granted).
 
7.2   Payment of Option Price .  The purchase price of shares subject to an Option may be paid in whole or in part (i) in cash, (ii) by bank-certified, cashier’s or personal check subject to collection, (iii) if so provided in the Option and subject to such terms and conditions as the Committee may impose, by delivering to the Company a properly executed exercise notice together with a copy of irrevocable instructions to a stockbroker to sell immediately some or all of the shares acquired by exercise of the Option and to deliver promptly to the Company an amount of sale proceeds (or, in lieu of or pending a sale, loan proceeds) sufficient to pay the purchase price, or (iv) if so provided in the Option and subject to such terms and conditions as are specified in the Option, in shares of Common Stock or other property surrendered to the Company.  Property for purposes of this section shall include an obligation of the Company unless prohibited by applicable law.  Shares of Common Stock thus surrendered shall be valued at their Fair Market Value on the date of exercise.  Any such other property thus surrendered shall be valued at its fair market value on any reasonable basis established or approved by the Committee.  Notwithstanding any other provision of the Plan, the Committee shall not, without prior approval of the Company’s shareholders, grant an Option or any other Stock Incentive that provides for the making of a loan or other extension of credit, directly or indirectly, by the Company or Plan to an Employee, Participant, officer of the Company, or any other person in connection with the grant, exercise, payment or award of any such Option or other Stock Incentive.
 
7.3   Option Terms .  Options may be granted for such lawful consideration, including money or other property, tangible or intangible, or labor or services received or to be received by the Company, as the Committee may determine when the Option is granted, including the agreement of the optionee to remain in the employ of the Company or one or more of its Subsidiaries at the pleasure of the Company for such period, and on such terms, as are more particularly provided for therein.  Property for purposes of the preceding sentence shall include an obligation of the Company unless prohibited by applicable law.  Subject to the foregoing and the other provisions of this Section 7, each Option may be exercisable in full at the time of grant or may become exercisable in one or more installments, at such time or times and subject to satisfaction of such terms and conditions as the Committee may determine.  The Committee may at any time accelerate the date on which an Option becomes exercisable, and no additional consideration need be received by the Company in exchange for such acceleration.  Unless otherwise provided in the Option, an Option, to the extent it becomes exercisable, may be exercised at any time in whole or in part until the expiration or termination of the Option.
 
7.4   Exercise by Optionee .  Each Option shall be exercisable during the life of the optionee only by him or her or his or her guardian or legal representative, and after the death of the optionee only by his or her Beneficiary or, absent a Beneficiary, by his or her estate or by a person who acquired the right to exercise the Option by will or the laws of descent and distribution; provided, that an Option that is made transferable by its terms and approved by the
 
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Committee pursuant to Section 14.1 shall be exercisable by a permissible transferee in accordance with the terms of the Option.  Each Option shall expire at such time or times as the Committee may determine; provided, that notwithstanding any other provision of this Plan, (i) no Option shall be exercisable after the expiration of ten (10) years from the date the Option was granted, and (ii) no Incentive Stock Option which is granted to any optionee who, at the time such Option is granted, owns stock possessing more than ten percent (10%) of the total combined voting power of all classes of stock of his or her employer corporation or of its parent or subsidiary corporation, shall be exercisable after the expiration of five (5) years from the date such Option is granted.  If an Option is granted for a term of less than ten (10) years, the Committee may, at any time prior to the expiration of the Option, extend its term for a period ending not later than the expiration of ten (10) years from the date the Option was granted, and no additional consideration need be received by the Company in exchange for such extension.  The Committee may but need not provide for an Option to be exercisable after termination of employment until its fixed expiration date (or until an earlier date or specified event occurs). Unless otherwise specifically provided for under Section 10 and subject to the requirements of Section 11, an Option shall not provide for the deferral of compensation to a Participant.
 
7.5   Exercise of Option .  An Option shall be considered exercised if and when written notice, signed by the person exercising the Option, or an electronic communication if such communication is authorized and approved by the Committee in the terms of the Option, and stating the number of shares with respect to which the Option is being exercised, is received by the Secretary in or on a form approved for such purpose by the Committee, accompanied by full payment of the Option exercise price in one or more forms of payment authorized by the Committee described in Section 7.2, for the number of share purchased.  No Option may at any time be exercised with respect to a fractional share.
 
7.6   Incentive Stock Option s .  An Option may, but need not, be an Incentive Stock Option.  All shares of Common Stock which may be made subject to Stock Incentives under this Plan may be made subject to Incentive Stock Options; provided that the aggregate Fair Market Value (determined as of the time the Option is granted) of the stock with respect to which Incentive Stock Options may be exercisable for the first time by any Employee during any calendar year (under all plans, including this Plan, of his or her employer corporation and its parent and subsidiary corporations) shall not exceed One Hundred Thousand Dollars ($100,000) or such other amount, if any, as may apply under the Code.  In no event shall an Incentive Stock Option be granted under the Plan more than ten (10) years from and after the date the Plan is adopted, or the date the Plan is approved by the shareholders of the Company, whichever is earlier.
 
7.7   Written Instrument .  Each Option shall be evidenced in writing as authorized and provided for in Section 15.4.  An Option, if so approved by the Committee, may include terms, conditions, restrictions and limitations in addition to those provided for in this Plan including, without limitation, terms and conditions providing for the transfer or issuance of shares, on exercise of an Option, which may be non-transferable and forfeitable to the Company in designated circumstances.
 
7.8   Restored or Reload Options Prohibited .  Notwithstanding any other provision of the Plan, the Committee shall not, without prior approval of Company’s shareholders, grant an
 
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Incentive Stock Option, Non-Statutory Option or other form of Option under this Plan containing any provision pursuant to which the optionee is to be granted a restored or reload Option of any kind by reason of the exercise of all or part of an Option by paying all or part of the exercise price of such Option by surrendering shares of Common Stock.
 
7.9   Repricing Prohibited .  Notwithstanding any other provision of the Plan, except in connection with a corporate transaction involving the Company (including, without limitation, any stock dividend, stock split, extraordinary cash dividend, recapitalization, reorganization, merger, consolidation, split-up, spin-off, combination, or exchange of shares), the terms of outstanding Stock Incentives may not be amended to reduce the exercise price of outstanding Options or cancel outstanding Options in exchange for cash, other Stock Incentives or Options with an exercise price that is less than the exercise price of the original Options without Company shareholder approval.
 
7.10   Regulatory Compliance .  No Option shall be exercisable unless and until the Company (i) obtains the approval of all regulatory bodies whose approval the General Counsel may deem necessary or desirable, and (ii) complies with all legal requirements deemed applicable by the General Counsel.
 
8.  
Stock Appreciation Rights
 
8.1   General .  Subject to the terms of the Plan, Stock Appreciation Rights may be granted to Employees by the Committee upon such terms and conditions as the Committee determines; provided, that the base price per share of a freestanding Stock Appreciation Right shall be not less than one hundred percent (100%) of the Fair Market Value of a share of the Common Stock on the date of grant of a Stock Appreciation Right; and such Stock Appreciation Right shall be exercisable, or be forfeited or expire upon such terms as the Committee determines and are made a part of such Stock Appreciation Right.
 
8.2   Stock Appreciation Rights, Options .  Stock Appreciation Rights may be granted by the Committee as freestanding Stock Incentives or in tandem with Options.  A tandem Stock Appreciation Right may be included in an Option at the time the Option is granted or by amendment of the Option.  Exercise of any such a tandem Stock Appreciation Right will be deemed to surrender the related Option for cancellation and vice versa.
 
8.3   Exercise .  A Stock Appreciation Right shall be exercised by delivery of written notice (including facsimile or electronic transmittal) to the Committee setting forth the number of shares with respect to which the Stock Appreciation Right is exercised and date of exercise, at such time and as otherwise prescribed in the Stock Appreciation Right.
 
8.4   Settlement .  A Stock Appreciation Right may be settled or paid in either cash, shares of Common Stock, or a combination thereof in accordance with its terms.  If a Stock Appreciation Right is settled or paid in shares of Common Stock, such shares shall be deemed to be issued hereunder only when and to the extent that settlement or payment is actually made in shares of Common Stock.  To the extent that a Stock Appreciation Right is actually settled in cash and not shares of Common Stock, any shares previously reserved for issuance or transfer pursuant to such Stock Appreciation Right shall again be deemed available for issuance or
 
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transfer under the Plan; and the maximum number of shares of Common Stock that may be issued under the Plan shall not be reduced by any actual settlement of a Stock Appreciation Right in cash. Unless otherwise specifically provided for under Section 10 and subject to the requirements of Section 11, a Stock Appreciation Right shall not provide for the deferral of compensation to a Participant.
 
8.5   Written Instrument .  Each Stock Appreciation Right granted shall be evidenced in writing as authorized and provided in Section 15.4.
 
8.6   Repricing Prohibited .  Notwithstanding any other provision of the Plan, except in connection with a corporate transaction involving the Company (including, without limitation, any stock dividend, stock split, extraordinary cash dividend, recapitalization, reorganization, merger, consolidation, split-up, spin-off, combination, or exchange of shares), the terms of outstanding Stock Incentives may not be amended to reduce the exercise price of outstanding Stock Appreciation Rights or cancel outstanding Stock Appreciation Rights in exchange for cash, other Stock Incentives or Stock Appreciation Rights with an exercise price that is less than the exercise price of the original Stock Appreciation Rights without Company shareholder approval.
 
9.  
Director Stock Awards
 
9.1   General .  Each Non-Employee Director Participant shall receive such portion of his or her Director Fees in Common Stock as shall be established from time to time by the Board, with the remainder of such Director Fees to be payable in cash or in Common Stock as elected by the Non-Employee Director Participant in accordance with Section 9.2.
 
9.2   Non-Employee Director Election .  Each Non-Employee Director Participant shall have an opportunity to elect to have the remaining portion of his or her Director Fees paid in cash or shares of Common Stock or a combination thereof.  Except for the initial election pursuant to the adoption of the Plan, or the Director’s election to the Board, any such election shall be made in writing and must be made at least thirty (30) days before the beginning of the Plan Year in which the services are to be rendered giving rise to such Director Fees and may not be changed thereafter except by timely written election as to Director Fees for services to be rendered in a subsequent Plan Year.  In the absence of such an election, such remaining portion of the Director Fees of a Non-Employee Director shall be paid entirely in cash.  Nothing contained in this Section 9.2 shall be interpreted in such a manner as would disqualify the Plan for treatment as a “formula plan” under Rule 16b-3 pursuant to which the terms and conditions of each transaction authorized by Section 9.1 are fixed in advance by the relevant terms and provisions thereof.
 
9.3   Share Awards .  The number of shares of Common Stock to be paid and distributed to a Non-Employee Director under the provisions of Sections 9.1 and 9.2, shall be determined by dividing the dollar amount of his or her Director Fees (which the Board has established, and/or such Non-Employee Director has elected) to be paid in Common Stock on any payment date by the Fair Market Value of a share of Common Stock on that date.  Except as may otherwise be directed by the Committee, in its sole discretion, the payment and distribution
 
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of such shares to a Non-Employee Director shall be on or within five days after the date such Director Fees would otherwise have been paid to him or her in cash.
 
10.  
Deferred Compensation Program
 
10.1   Establishment of Deferred Compensation Program .  This Section 10 shall not be effective unless and until the Committee determines to establish a program or procedures under the Plan providing for deferral of compensation with respect to Awards (“Deferred Compensation Program”) pursuant to this Section.  The Committee, in its discretion and upon such terms and conditions as it may determine, pursuant to Sections 6.2, 6.4, 7.3, 8.1 and 14.2 herein, and consistent with the requirements of Section 409A, may establish one or more Deferred Compensation Programs pursuant to the Plan under which:
 
(a)   Deferred Compensation .  Participants designated by the Committee may irrevocably elect, prior to a date specified by the Committee and subject to compliance with the requirements of Section 409A, to be granted an Award that provides for the deferral of compensation of Stock Units with respect to such number of shares of Common Stock and/or upon such other terms and conditions as established by the Committee in lieu of:
 
(1)   shares of Common Stock otherwise issuable to a Participant upon the exercise of an Option;
 
(2)   shares of Common Stock or cash otherwise issuable to a Participant upon the exercise of a Stock Appreciation Right;
 
(3)   shares of Common Stock or cash otherwise issuable to a Participant upon the settlement and date of distribution, payment and transfer of a Restricted Unit Award;
 
(4)   shares of Common Stock or cash otherwise issuable to a Participant upon the settlement, distribution, payment and transfer of a Performance Unit Award; or
 
(5)   shares of Common Stock or cash otherwise issuable to a Participant upon the settlement, distribution, payment and transfer of any other form of Stock Incentive and Award that may otherwise be granted under the Plan.
 
(b)   Award Deferral Feature.  The providing for the deferral of compensation under a Stock Incentive or Award, upon the granting of such Stock Incentive or Award, or by amendment or change of its terms, is intended to and shall only affect the time of distribution, payment and transfer of the Award, consistent with the nature of the Award as authorized by the Plan, and shall in no event expand the types of Awards available under the Plan, increase the number of Shares available under the Plan, expand the classes of persons eligible under the Plan, provide for any extension of the term of the Plan, change the method of determining a strike price of Options granted under the Plan, or provide for the deletion or any limitation of any provision of the Plan or the Award
 
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prohibiting re-pricing, and shall not increase the potential dilution of shareholders of the Company over the lifetime of the Plan.
 
(c)   Section 409A Compliance.  The provisions of the Plan and any amendment of the Plan with respect to the deferral of compensation or a deferred compensation feature under a Stock Incentive or Award are intended to satisfy the requirements of Section 409A. It is intended that any and all amendments of the Plan and any Awards to satisfy the requirements of Section 409A shall not to be made in any manner so as to expand the types of Stock Incentives or Awards available under the Plan, and the Plan and all Awards shall be interpreted and applied in a manner consistent with such intent.
 
10.2   Terms and Conditions of Stock Incentives, Awards .  Stock Incentives or Awards granted under the Plan that pursuant to this Section 10 provide for deferral of compensation, shall be evidenced by Award Agreements applicable to such Stock Incentives or Awards and other written instruments in such form as the Committee shall from time to time establish.  Award Agreements and other written instruments evidencing such Award Agreements may incorporate all or any of the terms of the Plan by reference and, except as provided below, shall comply with and be subject to the terms and conditions of Section 11.
 
(a)   Voting Rights; Dividend Equivalent Rights and Distributions.  Participants shall have no voting rights with respect to shares of Stock represented by Stock Units until the date of the issuance of such shares of Common Stock.  A  Participant may be entitled to dividend equivalent rights with respect to the payment of cash dividends on Common Stock during the period beginning on the date the Stock Units are granted to the Participant and ending on the earlier of the date on which such Stock Units are settled, as provided for by the Award Agreement and determined by the Committee, subject to the terms and conditions of Section 11.
 
(b)   Settlement, Payment and Transfer.  A Participant electing to receive an Award of Stock Units pursuant to this Section 10 shall specify at the time of such election a settlement, distribution, payment and transfer date with respect to such Award in compliance with the requirements of Section 409A.  The Company shall issue to the Participant on the specified payment date elected by the Participant, or established with respect to the Award, or as soon thereafter as practicable, a number of whole shares of Stock equal to the number of vested Stock Units subject to the Stock Unit Award.  Such shares of Stock shall be fully vested, and the Participant shall not be required to pay any additional consideration (other than applicable tax withholding) to acquire such shares.
 
11.  
Compliance With Section 409A
 
11.1   Awards Subject to Section 409A .  The provisions of this Section 11 shall apply to any Stock Incentive or Award or portion thereof that provides for the deferral of compensation and is or becomes subject to Section 409A, notwithstanding any provision to the contrary contained in the Plan or the Award Agreement or other written instrument applicable to such Award.  Awards subject to Section 409A include, without limitation:
 

 
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(a)           Any Nonstatutory Stock Option or Stock Appreciation Right that permits the deferral of compensation other than the deferral of recognition of income until the exercise of the Award;
 
(b)   Each Stock Incentive or Award that provides for the deferral of compensation; and
 
(c)   Any Restricted Stock Unit Award, Performance Award, cash-based Award or Other Stock-based Award if such Award provides for the deferral of compensation and either (i) the Award provides by its terms for settlement, distribution, payment and transfer of all or any portion of the Award on one or more specified dates or (ii) the Committee permits or requires the Participant to elect, or the Committee designates one or more dates on which the Award will be settled, distributed, paid and transferred.
 
11.2   Deferral and/or Distribution Elections .  Except as otherwise permitted or required by Section 409A and Treasury Regulations thereunder or other applicable Secretary of the Treasury published guidance, the following rules shall apply to any deferral of compensation and/or distribution elections (each, an “ Election ”) that may be permitted, required or designated by the Committee pursuant to an Award subject to Section 409A:
 
(a)   All Elections must be in writing and specify the amount of the distribution, payment and transfer in settlement of an Award being deferred, as well as the Specific Time and form of distribution as permitted by this Plan, in accordance with Section 409A and the Treasury Regulations thereunder.
 
(b)   All Elections shall be made by the end of the Participant’s taxable year prior to the year in which services commence for which an Award may be granted to such Participant; provided, however, that:
 
(1)   if the Award provides for forfeitable rights under which the Participant has a legally binding right to a distribution, payment or transfer in a subsequent year that is subject to a condition requiring the Participant to continue to provide services for a period of at least 12 months from the date the Participant obtains a legally binding right to avoid forfeiture of the distribution, payment or transfer and the Election is made at least 12 months in advance of the earliest date the Participant at which a forfeiture condition could lapse, or
 
(2)   if the Award qualifies as “performance-based compensation” for purposes of Section 409A and is based on services performed over a period of at least twelve (12) months, then the Election may be made no later than six (6) months prior to the end of such period, or
 
(3)   if the Election is otherwise permissible at a later date pursuant to Section 409A, the Treasury Regulations thereunder or other applicable guidance.
 
(c)   Elections shall continue in effect until a written election to revoke or change such Election is received by the Company, except that a written election to revoke or change such Election must be made prior to the last day for making an Election
 
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determined in accordance with paragraph (b) above or as permitted by Section 11.3, and Section 409A.
 
11.3   Subsequent Elections .  Except as otherwise permitted or required by Section 409A, the Treasury Regulations thereunder or other applicable guidance, any Award subject to Section 409A which permits a subsequent Election (“Subsequent Election”) to delay the distribution or change the form of distribution in settlement of such Award shall comply with the following requirements:
 
(a)   No Subsequent Election may take effect until at least twelve (12) months after the date on which the Subsequent Election is made;
 
(b)   Each Subsequent Election related to a distribution, payment, or transfer in settlement of an Award not described in Section 11.4(b), 11.4(c) or 11.4(f) must result in a delay of the payment, distribution or transfer for a period of not less than five (5) years from the date such distribution, payment or transfer would otherwise have been made; and
 
(c)   No Subsequent Election related to a distribution, payment or transfer pursuant to Section 11.4(d) shall be made less than twelve (12) months prior to the date of the first scheduled payment as to such distribution, payment or transfer.
 
11.4   Distributions Pursuant to Deferral Elections .  Except as otherwise permitted or required by Section 409A or Treasury Regulations thereunder or other applicable guidance, no distribution, payment or transfer in settlement of an Award subject to Section 409A may commence earlier than:
 
(a)   Separation from service within the meaning of and as provided for under Section 409A and the Treasury Regulations thereunder (“Separation from Service”);
 
(b)   The date the Participant becomes Disabled (as defined below);
 
(c)   Death;
 
(d)   A Specified Time (or pursuant to a Fixed Schedule) that is either (i) designated by the Committee upon the grant of an Award and set forth in the Award Agreement evidencing such Award or (ii) specified by the Participant in an Election complying with the requirements of Section 11.2 and/or 11.3, as applicable;
 
(e)   To the extent provided by Treasury Regulations under Section 409A, a change in the ownership or control of the Company or in the ownership of a substantial portion of the assets of the Company; or
 
(f)   The occurrence of an Unforeseeable Emergency (as defined below and as provided for under by Treasury Regulations under Section 409A).
 
For purposes of the foregoing and the Plan, a "Specified Time" means a date or dates at which deferred compensation is payable and that are nondiscretionary and objectively
 

 
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determinable at the time the compensation is deferred, as provided for in Treasury Regulations under Section 409A; and "Fixed Schedule” means the distribution or payment of deferred compensation in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such compensation is first elected or designated pursuant to the Plan and the requirements of Section 409A.
 
Notwithstanding anything else herein to the contrary, to the extent that a Participant is a “Specified Employee” (as defined in Section 409A(a)(2)(B)(i) of the Code) of the Company, no distribution pursuant to Section 11.4(a) in settlement of an Award subject to Section 409A may be made before the date (the “Delayed Payment Date”) which is six (6) months after such Participant’s date of Separation from Service, or, if earlier, the date of the Participant’s death.  All such amounts that would, but for this paragraph, become payable prior to the Delayed Payment Date shall be accumulated and paid on the Delayed Payment Date.
 
11.5   Unforeseeable Emergency .  The Committee shall have the authority to provide in the Award Agreement evidencing any Award subject to Section 409A for distribution in settlement of all or a portion of such Award in the event that a Participant establishes, to the satisfaction of the Committee, the occurrence of an Unforeseeable Emergency.  In such event, the amount(s) distributed with respect to such Unforeseeable Emergency cannot exceed the amounts necessary to satisfy such Unforeseeable Emergency plus amounts necessary to pay taxes reasonably anticipated as a result of such distribution(s), after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise, by liquidation of the Participant’s assets  the liquidation of such assets would not itself cause severe financial hardship) or by cessation of deferrals under the Award.  All distributions with respect to an Unforeseeable Emergency shall be made in a lump sum as soon as practicable following the Committee’s determination that an Unforeseeable Emergency has occurred.  For purposes of the foregoing, Unforeseeable Emergency means a severe financial hardship to the Participant resulting from illness or accident of the Participant, the Participant’s spouse, or a dependent (as defined in Code Section 152(a)) of the Participant, loss of the Participant’s property due to casualty, or other similar extraordinary circumstances arising as a result of events beyond the control of the Participant, including such events and circumstances as  and considered to be an Unforeseeable Emergency under Code section 409A and the regulations thereunder.  It is intended and directed with respect to any such unforeseeable emergency that any amounts distributed under the Plan by reason thereof shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the Participant’s assets (to the extent the liquidation of such assets would not itself cause severe financial hardship).
 
The occurrence of an Unforeseeable Emergency shall be judged and determined by the Committee.  The Committee’s decision with respect to whether an Unforeseeable Emergency has occurred and the manner in which, if at all, the distribution, payment or transfer in settlement of an Award shall be altered or modified, shall be final, conclusive, and not subject to approval or appeal.
 

 
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11.6            Disab ility .  The Committee shall have the authority to provide in any Award subject to Section 409A for distribution, payment or transfer in settlement of such Award in the event that the Participant becomes Disabled.  A Participant shall be considered “Disabled” and that term shall mean means that a Participant is unable to engage in substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than twelve (12) months, or is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or expected to last for a continuous period of not less than twelve (12) months, receiving income replacement benefits for a period of not less than three (3) months under an accident or health plan covering Employees of the Corporation.  A Participant will be deemed to be Disabled if such Participant is determined to be totally disabled by the Social Security Administration.
 
All distributions payable by reason of a Participant becoming Disabled shall be paid in a lump sum or in periodic installments as established by the Participant’s Election, commencing as soon as practicable following the date the Participant becomes Disabled.  If the Participant has made no Election with respect to distributions upon becoming Disabled, all such distributions shall be paid in a lump sum as soon as practicable following the date the Participant becomes Disabled.
 
11.7   Death .  If a Participant dies before complete distribution, payment or transfer of amounts to be distributed, paid or transferred upon settlement of an Award subject to Section 409A, such undistributed amounts shall be distributed, paid or transferred to his or her beneficiary under the distribution and payment method for death established by the Participant’s Election as soon as administratively possible following receipt by the Committee of satisfactory notice and confirmation of the Participant’s death.  If the Participant has made no Election with respect to distribution or payment upon death, distribution and payment shall be paid in a lump sum as soon as practicable following the date of the Participant’s death.
 
11.8   No Acceleration of Distributions .  Notwithstanding anything to the contrary herein, this Plan does not permit the acceleration of the time or schedule of any distribution, payment or transfer under an Award subject to Section 409A, except as provided by Section 409A and/or the Treasury Regulations thereunder.
 
12.  
Certain Change in Control, Termination of Employment and Disability Provisions
 
Notwithstanding any provision of the Plan to the contrary, any Stock Incentive which is outstanding but not yet exercisable, vested or payable at the time of a Change in Control shall become exercisable, vested and payable at that time; provided, that if such Change in Control occurs less than six months after the date on which such Stock Incentive was granted and if the consideration for which such Stock Incentive was granted consisted in whole or in part of future services, then such Stock Incentive shall become exercisable, vested and payable at the time of such Change in Control only if the Participant agrees in writing (if requested to do so by the Committee in writing) to remain in the employ of the Company or a Subsidiary at least through the date which is six months after the date such Stock Incentive was granted with substantially the same title, duties, authority, reporting relationships and compensation as on the day immediately preceding the Change in Control.  Any Option affected by the preceding sentence
 

 
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shall remain exercisable until it expires or terminates pursuant to its terms and conditions.  Subject to the foregoing provisions of this Section 12, the Committee may at any time, and subject to such terms and conditions as it may impose:
 
(a)   authorize the holder of an Option to exercise the Option following the termination of the Participant’s employment with the Company and its Subsidiaries, or following the Participant’s disability, whether or not the Option would otherwise be exercisable following such event, provided that in no event may an Option be exercised after the expiration of its term;
 
(b)   grant Options which become exercisable only in the event of a Change in Control;
 
(c)   authorize a Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award, or Restricted Unit Award to become non-forfeitable, fully earned and payable upon or following (i) the termination of the Participant’s employment with the Company and its Subsidiaries, or (ii) the Participant’s disability, whether or not the Award would otherwise become non-forfeitable, fully earned and payable upon or following such event;
 
(d)   grant Stock Bonus Awards, Performance Stock Award, Performance Unit Awards, Restricted Stock Awards or Restricted Unit Awards which become non-forfeitable, fully earned and payable only in the event of a Change in Control; and
 
(e)   provide in advance or at the time of Change in Control for cash to be paid in settlement of any Option, Stock Bonus Award, Performance Stock Award, Performance Unit Award, Restricted Stock Award or Restricted Unit Award in the event of a Change in Control, either at the election of the Participant or at the election of the Committee.
 
13.  
Adjustment Provisions
 
In the event that any recapitalization, or reclassification, split-up or consolidation of shares of Common Stock shall be effected, or the outstanding shares of Common Stock shall be, in connection with a merger or consolidation of the Company or a sale by the Company of all or a part of its assets, exchanged for a different number or class of shares of stock or other securities or property of the Company or any other entity or person, or a record date for determination of holders of Common Stock entitled to receive a dividend or other distribution payable in Common Stock or other property (other than normal cash dividends) shall occur, (i) the number and class of shares or other securities or property that may be issued or transferred pursuant to Stock Incentives thereafter granted or that may be optioned or awarded under the Plan to any Participant, (ii) the number and class of shares or other securities or property that may be issued or transferred under outstanding Stock Incentives, (iii) the purchase price to be paid per share under outstanding and future Stock Incentives, and (iv) the price to be paid per share by the Company or a Subsidiary for shares or other securities or property issued or transferred pursuant to Stock Incentives which are subject to a right of the Company or a Subsidiary to reacquire such shares or other securities or property, shall in each case be equitably adjusted; provided that with
 

 
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respect to Incentive Stock Options any such adjustments shall comply with Sections 422 and 424 of the Code.
 
14.  
Administration
 
14.1   Committee .  The Plan shall be administered by a committee of the Board of Directors consisting of two or more non-employee directors appointed from time to time by the Board of Directors.  A majority of the Committee members shall constitute a quorum.  The acts of a majority of the Committee members at a meeting at which a quorum is present or acts approved in writing by a majority of the Committee members shall be deemed acts of the Committee.  Each member of the Committee shall satisfy such criteria of independence as the Board of Directors may establish and such regulatory or listing requirements as the Board of Directors may determine to be applicable or appropriate.  No person shall be appointed to or shall serve as a member of such Committee unless at the time of such appointment and service he or she shall be a “Non-Employee Director,” as defined in SEC Rule 16b-3.  Unless the Board of Directors determines otherwise, the Committee shall be comprised solely of “outside directors” within the meaning of Section 162(m)(4)(C)(i) of the Code.
 
14.2   Committee Authority, Rules, Interpretations of Plan .  The Committee may establish such rules and regulations, not inconsistent with the provisions of the Plan, as it may deem necessary for the proper administration of the Plan, and may amend or revoke any rule or regulation so established.  The Committee shall, subject to the provisions of the Plan, have full power to interpret, administer and construe the Plan and any instruments issued under the Plan and full authority to make all determinations and decisions thereunder including without limitation the authority to (i) select the Participants in the Plan, (ii) determine when Stock Incentives shall be granted, (iii) determine the number of shares to be made subject to each Stock Incentive, (iv) determine the type of Stock Incentive to grant, (v) determine the terms and conditions of each Stock Incentive, including the exercise price, in the case of an Option, (vi) prescribe the terms and forms of written instruments evidencing Stock Incentives granted pursuant to and in accordance with the Plan and other forms necessary for administration of the Plan, and (vii) approve any transaction involving a Stock Incentive for a Section 16 Person (other than a “Discretionary Transaction” as defined in SEC Rule 16b-3) so as to exempt such transaction under SEC Rule 16b-3; provided, that any transaction under the Plan involving a Section 16 Person also may be approved by the Board of Directors, or may be approved or ratified by the shareholders of the Company, in the manner that exempts such transaction under SEC Rule 16b-3.  The interpretation by the Committee of the terms and provisions of the Plan and any instrument or other evidence of a Stock Incentive issued thereunder, and its administration thereof, and all action taken by the Committee, shall be final, binding, and conclusive on the Company, the shareholders of the Company, Subsidiaries, all Participants and employees, and upon their respective Beneficiaries, successors and assigns, and upon all other persons claiming under or through any of them.
 
14.3   Section 409A Compliance Authority .  Notwithstanding any other provision of the Plan to the contrary or any Award or Award Agreement, the Committee may, but shall not be required to, in its sole and absolute discretion and without the consent of any Participant, amend the Plan, or any Award Agreement, or other written instrument issued under the Plan, or take such other actions with respect to an Award of Award Agreement, to take effect retroactively or
 

 
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otherwise, as it deems necessary or advisable for the purpose of conforming the Plan, or such Award Agreement or other written instrument to any present or future law, regulation or rule applicable to the Plan or such Award or Award Agreement, including without limitation, Section 409A and Treasury Regulations issued under Section 409A.
 
The Company intends that the Plan shall be administered and all Awards and Stock Incentives granted thereunder subject to Section 409A shall be administered, interpreted and applied in a manner that complies with Section 409A.
 
Provided, that the Company and the Committee makes no representations that Stock Incentives and Awards granted under the Plan shall be exempt from or comply with Section 409A of the Code and makes no undertaking to preclude Section 409A of the Code from applying to Stock Incentives and Awards granted under the Plan.  The Company and the Committee shall not be responsible for any additional tax imposed upon a Participant or other person pursuant to Section 409A, nor shall the Company or Committee indemnify or otherwise reimburse a Participant or other person for any liability incurred as a result of Section 409A.
 
14.4   Limitation of Liability .  Members of the Board of Directors and members of the Committee acting under this Plan shall be fully protected in relying in good faith upon the advice of counsel and shall incur no liability except for gross or willful misconduct in the performance of their duties.
 
15.  
General Provisions
 
15.1   Nontransferability .  Any provision of the Plan to the contrary notwithstanding, any Stock Incentive issued under the Plan, including without limitation any Option, shall not be transferable by the Participant other than by will or the laws of descent and distribution or to a Beneficiary designated by the Participant, unless the instrument evidencing the Stock Incentive expressly so provides (or is amended to so provide) and is approved by the Committee; and any purported transfer of an Incentive Stock Option to a Beneficiary, or other transferee, shall be effective only if such transfer is, in the opinion of the General Counsel, permissible under and consistent with SEC Rule 16b-3 or Section 422 of the Code, as the case may be.  Notwithstanding the foregoing, a Participant may transfer any Stock Incentive granted under this Plan, other than an Incentive Stock Option, to members of his or her immediate family (defined as his or her children, grandchildren and spouse) or to one or more trusts for the benefit of such immediate family members or partnerships in which such immediate family members are the only partners if (and only if) the instrument evidencing such Stock Incentive expressly so provides (or is amended to so provide) and is approved by the Committee; provided, that under no circumstances shall any transfer of a Stock Incentive be made for value or consideration to the Participant.  Any such transferred Stock Incentive shall continue to be subject to the same terms and conditions that were applicable to such Stock Incentive immediately prior to its transfer (except that such transferred Stock Incentive shall not be further transferable by the transferee inter vivos , except for transfer back to the original Participant holder of the Stock Incentive) and provided, further, that the foregoing provisions of this sentence shall apply to Section 16 Persons only if the General Counsel determines that doing so would not jeopardize any exemption from Section 16 of the Exchange Act (including without limitation SEC Rule 16b-3) for which the Company intends Section 16 Persons to qualify.  The designation of a Beneficiary by a
 
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Participant pursuant to Section 15.15 is not a transfer for purposes of the foregoing provisions of this paragraph.
 
15.2   No Employment Contract .  Nothing in this Plan or in any instrument executed pursuant hereto shall confer upon any person any right to continue in the employment of the Company or a Subsidiary, or shall affect the right of the Company or a Subsidiary to terminate the employment of any person at any time with or without cause.
 
15.3   Right to Shares .  No shares of Common Stock shall be issued or transferred pursuant to a Stock Incentive unless and until all legal requirements applicable to the issuance or transfer of such shares have, in the opinion of the General Counsel, been satisfied.  Any such issuance or transfer shall be contingent upon the person acquiring the shares giving the Company any assurances the General Counsel may deem necessary or desirable to assure compliance with all applicable legal requirements.
 
15.4   Written Instrument .  A Stock Incentive and Award granted under this Plan shall be evidenced in writing in such manner as the Committee determines, including, without limitation, by written Award Agreement or other physical instrument, by electronic communication, or by book entry.  Such written evidence of a Stock Incentive shall contain the terms and conditions thereof, consistent with this Plan, which shall be incorporated in it by reference.  In the event of any dispute or discrepancy regarding the terms of a Stock Incentive, the records of the Board of Directors and Committee shall be determinative.
 
15.5   Limitation of Interest .  No person (individually or as a member of a group) and no Beneficiary or other person claiming under or through him or her, shall have any right, title or interest in or to any shares of Common Stock (i) issued or transferred to, or acquired by, a trust, (ii) allocated, or (iii) reserved for the purposes of this Plan, or subject to any Stock Incentive except as to such shares of Common Stock, if any, as shall have been issued or transferred to him or her.  The Committee may (but need not) provide at any time or from time to time (including without limitation upon or in contemplation of a Change in Control) for a number of shares of Common Stock, equal to the number of such shares subject to Stock Incentives then outstanding, to be issued or transferred to, or acquired by, a trust (including but not limited to a grantor trust) for the purpose of satisfying the Company’s obligations under such Stock Incentives, and, unless prohibited by applicable law, such shares held in trust shall be considered authorized and issued shares with full dividend and voting rights, notwithstanding that the Stock Incentives to which such shares relate shall not have been exercised or may not be exercisable or vested at that time.
 
15.6   Withholdings .  The Company and its Subsidiaries may make such provisions as they may deem appropriate for the withholding of any taxes which they determine they are required to withhold in connection with any Stock Incentive.  Without limiting the foregoing, the Committee may, subject to such terms and conditions as it may impose, permit or require any withholding tax obligation arising in connection with the grant, exercise, vesting, distribution or payment of any Stock Incentive to be satisfied in whole or in part, with or without the consent of the Participant, by having the Company withhold all or any part of the shares of Common Stock that vest or would otherwise be distributed at such time.  Any shares so withheld shall be valued at their Fair Market Value on the date of such withholding.
 

 
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15.7   Other Plan s .  Nothing in this Plan is intended to be a substitute for, or shall preclude or limit the establishment or continuation of, any other plan, practice or arrangement for the payment of compensation or fringe benefits to directors, officers or employees generally, or to any class or group of such persons, which the Company or any Subsidiary now has or may hereafter lawfully put into effect, including, without limitation, any incentive compensation, retirement, pension, group insurance, stock purchase, stock bonus or stock option plan.
 
15.8   Section 16 Exemption Requirement s .  Any provision of the Plan to the contrary notwithstanding, except to the extent that the Committee determines otherwise, transactions by and with respect to Section 16 Persons under the Plan are intended to qualify for any applicable exemptions provided by SEC Rule 16b-3, and the provisions of the Plan and Stock Incentives granted under the Plan shall be administered, interpreted and construed to carry out such intent and any provision that cannot be so administered, interpreted and construed shall to that extent be disregarded.
 
15.9   Section 162(m) Qualification .  Any provision of the Plan to the contrary notwithstanding, except to the extent the Committee determines otherwise, transactions with respect to persons whose remuneration would not be deductible by the Company but for compliance with the provisions of Section 162(m) of the Code are intended to be Qualified Performance Stock Incentives that comply with the provisions of Section 162(m) of the Code.  The Plan is also intended to give the Committee the authority to award Stock Incentives that are Qualified Performance Stock Incentive awards that qualify as performance-based compensation under Section 162(m) of the Code, as well as Stock Incentives that are Non-Qualified Performance Stock Incentive awards that do not so qualify.  Every provision of the Plan shall be administered, interpreted and construed to carry out such intent and any provision that cannot be so administered, interpreted and construed shall to that extent be disregarded.  In administration and interpretation of the Plan:
 
(a)   Performance Stock Incentives granted to Employees under the Plan that are intended to be Qualified Performance Stock Incentives shall be paid, vested or otherwise awarded and delivered solely on account of the attainment of one or more pre-established, objective Performance Goals established by the Committee in writing.  A Performance Goal shall generally be pre-established prior to commencement of the Performance Period, and in no event later than the earlier of (i) ninety (90) days after the commencement of the period of service to which a Performance Goal relates, provided, that the outcome is substantially uncertain at the time the Performance Goal is established, and (ii) the lapse of twenty-five percent (25%) of the period of service (as scheduled in good faith at the time the Performance Goal is established), and in any event while the outcome is substantially uncertain.  A Performance Goal shall be deemed objective if a third party having knowledge of the relevant facts could determine if it is met.  Such a Performance Goal may be based on one or more business performance criteria that apply to a Participant, one or more business units, subsidiaries, divisions or sectors of the Company, or the Company as a whole, and if so determined by the Committee, by comparison with a designated peer group of companies or businesses.  A Performance Goal may include one or more of the following criteria or standards: (i) increased revenue, (ii) net income measures, including without limitation, income after capital costs, and income before or after taxes, (iii) stock price measures, including
 
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without limitation, growth measures and total stockholder return, (iv) market share, (v) earnings per share (actual or targeted growth), (vi) earnings before interest, taxes, depreciation, and amortization, (vii) economic value added, (viii) cash flow measures, including without limitation, net cash flow, and net cash flow before financing activities, (ix) return measures, including without limitation, return on equity, return on average assets, return on capital, risk adjusted return on capital, return on investors’ capital and return on average equity, (x) operating measures, including without limitation, operating income, funds from operations, cash from operations, after-tax operating income, sales volumes, production volumes, and production efficiency, (xi) expense measures, including but not limited to, finding and development costs, overhead costs, and general and administrative expense, (xii) margins, (xiii) shareholder value, (xiv) total shareholder return, (xv) reserve addition, (xvi) proceeds from dispositions, (xvii) total market value, and (xviii) corporate value criteria or standards including, without limitation, ethics, environmental and safety compliance.
 
(b)   A Performance Goal need not be based upon an increase or a positive result under a particular business criterion, and may include, the maintaining of the status quo or limiting economic or financial losses measured by reference to specific business criteria.  A Performance Goal must include business criteria, and a Performance Goal shall not be established or be considered to exist based on the mere continued employment of an Employee.
 
(c)   Performance Goals may be identical for all Participants, or may be different for one or more Participants, as determined by the Committee in its sole discretion.
 
(d)   In interpreting the provisions of the Plan and Stock Incentives granted under the Plan applicable to Qualified Performance Stock Incentives, it is intended that the Plan will conform with the standards and requirements of Section 162(m) of the Code and Treasury Regulation §1.162-27(e)(2), and any successor provisions of the Code and Treasury Regulations as to Stock Incentives granted to those Employees whose compensation is, or likely to be, subject to Section 162(m) of the Code, and the Committee in establishing Performance Goals and interpreting the Plan and Stock Incentives shall be guided by such provisions, as it determines, in its sole discretion.
 
(e)   Prior to the payment or distribution of any compensation based upon the achievement of Performance Goals for a Qualified Performance Stock Incentive, the Committee shall certify in writing that the applicable Performance Goals and any of the material terms thereof were, in fact, satisfied.  The approved minutes of a Committee meeting or written memorandum of action of the Committee without a meeting in which the certification is made may be treated as a written certification.  Certification by the Committee is not required for compensation that is attributable solely to the increase in the value of the Common Stock.
 
(f)   Subject to the foregoing provisions, the terms, conditions and limitations applicable to any Qualified Performance Stock Incentives that are granted pursuant to the Plan shall be determined by the Committee.
 

 
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15.10   Plan Acceptance .  By accepting any benefits under the Plan, each Participant, and each person claiming under or through a Participant shall be conclusively deemed to have indicated his or her acceptance and ratification of, and consent to, all provisions of the Plan and any action or decision under the Plan by the Company, its agents and employees, and the Board of Directors and the Committee.
 
15.11   Governing Law .  The validity, construction, interpretation and administration of the Plan and of any determinations or decisions made thereunder, and the rights of all persons having or claiming to have any interest therein or thereunder, shall be governed by, and determined exclusively in accordance with, the laws of the State of Oklahoma, but without giving effect to the principles of conflicts of laws thereof.  Without limiting the generality of the foregoing, the period within which any action arising under or in connection with the Plan must be commenced, shall be governed by the laws of the State of Oklahoma, without giving effect to the principles of conflicts of laws thereof, irrespective of the place where the act or omission complained of took place and of the residence of any party to such action and irrespective of the place where the action may be brought.
 
15.12   No Secured Interest .  A Participant shall have only a right to shares of Common Stock or cash or other amounts, if any, payable in settlement of a Stock Incentive under this Plan, unsecured by any assets of the Corporation or any other entity.
 
15.13   Gender and Singular References .  The use of the masculine gender shall also include within its meaning the feminine.  The use of the singular shall include within its meaning the plural and vice versa.
 
15.14   Death of Participant .  Unless otherwise specified in the Stock Incentive, if the person to whom the Stock Incentive is granted dies, then (1) an Option that is not yet exercisable shall become immediately exercisable in full, (2) any remaining restrictions with respect to the Stock Incentive shall expire, and (3) the Committee may alter or accelerate the settlement schedule, Performance Goals or other performance criteria, or payment or other terms of any Stock Incentive.
 
15.15   Beneficiary Designation .  A Participant to whom a Stock Incentive is granted under this Plan may designate a Beneficiary in writing and in accordance with such requirements and procedures as the Committee may establish.
 
16.  
Plan Amendment and Termination
 
The Plan may be amended by the Board of Directors, without shareholder approval, at any time and in any respect, unless approval of the amendment in question by the shareholders of the Company is required under Oklahoma law, the Code (including without limitation Code Section 422 and Proposed Treasury Regulation Section 1.422A-9(b)(iv) thereunder), any applicable exemption from Section 16 of the Exchange Act (including without limitation SEC Rule 16b-3) for which the Company intends Section 16 Persons to qualify, any national securities exchange or system on which the Common Stock is then listed or reported, by any regulatory body having jurisdiction with respect to the Plan, or under any other applicable laws, rules or regulations, in which case such amendment shall be effective only if and to the extent it is approved by the
 

 
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shareholders of the Company as so required.  The Plan may also be terminated at any time by the Board of Directors.  No amendment or termination of this Plan shall adversely affect any Stock Incentive granted prior to the date of such amendment or termination without written consent of the Participant. Notwithstanding any other provision of the Plan to the contrary, the Committee may, in its sole and absolute discretion and without the consent of any Participant, amend the Plan or any Award Agreement, or any written instrument issued under the Plan, to take effect retroactively or otherwise, as it deems necessary or advisable for the purpose of conforming the Plan or such Award Agreement or instrument to any present or future law, regulation or rule applicable to the Plan, including, without limitation, Section 409A.
 

 
Amended and restated as of this 18 th day of December, 2008.
 

By: __________________________________________
                                               David E. Roth
Senior Vice President Administrative Services

 

 
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Exhibit 10.54
 
PERFORMANCE UNIT AWARD AGREEMENT
 
This instrument is issued as of the 15th day of January, 2009, by ONEOK, Inc., an Oklahoma corporation, (hereinafter referred to as “Corporation”), to «Officer_Name» (hereinafter referred to as “Grantee”), an employee of the Corporation or a division or subsidiary thereof, pursuant to the terms of the ONEOK, Inc. Equity Compensation Plan, effective February 17, 2005, (hereinafter referred to as the “Plan”).
 
1.   Performance Unit Award .  This instrument and that certain Notice of Performance Unit Award and Agreement, dated January 15, 2009, a copy of which is attached hereto and incorporated herein by reference (the “Notice of Performance Unit Award and Agreement”), constitute evidence of the issuance and grant of a Performance Unit Award (hereinafter referred to as “Award”) of «No_of_Perf_Units» Performance Units to the Grantee by the Corporation that shall entitle the Grantee to receive shares of the Corporation’s Common Stock (hereinafter also referred to as “Common Stock”) or cash, all pursuant and subject to the terms, provisions, and conditions of this instrument (including, without limitation, the conditions, restrictions and limitations stated in paragraph 5, below) and the terms and provisions of the Plan, which are incorporated herein by reference.  This instrument, when executed by the Grantee, together with the Notice of Performance Unit Award and Agreement constitute an agreement between the Corporation and the Grantee.  Notwithstanding the foregoing, should there be any inconsistency between the provisions of this instrument and the terms and provisions of the Award stated in the resolutions and records of the Board of Directors of the Corporation providing for the Award or provisions of the Plan, the provisions of such resolutions and records and of the Plan shall control.  The grant of such Performance Units to the Grantee shall be effective in the manner and to the extent provided in this instrument and the Plan as to all or any part of the shares of Common Stock subject to the grant from time to time during the period stated herein.
 
2.   Plan .  The Award is made to the Grantee pursuant to the terms and provisions of the Plan, as approved by the Shareholders of the Corporation, which Plan provides that a specific aggregate number of shares of Common Stock of the Corporation may be issued or transferred pursuant to Stock Incentives under the Plan.  The Plan specifies the authority of the Corporation, its Board of Directors, and a committee of the Board of Directors to select employees to be granted Stock Incentives under the Plan.   The Executive Compensation Committee of the Board of Directors (hereinafter referred to as the “Committee”) is authorized to administer the Plan with respect to this instrument and the grant of the Award made to the Grantee pursuant to the Plan.  Except where expressly stated or clearly indicated otherwise by the terms of this instrument, all terms, words and phrases used herein shall have the same meaning and effect as stated in the Plan.  The Grantee has been provided a complete copy of the Plan with this instrument.
 
3.   Grantee’s Agreement Concerning Award and Employment .  In consideration of the Corporation’s granting of the Award of Performance Units and entitlement to shares of Common Stock, as incentive compensation to Grantee pursuant to this instrument, the Grantee, by acceptance thereof, and signing this instrument evidencing its terms, agrees to such terms and to continue to contribute and perform service in the employ of the Corporation or a division or subsidiary thereof at the direction, will and pleasure of the Corporation and the Board of
 

 
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Directors.  Provided, however, neither the foregoing agreement of the Grantee in this paragraph 3, nor any other provision in this instrument shall confer on the Grantee any right to continue in the employ of the Corporation (or a division or Subsidiary thereof), or interfere in any way with the right of the Corporation (or such division or Subsidiary) to terminate the Grantee’s employment at any time.
 
4.   Registration of Stock; Grantee’s Representation With Respect To Acquiring for Investment .  It is intended by the Corporation that the Plan and the shares of Common Stock covered by the Award issued and granted to the Grantee referred to in paragraph 1, above, are to be registered under the Securities Act of 1933, as amended, prior to the date of the grant; provided, that in the event such registration is for any reason not made effective for such shares, the Grantee agrees, for the Grantee, and for the Grantee’s permissible assignees, heirs and legal representatives by inheritance or bequest, that all shares acquired pursuant to the grant will be acquired for investment and not with a view to, or for sale or tender in connection with the distribution of any part thereof, including any transfer or distribution of such shares by the Grantee pursuant to the grant and this instrument or as otherwise allowed by the Plan.
 
5.   Terms and Conditions of Award; Transfer of Stock to Grantee .  The issue and grant of the Award of Performance Units to the Grantee stated in paragraph 1, above, shall be subject to the following terms and conditions:
 
(a)   The right to ownership and transfer of the Performance Units granted to the Grantee shall be subject to the Award during the period beginning January 15, 2009, the date of the grant thereof (hereinafter referred to as “Grant Date”) and ending on  January 15, 2012, (which period is hereinafter referred to as “Performance Period”), as herein provided.
 
(b)   The Grantee shall earn and become entitled to receive a percentage of the number of Performance Units granted under paragraph 1, above, at the expiration of the Performance Period as provided for in Exhibit A and Exhibit B, attached hereto, based upon the Corporation’s ranking for Total Stockholder Return in the ONEOK Peer Group listed in Exhibit C attached hereto, all as determined by the Committee, in its sole discretion.
 
(c)   Upon expiration of the Performance Period, the Grantee shall be entitled to receive one (1) share of Common Stock for each Performance Unit that becomes earned by and vested in the Grantee pursuant to the Award; provided, no fractional shares shall be issued and any fractional shall be paid to the Grantee in cash.
 
(d)   All Common Stock the Grantee becomes entitled to receive pursuant to the Award and any other compensation payable to the Grantee under the Award shall be paid, distributed, transferred  and issued by the Corporation to the Grantee at the expiration of the Performance Period, or as soon a practicable after the determination that the Grantee has earned and become entitled to Performance Units and to receive such Common Stock and cash, as determined by the Committee,  and in no event later than the 15th day of the third month after the date of expiration of the Performance Period, and the Grantee shall not be permitted, directly or indirectly, to designate the time of payment, distribution or transfer or the taxable year in which it is to be made. Provided, that if the Grantee elects pursuant to paragraph 6, below, to defer the
 

 
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receipt of all Performance Units, Common Stock and cash for each Performance Unit that becomes earned by and vested in the Grantee pursuant to the Award, the payment, distribution and transfer of such Performance Units, Common Stock and cash shall be deferred and thereafter paid, distributed and transferred by the Corporation to the Grantee at the specified time and in accordance with the method of payment, distribution and transfer that is elected in by the Grantee in accordance with the election provisions set forth therein.
 
(e)   The Grantee shall not be entitled to vote any shares of Common Stock of the Corporation, or otherwise have any right or interest as a Common Stock shareholder by reason of the Performance Unit Award granted under the Award during the Performance Period, and prior to the actual transfer of Common Stock to the Grantee pursuant to the Award.
 
(f)   No dividends or any similar amounts shall be payable or paid with respect to Performance Units, Common Stock earned under the Award, or the Award during or for the Performance Period.
 
(g)   The Grantee shall have no right to receive cash or acquire shares of Common Stock of the Corporation under the Award other than the cash and Common Stock attributable to the Performance Units earned by the Grantee to the extent provided for herein.
 
(h)   The Common Stock or cash to which the Grantee becomes entitled shall be paid and transferred to the Grantee only upon the determination of the Performance Units earned by the Grantee at the expiration of the Performance Period.  The payment and transfer of such Common Stock or cash to the Grantee shall be made as soon as reasonably practicable after the expiration of the Performance Period, as determined and directed by the Committee, in its sole discretion.
 
(i)   The Performance Units or any Common Stock or cash to be paid or transferred to Grantee pursuant to the Award may not be sold, assigned, transferred, pledged, encumbered or otherwise disposed of by Grantee or any other person except as provided in the Award and the Plan until the expiration of the Performance Period and payment and transfer of Common Stock or cash pursuant to the Agreement and Plan.
 
(j)   The Grantee shall become entitled to receive Performance Units earned, and shall become owner of the shares of Common Stock or cash paid and transferred to the Grantee pursuant to the Award free and clear of all terms, conditions and restrictions imposed by the Award if the Grantee’s employment by the Corporation does not terminate during the Performance Period; provided, that the Grantee shall become entitled to a prorated amount of Performance Units and the terms and conditions imposed by the Award shall partially cease to apply in certain events to the extent described in paragraph 6(d), below.
 
(k)   If the Grantee’s employment with the Corporation (or a division or Subsidiary thereof) terminates prior to the end of the Performance Period other than by reason of retirement, Total Disability or death, the Grantee shall forfeit all of the Grantee’s right, title or interest in the Performance Units; and the Grantee shall forfeit such right, title and interest in the Performance Units regardless of the reason for such termination of employment.  Any such
 

 
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termination of employment of the Grantee described in the preceding sentence shall not be deemed to occur by reason of transfer of employment of the Grantee by or between the Corporation and any division or Subsidiary of the Corporation.  Upon a forfeiture the Performance Units forfeited shall be cancelled for all purposes.
 
6.   Deferral of Payment, Distribution and Transfer of Stock.
 
(a)  The Grantee may irrevocably elect to defer the time of  payment, distribution and transfer of Performance Units , Common Stock and cash that the Grantee becomes entitled to receive under this Agreement and Award from the end of the Performance Period generally provided for in paragraph 5, above, to a specified time by filing with the Committee, on or before the deferral election date (hereinafter referred to as "Election Date") described in paragraph 6(b), below, a signed written irrevocable election (hereinafter referred to as "Election") which shall be in the form substantially the same as attached hereto as Exhibit D, attached hereto, or as otherwise prescribed by the Committee.

(b) An Election of the Grantee to defer the payment, distribution and transfer of Performance Units, Common Stock and cash that the Grantee becomes entitled to receive under this Agreement and Award shall filed by the Grantee with the Committee on or before the Election Date, which shall be July 15, 2011, the date that is six (6) months before the end of the Performance Period, provided that the Grantee performs services for the Corporation continuously from the later of the beginning of the Performance Period or the date the performance criteria are established through the date the Election is made under this paragraph 6(b), and provided, further, that in no event may the Grantee make an Election to defer the payment, distribution and transfer of Performance Units, Common Stock or cash after such compensation has become readily ascertainable; and in this regard for purposes of this paragraph 6(b), if the amount of Performance Units, Common Stock and cash, or other compensation, as performance-based compensation, is a specified or calculable amount, then it shall be considered compensation that is readily ascertainable if and when the amount is first substantially certain to be paid, distributed and transferred to the Grantee. If the amount of Performance Units, Common Stock and cash, or other compensation, is performance-based compensation that is not a specified or calculable amount because, for example, the amount may vary based upon the level of performance, such compensation, or any portion of the compensation, shall be considered readily ascertainable when the amount is first both calculable and substantially certain to be paid. For this purpose, such performance-based compensation is to be bifurcated between the portion that is readily ascertainable and the amount that is not readily ascertainable, and, in general, any minimum amount that is both calculable and substantially certain to be paid shall be treated as readily ascertainable.
 
(c) A Grantee that makes an Election to defer payment, distribution and transfer of Performance Units, Common Stock and cash that the Grantee becomes entitled to receive under this Agreement and Award may irrevocably elect to have payment, distribution and transfer made to the Grantee at a Specified Time, that shall be either (i) the later of (A) the date of the Grantee's separation from service with the Corporation, or (B) a specified calendar date, or (ii) the date of the Grantee's separation from service with the Corporation; and may elect to have payment made in a specified form of payment that shall be either (i) a single lump sum payment, distribution
 

 
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and transfer, or (ii) a payment, distribution and transfer in two, three, four or five equal annual installments commencing at the Specified Time elected by the Grantee hereunder and thereafter on each anniversary thereof until fully paid, transferred and distributed.
 
(d) The Award shall be subject to such other rules and requirements as the Committee, in its sole discretion, may determine to be appropriate with respect to administration thereof and the restrictions made applicable to the Grantee and the Performance Units during the Performance Period.  This instrument and the rights and obligations of the parties involved, shall be subject to interpretation and construction by the Committee to the same extent and with the same effect as the Committee actions under pertinent provisions of the Plan.  The Grantee shall take all actions and execute and deliver all documents as may from time to time be requested by the Committee in connection with such restrictions and in furtherance hereof.  The Grantee agrees to pay to the Corporation any applicable federal, state, or local income, employment, social security, Medicare, or other withholding tax obligation arising in connection with the grant of the Award to the Grantee; and the Corporation shall have the right, without the Grantee’s prior approval or direction, to satisfy such withholding tax by withholding all or any part of the Common Stock that would otherwise be transferred and delivered to the Grantee, with any shares of Common Stock so withheld to be valued at the Fair Market Value (as defined in the Plan) on the date of such withholding. The Grantee, with the consent of the Corporation, may satisfy such withholding tax by delivery and transfer to the Corporation of shares of Common Stock previously owned by the Grantee, with any shares so delivered and transferred to be valued at the Fair Market Value on the date of such delivery.
 
(e) The provisions of this instrument providing for the deferral of payment, distribution, transfer or issuance of Performance Units, Common Stock or cash shall be applicable solely and exclusively to the Grantee and the Award Agreement and Award referred to herein, and shall not apply to any other stock incentive or other grant, award or transfer provided for or made under the Plan.
 
(f) Notwithstanding anything otherwise provided under the Plan or in the Award Agreement and Award, the following requirements shall apply to this Award Agreement and the Award, to all elections or subsequent elections made by the Grantee, and to all distributions and payments made to the Grantee pursuant to this Award Agreement and Award:
 
(1) Any compensation for services performed by the Grantee during a taxable year may be deferred at the Grantee's election or the Corporation's election or determination only if the election to defer such compensation is made not later than the close of the preceding taxable year or such other time as provided in Treasury Regulations under section 409A of the Internal Revenue Code of 1986, as amended ("Code"), but in all events any deferral of the payment, distribution, transfer or issuance of Performance Units, Common Stock or cash pursuant to the Award and Award Agreement may be made only by an election that is made on or before the Election Date.
 
(2) Any compensation deferred under the Plan shall not be distributed earlier than
 

 
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         (i) Separation from Service of the Grantee,
 
(ii) the date the Grantee becomes Disabled,
 
(iii) death of the Grantee,
 
 
(iv) a Specified Time (or pursuant to a Fixed Schedule) specified under the plan under which the compensation is deferred at the date of deferral of such compensation,
 
(v) a Change in Ownership or Control, or
 
(vi) the occurrence of an Unforeseeable Emergency.
 
(3) If the Grantee is a Specified Employee, no payment or distribution shall be made before the date which is six (6) months after the date of the Grantee's Separation from Service, or, if earlier, the date of death of the Grantee.
 
(4) No acceleration of the time or schedule of any distribution or payment under the plan under which compensation is deferred shall be permitted or allowed, except to the extent provided in Treasury Regulations issued under Code section 409A.
 
(5) This instrument shall not permit a subsequent election unless authorized and agreed upon in writing by  the Corporation and Grantee, and if the Plan or this instrument permits under any subsequent election by the Grantee a delay in a payment or a change in the form of payment of compensation deferred under this Award Agreement and Award, such subsequent election shall not take effect until at least twelve (12) months after the date on which it is made.  In the case of a subsequent election related to a payment to be made upon Separation from Service of the Grantee, at a Specified Time or pursuant to a Fixed Schedule, or upon a Change in Ownership or Control, the first payment with respect to which such subsequent election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such subsequent election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.
 
(6) For purposes of the Plan and this instrument and the Award, the following terms and definitions shall apply with respect to deferral of compensation and the time of payment of any deferred compensation:
 
(i) "Change of Ownership or Control" means to the extent provided by Treasury Regulations issued under Code Section 409A, a change in the ownership or effective control of the Corporation, or in the ownership of a substantial portion of the assets of the Corporation, which shall be if (i) a Person acquires more than 50% of the  Corporation’s stock; (ii) a Person acquires during a 12-month period at least 30% (or a higher percentage specified under the Plan) of the Corporation’s stock; (iii) a majority of the members of the Board of Directors of the Corporation are replaced during a 12-month period; or (iv) a  Person acquires during a 12-month period at least 40% of the gross fair market value of the Corporation’s assets.
 

 
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(ii) "Disabled" means that an individual (i) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, or (ii)  is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, receiving income replacement benefits for a period of not less than 3 months under an accident and health plan covering employees of the individual's employer.
 
(iii) "Fixed Schedule" means the distribution or payment of compensation deferred under this instrument and Award in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such compensation is first elected by or the Grantee or the Corporation.
 
(iv) "Specified Employee" means a key employee (as defined in Code section 416(i) without regard to paragraph (5) thereof) of the Corporation.
 
(v) "Specified Time" means a specified date at which deferred compensation deferred by or for the Grantee pursuant to this instrument and Award is required to be distributed or paid and which is specified at the time of the election of deferral of such deferred compensation
 
(vi) “Unforeseeable Emergency” means a severe financial hardship to the participant resulting from an illness or accident of the participant, the participant's spouse, or a dependent (as defined in Code section 152(a) ) of the participant, loss of the participant's property due to casualty, or other similar extraordinary and unforeseeable circumstances arising as a result of events beyond the control of the participant. As determined under Treasury Regulations under Code section 409A, the amounts distributed with respect to an emergency shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the participant's assets (to the extent the liquidation of such assets would not itself cause severe financial hardship)."
 
7.   Transferability of Performance Units; Termination of Employment .
 
(a)           Except as provided in subparagraph (b) of this paragraph 7, below, the Award, the Grantee’s rights and obligations hereunder and the Performance Units granted hereunder shall not be transferable by the Grantee otherwise than by will or the laws of descent and distribution which apply to the Grantee’s estate.

(b)           Notwithstanding the foregoing, the Grantee may transfer any part or all of the Grantee’s rights in and to the Performance Units to members of the Grantee’s immediate family, or to one or more trusts for the benefit of such immediate family members, or partnerships in which such immediate family members are the only partners if the Grantee does not receive any consideration for the transfer.  In the event of any such transfer, Performance

 
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Units shall continue to be subject to the same terms and conditions otherwise applicable hereunder and under the Plan immediately prior to its transfer, except that this stock shall not be further transferable by the transferee inter vivos , except for transfer back to the original Grantee.  For any such transfer to be effective, the Grantee must provide prior written notice thereof to the Committee, unless otherwise authorized and approved by the Committee, in its sole discretion; and the Grantee shall furnish to the Committee such information as it may request with respect to the transferee and the terms and conditions of any such transfer.  For purposes of transfer of this grant under this subparagraph (b), “immediate family” shall mean the Grantee’s spouse, children and grandchildren.

(c)           Notwithstanding anything to the contrary expressed or implied herein (including without limitation, the restrictions stated in paragraph 5, above, applicable to the Performance Units), all rights and interest of the Grantee in the Performance Units shall become invalid and wholly terminated and forfeited upon the termination of the Grantee’s employment with the Corporation (or a division or Subsidiary), during the Performance Period other than a termination by reason of retirement, Total Disability or death of the Grantee.
 
(d)           Notwithstanding the foregoing provisions, in the event of termination of the Grantee’s employment with the Corporation (or a division or Subsidiary) during the Performance Period by reason of (i) the Retirement of the Grantee, (ii) the Total Disability of the Grantee, or (iii) the Grantee’s death while still employed by the Corporation (or a division or Subsidiary), then an adjusted and prorated entitlement to Performance Units shall be allowed as provided in this paragraph 7(d). The Grantee shall become vested in and entitled receive, in the event of any such Retirement or Total Disability, and the legatees, designated Beneficiary, or personal representatives or heirs of the Grantee shall be vested in and entitled to receive, in the event of the Grantee’s death , a prorated award of Performance Units earned in the Performance Period following such Retirement, Total Disability or death.  The award shall be a prorated amount of Performance Units equal to the total of Performance Units earned under the Award at the end of the Performance Period for the Grantee, multiplied by a fraction of which the numerator shall be the number of full months which have elapsed under the Performance Period at the time of such termination of employment by reason of Retirement, Total Disability or death, and the denominator of which shall be the total number of months in the Performance Period. The Grantee, legatees, designated Beneficiary, or personal representatives or heirs of the Grantee, as the case may be, shall become entitled to receive such prorated award at the expiration of the Performance Period and following application of the performance criteria as provided in the Award and determined by the Committee.

(e)           The Grantee may designate a Beneficiary to receive any rights of the Grantee which may become vested in the event of the death of the Grantee under procedures and in the form established by the Committee; and in the absence of such designation of a Beneficiary, any such rights shall be deemed to be transferred to the estate of the Grantee.

(f)           For purposes of the Award and this instrument, "Retirement" shall mean a voluntary termination of employment of the Grantee with the Corporation and/or a division or subsidiary thereof by the Grantee if at the time of such termination of employment the Grantee

 
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has both completed five (5) years of service with the Corporation and/or a division or subsidiary thereof and attained age fifty (50); and except as provide for in paragraph 6 with respect to deferred compensation payments, “Total Disability” shall mean that the Grantee is permanently and totally disabled and unable to engage in any substantial gainful activity by reason of a medically determinable physical or mental impairment which can be expected to result in death or which has lasted or can be expected to last for a continuous period of not less than twelve (12) months, and has established such disability to the extent and in the manner and form as may be required under the provisions of Section 22(e) of the Internal Revenue Code of 1986, as amended (or corresponding section of any future federal tax code), and regulations thereunder.

8.   Administration of Performance Unit Award .  The grant of the Award shall be subject to such other rules and requirements as the Committee, in its sole discretion, may determine to be appropriate with respect to administration thereof and the terms and conditions made applicable to the Grantee and the Performance Units during the Performance Period.  The Award, this instrument, and the rights and obligations of the parties thereto shall be subject to interpretation and construction by the Committee to the same extent and with the same effect as the Committee actions under pertinent provisions of the Plan.  The Grantee shall take all actions and execute and deliver all documents as may from time to time be requested by the Committee in connection with such restrictions and in furtherance hereof.  The Grantee agrees to pay to the Corporation any applicable federal, state, or local income, employment, social security, medicare, or other withholding tax obligation arising in connection with the grant of the Award to the Grantee; and the Corporation shall have the right, without the Grantee’s prior approval or direction, to satisfy such withholding tax by withholding all or any part of the shares of Common Stock or cash that would otherwise be paid and transferred to the Grantee, with any shares of Common Stock so withheld to be valued at the Fair Market Value (as defined in the Plan) on the date of such withholding. The Grantee, with the consent of the Corporation, may satisfy such withholding tax by delivery and transfer to the Corporation of shares of Common Stock previously owned by the Grantee, with any shares so delivered and transferred to be valued at the Fair Market Value on the date of such delivery.
 
9.   Adjustment Provisions .  It is understood that, prior to the expiration of the Performance Period certain changes in capitalization of the Corporation may occur.  It is, therefore, understood and agreed with respect to changes in capitalization that:
 
(a)   If a stock dividend is declared on the Common Stock of the Corporation, there shall be added to the number of Performance Units provided for under the Award and stated in paragraph 1 of this instrument, the number of Performance Units equal to the number of Performance Units which would have been granted to the Grantee had the Grantee been the fully vested and unrestricted owner of the number of Performance Units then provided for under the Award granted, but not theretofore received without restriction; provided, however, that the additional Performance Units shall be subject to all terms and provisions of this instrument (including, without limitation, the terms and conditions stated in paragraph 5, above), and in making such adjustments, no fractional units, shares, or scrip certificates in lieu thereof, shall be granted or issuable by the Corporation, and the Grantee shall be entitled to only the number of full Performance Units to which the Grantee may be entitled by reason of such adjustment at the adjusted grant.

 
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(b)   In the event of an increase in the outstanding shares of Common Stock of the Corporation, effectuated for the purpose of acquiring properties or securities of another corporation or business enterprise, there shall be no increase in the number of Performance Units which are the subject matter of the Award under this instrument as a result of such acquisition.

(c)   In the event of an increase or decrease in the number of outstanding shares of Common Stock of the Corporation through recapitalization, reclassification, stock split-ups, consolidation of shares, changes in par value and the like, an appropriate adjustment shall be made in the number of Performance Units provided for under the Award and stated in Section 1 of this instrument, by increasing or decreasing the number of Performance Units, as may be required to enable the Grantee to acquire the same proportionate stockholdings as the grant of the Award would originally have provided.  Provided, however, that any additional Performance Units shall be subject to all terms and provisions of this instrument (including, without limitation, the restrictions stated in paragraph 5, above), and that in making such adjustments, no fractional Performance Units shall be awarded, and the Grantee shall be entitled to receive only the number of full Performance Units to which the Grantee may be entitled by reason of such adjustment.

(d)           Except as otherwise provided for with respect to the payment of any deferred compensation in paragraph 6, above,  to the extent Performance Units are still not vested in Grantee at the time of a Change in Control with respect to the Corporation, then pursuant to the provisions of the Plan, they shall become fully vested and completely free and clear of any conditions or restrictions stated herein at that time; provided, that if such Change in Control occurs less than six (6) months after the date of the grant of the Award hereunder to the Grantee, then Performance Units shall become fully vested and completely free and clear of any conditions or restrictions stated herein at the time of such Change in Control only if the Grantee agrees in writing, if requested by the Corporation in writing, to remain in the employ of the Corporation or a division or subsidiary of the Corporation at least through the date which is six (6) months after the date the grant was made with substantially the same title, duties, authority, reporting relationships, and compensation as on the day immediately preceding the Change in Control.  The provisions of this subparagraph (d) shall be applied in addition to, and shall not reduce, modify, or change any other obligation or right of the Grantee otherwise provided for in paragraph 3, above, concerning the Grantee’s continued employment with the Corporation or the termination thereof.  If the Performance Units become subject to this subparagraph (d), they shall become fully vested in the Grantee and nonforfeitable.  The Performance Units are subject to the provisions of the Plan authorizing the Corporation, or a committee of its Board of Directors, to provide in advance or at the time of a Change in Control for cash to be paid in actual settlement of the shares of Common Stock for earned Performance Units, all subject to such terms and conditions as the Corporation or the Committee, in its sole discretion, may determine and impose.  For purposes of this subparagraph (d), the term “Change in Control” shall have the same meaning as provided in the definition of that term stated in the Plan, including any amendments thereof which may be made from time to time in the future pursuant to the provisions of the Plan, with any amended definition of such term to apply to all events thereafter coming within the amended meaning.

 
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10.   Required Grantee Repayment/Reduction Provision.  Notwithstanding anything in the  Plan, the Award or this instrument to the contrary, all or a portion of the Award made to the Grantee  under this instrument  is subject to being called for repayment to the Corporation or reduced in any situation where the Board of Directors of the Corporation or a Committee thereof determines that fraud, negligence, or intentional misconduct by the Grantee  was a contributing factor to the Corporation having to restate all or a portion of its financial statement(s). The Committee may determine whether the Corporation  shall effect any such repayment or reduction : (i) by seeking repayment from the Grantee , (ii) by reducing (subject to applicable law and the terms and conditions of the Plan or any other applicable plan, program, or arrangement) the amount that would otherwise be awarded or payable to the Grantee  under the Award, the Plan or any other compensatory plan, program, or arrangement maintained by the Corporation , (iii) by withholding payment of future increases in compensation (including the payment of any discretionary bonus amount) or grants of compensatory awards that would otherwise have been made in accordance with the Corporation's  otherwise applicable compensation practices, or (iv) by any combination of the foregoing. The determination regarding the Grantee's  conduct, and repayment or reduction under this provision shall be within the sole discretion of the Committee and shall be final and binding on the Grantee  and the Corporation. The Grantee, in consideration of the grant of the Award, and by the Grantee's execution of this instrument, acknowledges the Grantee's understanding of and agreement to this provision, and hereby agrees to make and allow an immediate and complete repayment or reduction in accordance with this provision in the event of a call for repayment or other action by the Corporation or Committee to effect its terms with respect to the Grantee, the Award and/or any other compensation described herein.
 
11.   Stock Reserved .  The Corporation shall at all times during the term of the Award reserve and keep available such number of shares of its Common Stock as will be sufficient to satisfy the Award issued and granted to Grantee and the requirements thereof as evidenced by this instrument, and shall pay all original issue taxes, if any, on the transfer of Common Stock to the Grantee, and all other fees and expenses necessarily incurred by the Corporation in connection therewith.
 
12.   Rights of Shareholder .  Except as otherwise provided in the Award and this instrument, the Grantee shall have no rights as a shareholder of the Corporation in respect of the Performance Units or Common Stock for which the Award is granted; and the Grantee shall not be considered or treated as a record owner of shares with respect to the Common Stock until the Performance Units are fully vested and no longer subject to any of the conditions, performance requirements, or restrictions imposed under the Award, and Common Stock is actually issued and transferred to the Grantee.
 
13.   Entire Agreement .  This instrument contains the entire terms of the Award, and may not be changed orally or other than by a written instrument issued and approved by the Corporation pursuant to the Plan.  This instrument supersedes any agreements or understandings that may previously have existed, and there are no other agreements or understandings, relating to its subject matter.
 

 
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14.   Successors and Assigns .  The Award shall inure to the benefit of and be binding upon the heirs, legatees, legal representatives, successors, and assigns of the parties thereto.
 
The Grantee hereby acknowledges receipt of this instrument, the Notice of Performance Unit Award and a copy of the Plan, and accepts the Award under the terms and conditions stated in this instrument, subject to all terms and provisions of the Plan, by signing this instrument in duplicate originals, as of the date first above written.
 
 
 
                                                           
                                          
Date
 
«Officer_Name»
   
Grantee

   

 
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Exhibit  A
Performance Units Criteria
2009-2012 Performance Period
 


Total Stockholder Return (TSR):vs. ONEOK Peer Group
 
ONEOK TSR Ranking vs.ONEOK Peer Group
Percentage of Performance Units Earned
90th percentile and above
75th percentile
50th percentile
25th percentile
Below 25th percentile
200%
150%
100%
50%
0%

IF ONEOK’s TSR ranking at the end of the performance period is between the stated percentile levels in the above table, the percentage of the performance units earned will be interpolated between the earning levels.  No Performance Units are earned if ONEOK’s TSR ranking at the end of the performance period is below the 25 th percentile





 
 

 


Exhibit B
Illustration of Hypothetical 2009-20012 Performance Period
Performance Unit Award Calculation
 
Illustration assumes 1,000 Performance Units Granted in January 2009
 

Total Stockholder Return (TSR) vs. ONEOK Peer Group
 
Hypothetical 2007-2010 ONEOK TSR Ranking = 40th percentile
 
A 40th percentile TSR ranking earns 80% of Performance Units granted (i.e., 1,000 units)
as interpolated between 50% and 100% from Table A (see chart below)
 
800 units earned
 


Total Performance Units Earned
 
TR 800 Performance Units
 
800 performance units earned out of 1,000 units granted = 80.0% “earn-out” [80% (1,000 shares) paid and distributed in the form of Common Stock as provided in section 5.c.]
 

 

 

 
 

 


Exhibit  C
ONEOK PEER GROUP – 2009
           
Company Name
Sym
       
           
AGL Resources Inc.
ATG
       
ATMOS Energy
ATO
       
CenterPoint Energy Inc.
CNP
       
DCP Midstream Partners LP
DPM
       
Enbridge Inc.
ENB
       
Energy Transfer Partners LP
ETP
       
Enterprise Prods Prtner LP
EPD
       
Kinder Morgan Energy LP
KMP
       
OGE Energy CP
OGE
       
National Fuel Gas Company
NFG
       
New Jersey Resources Corp
NJR
       
NICOR Inc.
GAS
       
NiSource Inc.
NI
       
ONEOK, Inc .
OKE
       
Piedmont Natural Gas Company
PNY
       
SEMPRA Energy
SRE
       
Southern Union Company
SUG
       
Southwest Gas Corporation
SWX
       
Spectra Energy Corporation
SE
       
Teppco Partners LP
TPP
       
Transcanada Corporation
TRP
       
UGI Corporation
UGI
       
Vectren Corporation
VVC
       
WGL Holdings Inc.
WGL
       
Wisconsin Energy Corp
WEC
       


 
 

 



Exhibit D

ONEOK, INC. EQUITY COMPENSATION PLAN

PERFORMANCE UNIT AWARD AGREEMENT

DEFERRAL ELECTION

This Election is made by the undersigned Grantee pursuant to that certain Performance Unit Award granted to me under the ONEOK, Inc. Equity Compensation Plan, on the 15th day of January 2009, a copy of which is attached hereto (the "Award").

This Election is made on or before the date of July 15, 2011, which is six (6) months before the end of the Performance Period on January 15, 2012.

I hereby irrevocably elect to defer the payment, distribution and transfer and my receipt of all Performance Units, Common Stock and cash that I may earn and become entitled to receive from the regularly scheduled time of payment, distribution and transfer provided for in Section 5(d) of the Award, until a later date as follows:


A.           Election of Specified Time of Payment

(Initial one election of time of payment)

___           I elect to have all Common Stock, cash or other compensation which I earn or become entitled to receive under the Award and Award Agreement deferred and paid, distributed, transferred and issued to me on the later of (i) the date of my separation from service as an employee of the Corporation , or (ii) _________________, 20__ in the form specified below.

___           I elect to have all Common Stock, cash or other compensation which I earn or become entitled to receive under  the Award and Award Agreement deferred and paid, distributed, transferred and issued to me on the date of my separation from service as an employee of the Corporation.

B.           Election of Form of Payment

(Initial one election of form of payment)

___           I elect to receive payment, transfer and distribution of all Common Stock, cash or other compensation which I earn or become entitled to receive under the Award or Award Agreement in a single lump sum payment.

____           I elect to receive payment, transfer and distribution of all Common Stock, cash or other compensation which I earn or become entitled to receive under the Award or Award Agreement in ______(specify 2, 3, 4 or 5) equal annual installments commencing on the specified date of payment elected above, and thereafter on each anniversary thereof until fully paid and transferred. The number of shares of Common Stock or cash received in each installment will equal the number and amount that have not been settled, paid, transferred and distributed (as of the date immediately preceding the installment payment date) divided by the number of installments remaining to be paid (as of the date immediately preceding the installment payment date) rounded down to the next whole number except that the final installment shall be rounded up to the next whole number.

 
 

 

C.            Election for Death Prior to Specified Time of Payment (Put initials by your choice)

___           In the event of my death prior to the Specified Time of Payment that I have elected above, I elect to have my named beneficiaries receive payment and transfer of the Common Stock, cash or other deferred compensation in a single lump sum within 60 days following my death.

___           In the event of my death prior to the Specified Time of Payment that I have elected above, I elect to have my named beneficiaries receive payment and transfer of the Common Stock, cash or other deferred compensation be paid and transferred in ______ ( specify 2, 3, 4 or 5 ) equal annual installments commencing within 60 days following my death, and thereafter on each anniversary of the commencement date until fully paid and transferred. The number of shares of Common Stock or cash received in each installment will equal the number and amount that have not been paid (as of the date immediately preceding the installment payment date) divided by the number of installments remaining to be paid (as of the date immediately preceding the installment payment date) rounded down to the next whole number except that the final installment shall be rounded up to the next whole number.

D.           Election for Death After Specified Time of Payment (Put initials by your choice)

___           In the event of my death after the Specified Time of Payment elected above, I elect to have my named beneficiaries receive payment and transfer of the Common Stock, cash or other deferred compensation in a single lump sum within 60 days following my death.

___           In the event of my death after the Specified Time of Payment that I have elected above, I elect to have my named beneficiaries receive payment of any remaining Common Stock, cash or other compensation in accordance with the installment schedule elected above.

E.           Designation of Beneficiary ( List each beneficiary and percentage)

I designate the following individuals (entities) as my beneficiaries to receive the following share(s) of my Common Stock, cash or other deferred compensation, as indicated below:

Name of Beneficiary                                                                                                                                    Percent
_______________________________________                                                                                                           __________
_______________________________________                                                                                                           __________
_______________________________________                                                                                                           __________
_______________________________________                                                                                                           __________
_______________________________________                                                                                                           __________
                                       100% (total must equal 100%)

F.           Change in Ownership or Control

Notwithstanding the foregoing, immediately following a Change in Ownership or Control the Common Stock, cash or other deferred compensation that have not been paid and transferred will be paid and transferred.  In the event shares of Common Stock no longer exist at the time of payment and transfer, each of the deferred Performance Units shall be converted in a manner that is consistent with the manner in which shareholders of Common Stock were treated with respect to the Change in Ownership or Control.

Solely for purposes of this election, a “Change in Ownership or Control” shall mean and shall have occurred if one of the following has occurred: A person acquires more than 50% (or a higher percentage specified under the Plan) of the Corporation’s stock;  a person acquires during a 12-month period at least 30% (or a higher percentage specified under the Plan) of the Corporation’s stock; a majority (or a higher percentage specified under the Plan) of the members of the Board of Directors of the Corporation are replaced during a 12-month period; or a person acquires during a 12-month period at least 40% (or a higher percentage specified under the Plan) of the gross fair market value of the Corporation’s assets.

 
 

 

Made and executed by me as Grantee of the Award pursuant to the terms and provisions of Section 6 thereof, on this _______day of ______________, 20___.


_____________________________________
Grantee


Received this ____day of ____________, 20___,

______________________________________
For the Committee

 
 

 

 
 
 
Exhibit 10.55

RESTRICTED UNIT
 
STOCK BONUS AWARD
 
AGREEMENT
 
This instrument is issued as of the 15 th day of January, 2009, by ONEOK, Inc., an Oklahoma corporation, (hereinafter referred to as “Corporation”), to «Officer_Name» (hereinafter referred to as “Grantee”), an employee of the Corporation or a division or subsidiary thereof, pursuant to the terms of the ONEOK, Inc. Long-Term Incentive Plan, as amended (hereinafter referred to as the “Plan”).
 
1.   Restricted Unit Award .  This instrument and that certain Restricted Unit Stock Bonus Award and Agreement, dated January 15, 2009, a copy of which is attached hereto and incorporated herein by reference (the “Notice of Restricted Unit Stock Bonus Award and Agreement”) constitute evidence of the issuance and grant of a Stock Bonus Award (hereinafter referred to as "Award") to the Grantee by the Corporation under the Plan pursuant to which shares of the Corporation's Common Stock (hereinafter referred to as "Common Stock") shall be distributed in the future to the Grantee in lieu of, or as a supplement to, any other compensation that may have been earned by services rendered prior to the date the distribution is made, pursuant to and in accordance with the terms of this instrument under which the Corporation grants a Stock Bonus Award under the Plan that shall include and is to be awarded by the grant restricted stock units (hereinafter referred to a "Restricted Units) under the Plan in the amount of «No_of_Restricted_Units» Restricted Units that shall entitle the Grantee to receive shares of Common Stock  all subject to the terms, provisions, and conditions of this instrument (including, without limitation, the restrictions stated in paragraph 5, below) and of the Plan, which are incorporated herein by reference.  This instrument, when executed by the Grantee, together with the Notice of Restricted Unit Stock Bonus Award and Agreement constitute an agreement between the Corporation and the Grantee.  Notwithstanding the foregoing, should there be any inconsistency between the provisions of this instrument and the terms of the Award stated in the resolutions and records of the Board of Directors of the Corporation, or the Plan, the provisions of such resolutions and records and of the Plan shall control.  The grant of Restricted Units to the Grantee and the Grantee’s entitlement to receive and be issued shares of Common Stock shall be effective in the manner and to the extent provided in this instrument and the Plan as to all or any part of the shares of Common Stock subject to the grant from time to time during the period stated herein.
 
2.   Plan .  The Award is issued pursuant to the Plan, as approved by the Shareholders of the Corporation, which provides that a specific aggregate number of shares of Common Stock of the Corporation may be issued or transferred pursuant to Stock Incentives under the Plan.  The Plan specifies the authority of the Corporation, its Board of Directors, and a committee of the Board of Directors to select employees to be granted Stock Incentives.  The Executive Compensation Committee of the Board of Directors (hereinafter referred to as the “Committee”) is authorized to administer the Plan with respect to the Award and the grant of the Award made to the Grantee pursuant to the Plan.  Except where expressly stated or clearly indicated otherwise by the terms of this instrument, all terms, words and phrases used herein shall have the same meaning and effect as stated in the Plan.  The Grantee has been provided a complete copy of the Plan with this instrument.
 

  
 
 

 

3.   Grantee’s Agreement Concerning Award and Employment .  In consideration of the Corporation’s granting the Award as incentive compensation to Grantee pursuant to this instrument, the Grantee by acceptance thereof, and signing this instrument evidencing its terms, agrees to such terms and to continue to contribute and perform service in the employ of the Corporation or a division or subsidiary thereof at the direction, will and pleasure of the Corporation and the Board of Directors.  Provided, however, neither the foregoing agreement of the Grantee in this paragraph 3, nor any other provision in the Plan shall confer on the Grantee any right to continue in the employ of the Corporation (or a division or subsidiary thereof), or interfere in any way with the right of the Corporation (or such division or subsidiary) to terminate the Grantee’s employment at any time.
 
4.   Registration of Stock; Grantee’s Representation With Respect To Acquiring for Investment .  It is intended by the Corporation that the Plan and shares of Common Stock covered by the Award issued and granted to the Grantee referred to in paragraph 1, above, are to be registered under the Securities Act of 1933, as amended, prior to the date of the grant; provided, that in the event such registration is for any reason not made effective for such shares, the Grantee agrees, for the Grantee, and for the Grantee’s heirs and legal representatives by inheritance or bequest, that all shares acquired pursuant to the grant will be acquired for investment and not with a view to, or for sale or tender in connection with the distribution of any part thereof, including any transfer or distribution of such shares by the Grantee pursuant to the grant and this instrument or as otherwise allowed by the Plan.
 
5.   Restrictions; Restricted Period; Transfer of Common Stock to Grantee .  The issue and grant of the Award to the Grantee stated in paragraph 1, above, are subject to the following terms and conditions:
 
(a)   The ownership and transfer of the Restricted Units granted to the Grantee shall be restricted during the period beginning January 15, 2009, the date of the grant thereof (hereinafter referred to as “Grant Date”) and ending on January 15, 2012, (which period is hereinafter referred to as “Restricted Period”), as herein provided.
 
(b)   The Restricted Units, or any Common Stock or cash to be paid or transferred to Grantee as a Stock Bonus Award under the Plan pursuant to the Award may not be sold, assigned, transferred, pledged, encumbered or otherwise disposed of by Grantee or any other person except as provided in this instrument and the Plan until the expiration of the Restricted Period.
 
(c)   The Grantee shall earn and become vested and entitled to the Restricted Units granted by this Award under paragraph 1, above, at the expiration of the Restricted Period.  Upon expiration of the Restricted Period, the Grantee shall be entitled to receive, and the Corporation shall issue to Grantee one (1) share of Common Stock for each Restricted Unit that becomes earned by and vested in the Grantee pursuant to the Award.  The Common Stock the Grantee becomes entitled to receive under the Award shall paid, distributed, transferred and issued on the date of expiration of the Restricted Period, or a soon as practicable after such date as determined by the Committee, but in no event after the 15th day of the third month after such date.
 

 
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(d)   The Grantee shall become vested in the Restricted Units granted to the Grantee hereunder and Common Stock paid and transferred pursuant to the Award free and clear of all restrictions imposed by the Award if the Grantee’s employment by the Corporation (or a division or Subsidiary thereof) does not terminate during the Restricted Period; provided, that the Grantee shall become partially vested in the Restricted Units and Common Stock payable pursuant to the Award and the restrictions imposed by the Award shall partially cease to apply in certain events to the extent described in paragraph 6(d), below.
 
(e)   If the Grantee’s employment with the Corporation (or a division or Subsidiary thereof) terminates prior to the end of the Restricted Period by reason of (i) the Grantee’s voluntary termination of the Grantee’s employment with the Corporation (or a division or Subsidiary), or (ii) the involuntary Termination for Cause by the Corporation of the Grantee’s employment with the Corporation (or a division or Subsidiary), the Grantee shall forfeit all the Grantee’s right, title or interest in the Restricted Units, and to any Common Stock payable  or to be issued pursuant to the Award; and the Grantee shall forfeit such right, title and interest in the Restricted Units, and to any Common Stock payable or to be issued pursuant to the Award regardless of the reason for such termination of employment.  Any such termination of employment of the Grantee described in the preceding sentence shall not be deemed to occur by reason of transfer of employment of the Grantee by or between the Corporation and any division or Subsidiary of the Corporation.
 
(f)   The Grantee shall not be entitled to vote any shares of Common Stock that may be issued to the Grantee pursuant to the Award prior to the end of the Restricted Period and actual issuance of such Common Stock to the Grantee pursuant to the Award.
 
(g)   No dividends with respect to shares of Common Stock that may be issued to the Grantee under the Award shall accrue or become payable to the Grantee prior to the end of the Restricted Period and issuance of such Common Stock to Grantee pursuant to the Award.
 
6.   Transferability of Restricted Units, Cash or Common Stock; Termination of Employment .
 
(a)   Except as provided in subparagraph (b) of this paragraph 6, below, this instrument, the Grantee’s rights and obligations hereunder, and the Restricted Units granted hereunder shall not be transferable by the Grantee otherwise than by will or the laws of descent and distribution which apply to the Grantee’s estate.
 
(b)   Notwithstanding the foregoing, the Grantee may transfer any part or all of the Grantee’s rights in the Restricted Units to members of the Grantee’s immediate family, or to one or more trusts for the benefit of such immediate family members, or partnerships in which such immediate family members are the only partners if the Grantee does not receive any consideration for the transfer.  In the event of any such transfer, Restricted Units shall continue to be subject to the same terms and conditions otherwise applicable hereunder and under the Plan immediately prior to its transfer, except that such rights shall not be further transferable by the transferee inter vivos , except for transfer back to the original Grantee.  For any such transfer to be effective, the Grantee must provide prior written notice thereof to the Committee, unless otherwise authorized and approved by the Committee, in its sole discretion; and the Grantee shall
 

 
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furnish to the Committee such information as it may request with respect to the transferee and the terms and conditions of any such transfer.  For purposes of transfer of this grant under this subparagraph (b), “immediate family” shall mean the Grantee’s spouse, children and grandchildren.
 
(c)   Notwithstanding anything to the contrary expressed or implied herein (including without limitation, the restrictions stated in paragraph 5, above, applicable to the Restricted Units), all rights and interest of the Grantee in the Restricted Units shall become invalid and wholly terminated and forfeited upon (i) the Grantee’s voluntary termination of the Grantee’s employment with the Corporation (or a division or Subsidiary), or (ii) the involuntary Termination for Cause by the Corporation of the Grantee’s employment with the Corporation (or a division or Subsidiary).
 
(d)   Notwithstanding the foregoing provisions, in the event of termination of the Grantee’s employment with the Corporation (or a division or Subsidiary) during the Restricted Period by reason of (i) the involuntary termination of the Grantee’s employment with the Corporation (or a division or Subsidiary) other than a Termination for Cause (ii) the Retirement of the Grantee, (iii) the Total Disability of the Grantee, or (iv) the Grantee’s death while still employed by the Corporation (or a division or Subsidiary), then partial vesting shall be allowed as provided in this paragraph 6(d) and the Grantee shall become vested in and receive, in the event of any such involuntary termination of employment other than a Termination for Cause, Retirement or Total Disability, and the legatees, designated Beneficiary, personal representative or heirs of the Grantee shall be vested in and entitled to receive, in the event of the Grantee’s death, the percentage of the Restricted Units which is determined by dividing the number of full months which have elapsed under the Restricted Period at the time of such termination of employment by the number of full months in the Restricted Period.  The Grantee, or legatees, designated Beneficiary, personal representative or heirs of the Grantee, as applicable, shall be entitled to receive and the Corporation shall issue, to the Grantee, or such legatees, designated Beneficiary, personal representative or heirs, as applicable, one share of Common Stock for each vested Restricted Unit, which shall be issued, paid and transferred pursuant to the Award free and clear of all restrictions imposed by the Award on the date of expiration of the Restricted Period, or as soon as practicable thereafter as determined by the Committee, but in no event later than the 15th day of the third calendar month  after the date of the expiration of the Restricted Period.
 
(e)   The Grantee may designate a Beneficiary to receive any rights of the Grantee which may become vested in the event of the death of the Grantee under procedures and in the form established by the Committee; and in the absence of such designation of a beneficiary, any such rights shall be deemed to be transferred to the estate of the Grantee.
 
(f)   For purposes of the Award to the Grantee and this instrument, an involuntary “Termination for Cause” of the Grantee’s employment with and by the Corporation (or a division or Subsidiary) shall mean that the Corporation (or a division or Subsidiary) has terminated such employment by reason of (i) the Grantee’s conviction in a court of law of a felony, or any crime or offense involving misuse or misappropriation of money or property, (ii) the Grantee’s violation of any covenant, agreement or obligation not to disclose confidential information regarding the business of the Corporation (or a division or Subsidiary), (iii) any violation by the
 

 
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Grantee of any covenant not to compete with the Corporation (or a division or Subsidiary), (iv) any act of dishonesty by the Grantee which adversely effects the business of the Corporation (or a division or Subsidiary), (v) any willful or intentional act of the Grantee which adversely affects the business of, or reflects unfavorably on the reputation of the Corporation (or a division or Subsidiary); (vi) the Grantee’s use of alcohol or drugs which interferes with the Grantee’s performance of duties as an employee of the Corporation (or a division or Subsidiary), or (vii) the Grantee’s failure or refusal to perform the specific directives of the Corporation’s Board of Directors, or its officers which directives are consistent with the scope and nature of the Grantee’s duties and responsibilities with the existence and occurrence of all of such causes to be determined by the Corporation, in its sole discretion; provided, that nothing contained in the foregoing provisions of this paragraph shall be deemed to interfere in any way with the right of the Corporation (or a division or Subsidiary), which is hereby acknowledged, to terminate the Grantee’s employment at any time without cause.
 
(g)   For purposes of this instrument and the Award,"Retirement" shall mean a voluntary termination of employment of the Grantee with the Corporation and/or a division or subsidiary thereof by the Grantee if at the time of such termination of employment the Grantee has both completed five (5) years of service with the Corporation and/or a division or subsidiary thereof and attained age fifty (50); and“Total Disability” shall mean that the Grantee is permanently and totally disabled and unable to engage in any substantial gainful activity by reason of a medically determinable physical or mental impairment which can be expected to result in death or which has lasted or can be expected to last for a continuous period of not less than twelve (12) months, and has established such disability to the extent and in the manner and form as may be required under the provisions of Section 22(e)(3) of the Internal Revenue Code of 1986, as amended (or corresponding section of any future federal tax code), and regulations thereunder.
 
7.   Deferral of Payment, Distribution and Transfer of Stock.
 
(a)   The payment, distribution and transfer of Restricted Units, Common Stock and cash of the Grantee becomes entitled to receive upon the Grantee's separation from service with the Corporation upon the Grantee's Retirement prior to the expiration of the Restricted Period under paragraph 6 (d), above, shall be paid, distributed and transferred to the Grantee in a single payment, distribution and transfer at the Specified Time of the Grantee's separation from service with the Corporation by such Retirement, as soon as practicable thereafter as determined by the Committee,  but in no event later than the 15th day of the third calendar month after date of such Retirement, and the Grantee shall not be permitted, directly or indirectly, to designate the time of payment, distribution and transfer or the taxable year in which it is to be made.  The Specified Time of payment, distribution and transfer of any other compensation that is deferred under this instrument or the Award shall be the date of expiration of the Restricted Period, or as soon as practicable thereafter as determined by the Committee, but in no event later than the 15th day of the third calendar month after the date of expiration of the Restricted Period, and the Grantee shall not be permitted, directly or indirectly, to designate the time of payment, distribution or transfer or the taxable year in which it is to be made.
 
(b)   The Specified Time of payment and form of payment specified in paragraph 6(a), above shall be considered as the irrevocable deferral election of the Corporation and the Grantee
 

 
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of the time and form of payment for purposes of the application to this instrument and the Award of the provisions of Section 409A of the Internal Revenue Code of 1986, as amended, and the provisions of this instrument related thereto.  No other election to defer compensation, or subsequent election or acceleration of the time and form of payment of compensation is intended or shall be allowed.
 
(c)   The Award shall be subject to such other rules and requirements as the Committee, in its sole discretion, may determine to be appropriate with respect to administration thereof and the restrictions made applicable to the Grantee and the Restricted Units during the Restricted Period.  This instrument and the rights and obligations of the parties involved, shall be subject to interpretation and construction by the Committee to the same extent and with the same effect as the Committee actions under pertinent provisions of the Plan.  The Grantee shall take all actions and execute and deliver all documents as may from time to time be requested by the Committee in connection with such restrictions and in furtherance hereof.  The Grantee agrees to pay to the Corporation any applicable federal, state, or local income, employment, social security, Medicare, or other withholding tax obligation arising in connection with the grant of the Award to the Grantee; and the Corporation shall have the right, without the Grantee’s prior approval or direction, to satisfy such withholding tax by withholding all or any part of the Common Stock that would otherwise be transferred and delivered to the Grantee, with any shares of Common Stock so withheld to be valued at the Fair Market Value (as defined in the Plan) on the date of such withholding. The Grantee, with the consent of the Corporation, may satisfy such withholding tax by delivery and transfer to the Corporation of shares of Common Stock previously owned by the Grantee, with any shares so delivered and transferred to be valued at the Fair Market Value on the date of such delivery.
 
(d)   The provisions of this instrument providing for the deferral of payment, distribution, transfer or issuance of Restricted Units, Common Stock or cash shall be applicable solely and exclusively to the Grantee and the Award Agreement and Award referred to herein, and shall not apply to any other stock incentive or other grant, award or transfer provided for or made under the Plan.
 
(e)   Notwithstanding anything otherwise provided under the Plan or in this instrument  the following requirements shall apply to this Award Agreement and the Award, to all elections or subsequent elections made by the Grantee, and to all distributions and payments made to the Grantee pursuant to this Award Agreement and Award:
 
(1)   Any compensation for services performed by the Grantee during a taxable year may be deferred  only if the election to defer such compensation by the Grantee or the Corporation is made not later than the close of the preceding taxable year or such other time as provided in Treasury Regulations under section 409A of the Internal Revenue Code of 1986, as amended ("Code"), but in all events any deferral of the payment, distribution, transfer or issuance of Restricted Units, Common Stock or cash pursuant to the Award and Award Agreement may be made only by an election that is made on or before the Election Date.
 
(2)   Any compensation deferred shall not be distributed earlier than:
 
(i)  
Separation from Service of the Grantee,
 

 
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(ii)  
the date the Grantee becomes Disabled,
 
(iii)  
death of the Grantee,
 
(iv)  
Specified Time (or pursuant to a Fixed Schedule) specified under the plan under which the compensation is deferred at the date of deferral of such compensation,
 
(v)  
a Change in Ownership or Control, or
 
(vi)  
the occurrence of an Unforeseeable Emergency.
 
(3)   If the Grantee is a Specified Employee, no payment or distribution shall be made before the date which is six (6) months after the date of the Grantee's Separation from Service, or, if earlier, the date of death of the Grantee.
 
(4)   No acceleration of the time or schedule of any distribution or payment under the plan under which compensation is deferred shall be permitted or allowed, except to the extent provided in Treasury Regulations issued under Code section 409A.
 
(5)   This instrument shall not permit a subsequent election, unless authorized and agreed to in writing by the Corporation and Grantee; and if under the Plan or this instrument compensation is deferred or the Committee acting pursuant to the Plan, permits under any subsequent election by a Participant a delay in a payment or a change in the form of payment of compensation deferred under this Award Agreement and Award, such subsequent election shall not take effect until at least twelve (12) months after the date on which it is made.  In the case of a subsequent election related to a payment to be made upon Separation from Service of the Grantee, at a Specified Time or pursuant to a Fixed Schedule, or upon a Change in Ownership or Control, the first payment with respect to which such subsequent election is made shall be deferred for a period of not less than five (5) years from the date such payment would otherwise have been made; and any such subsequent election related to a payment at a Specified Time or pursuant to a Fixed Schedule may not be made less than twelve (12) months prior to the date of the first scheduled payment to which it relates.
 
(6)   For purposes of the Plan, this instrument and the Award, and the entitlement to and time of payment of any compensation deferred under this instrument or the Award, the following terms and definitions shall apply:
 
(i)   "Change of Ownership or Control" means to the extent provided by Treasury Regulations issued under Code Section 409A, a change in the ownership or effective control of the Corporation, or in the ownership of a substantial portion of the assets of the Corporation, which shall be if (i) a Person acquires more than 50% of the  Corporation’s stock; (ii) a Person acquires during a 12-month period at least 30% (or a higher percentage specified under the Plan) of the Corporation’s stock; (iii) a majority of the members of the Board of Directors of the Corporation are replaced during a 12-month period; or (iv) a  Person acquires during a 12-month period at least 40% of the gross fair market value of the Corporation’s assets.
 
(ii)   "Disabled" means that an individual (i) is unable to engage in any substantial gainful activity by reason of any medically determinable physical or mental impairment which
 

 
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can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, or (ii)  is, by reason of any medically determinable physical or mental impairment which can be expected to result in death or can be expected to last for a continuous period of not less than 12 months, receiving income replacement benefits for a period of not less than 3 months under an accident and health plan covering employees of the individual's employer.
 
(iii)   "Fixed Schedule" means the distribution or payment of compensation deferred under this instrument and award in a fixed schedule of distributions or payments that are determined and fixed at the time the deferral of such compensation is first elected by or the Grantee or the Corporation.
 
(iv)   "Specified Employee" means a key employee (as defined in Code section 416(i) without regard to paragraph (5) thereof) of the Corporation.
 
(v)   "Specified Time" means a specified date at which deferred compensation deferred by or for the Grantee pursuant to this instrument and Award is required to be distributed or paid and which is specified at the time of the election of deferral of such deferred compensation.
 
(vi)   “Unforeseeable Emergency” means a severe financial hardship to the participant resulting from an illness or accident of the participant, the participant's spouse, or a dependent (as defined in Code section 152(a) ) of the participant, loss of the participant's property due to casualty, or other similar extraordinary and unforeseeable circumstances arising as a result of events beyond the control of the participant. As determined under Treasury Regulations under Code section 409A, the amounts distributed with respect to an emergency shall not exceed the amounts necessary to satisfy such emergency plus amounts necessary to pay taxes reasonably anticipated as a result of the distribution, after taking into account the extent to which such hardship is or may be relieved through reimbursement or compensation by insurance or otherwise or by liquidation of the participant's assets (to the extent the liquidation of such assets would not itself cause severe financial hardship).
 
8.   Administration of Restricted Unit Award .  The grant of the Award shall be subject to such other rules and requirements as the Committee, in its sole discretion, may determine to be appropriate with respect to administration thereof and the restrictions made applicable to the Grantee and the Restricted Units during the Restricted Period.  This instrument and the rights and obligations of the parties involved, shall be subject to interpretation and construction by the Committee to the same extent and with the same effect as the Committee actions under pertinent provisions of the Plan.  The Grantee shall take all actions and execute and deliver all documents as may from time to time be requested by the Committee in connection with such restrictions and in furtherance hereof.  The Grantee agrees to pay to the Corporation any applicable federal, state, or local income, employment, social security, medicare, or other withholding tax obligation arising in connection with the grant of the Award to the Grantee; and the Corporation shall have the right, without the Grantee’s prior approval or direction, to satisfy such withholding tax by withholding all or any part of the Common Stock that would otherwise be transferred and delivered to the Grantee, with any shares of Common Stock so withheld to be valued at the Fair Market Value (as defined in the Plan) on the date of such withholding. The Grantee, with the consent of the Corporation, may satisfy such withholding tax by delivery and transfer to the
 

 
- 8 -

 

Corporation of shares of Common Stock previously owned by the Grantee, with any shares so delivered and transferred to be valued at the Fair Market Value on the date of such delivery.
 
9.   Adjustment Provisions .  It is understood that, prior to the expiration of the Restricted Period, certain changes in capitalization of the Corporation may occur.  It is, therefore, understood and agreed with respect to changes in capitalization that:
 
(a)   If a stock dividend is declared on the Common Stock of the Corporation, there shall be added to the number of Restricted Units described in paragraph 1 of this instrument, the number of Restricted Units which the Grantee would have been entitled to if the Grantee had been the fully vested and unrestricted owner of the number of Restricted Units then held under the Award granted, but not theretofore received without restriction; provided, however, that the additional Restricted Units shall be subject to all terms and provisions of this instrument (including, without limitation, the restrictions stated in paragraph 5, above), and in making such adjustments, no fractional Restricted Units shall be awarded, and the Grantee shall be entitled to receive only the number of full Restricted Units to which the Grantee may be entitled by reason of such adjustment at the adjusted grant price per share.
 
(b)   In the event of an increase in the outstanding shares of Common Stock of the Corporation, effectuated for the purpose of acquiring properties or securities of another corporation or business enterprise, there shall be no increase in the number of shares of Restricted Units which are the subject matter of the Award evidenced by this instrument as a result of such acquisition.
 
(c)   In the event of an increase or decrease in the number of outstanding shares of Common Stock of the Corporation through recapitalization, reclassification, stock split-ups, consolidation of shares, changes in par value and the like, an appropriate adjustment shall be made in the number of Restricted Units described in paragraph 1 of this instrument, by increasing or decreasing the number of Restricted Units, as may be required to enable the Grantee to acquire the same proportionate stockholdings as the grant of the Award would originally have provided.  Provided, however, that any additional Restricted Units shall be subject to all terms and provisions of this instrument (including, without limitation, the restrictions stated in paragraph 5, above), and that in making such adjustments, no fractional Restricted Units shall be awarded, and the Grantee shall be entitled to receive only the number of full Restricted Units to which the Grantee may be entitled by reason of such adjustment.
 
(d)   Except with respect to the time of payment of any compensation deferred under this instrument, to the extent Restricted Units are still restricted and not vested in Grantee at the time of a Change in Control with respect to the Corporation, then pursuant to the provisions of the Plan, they shall become fully vested and completely unrestricted and free and clear of any restrictions stated herein at that time; provided, that if such Change in Control occurs less than six (6) months after the date of the grant of Restricted Units to the Grantee, then Restricted Units shall become fully vested and completely unrestricted and free and clear of any restrictions stated herein at the time of such Change in Control only if the Grantee agrees in writing, if requested by the Corporation in writing, to remain in the employ of the Corporation or a division or subsidiary of the Corporation at least through the date which is six (6) months after the date the grant was made with substantially the same title, duties, authority, reporting relationships, and
 

 
- 9 -

 

compensation as on the day immediately preceding the Change in Control.  The provisions of this subparagraph (d) shall be applied in addition to, and shall not reduce, modify, or change any other obligation or right of the Grantee otherwise provided for in paragraph 3, above, concerning the Grantee’s continued employment with the Corporation or the termination thereof.  If the Restricted Units become subject to this subparagraph (d), they shall become fully vested in the Grantee and nonforfeitable.  Such Restricted Units are subject to the provisions of the Plan authorizing the Corporation, or a committee of its Board of Directors, to provide in advance or at the time of a Change in Control for cash to be paid in settlement of the Restricted Units, all subject to such terms and conditions as the Corporation or the Committee, in its sole discretion, may determine and impose.  For purposes of this subparagraph (d), the term “Change in Control” shall have the same meaning as provided in the definition of that term stated in the Plan, including any amendments thereof which may be made from time to time in the future pursuant to the provisions of the Plan, with any amended definition of such term to apply to all events thereafter coming within the amended meaning.
 
10.   Required Grantee Repayment/Reduction Provision.  Notwithstanding anything in the  Plan, the Award or this instrument to the contrary, all or a portion of the Award made to the Grantee  under this instrument  is subject to being called for repayment to the Corporation or reduced in any situation where the Board of Directors of the Corporation or a Committee thereof determines that fraud, negligence, or intentional misconduct by the Grantee  was a contributing factor to the Corporation having to restate all or a portion of its financial statement(s). The Committee may determine whether the Corporation  shall effect any such repayment or reduction : (i) by seeking repayment from the Grantee , (ii) by reducing (subject to applicable law and the terms and conditions of the Plan or any other applicable plan, program, or arrangement) the amount that would otherwise be awarded or payable to the Grantee  under the Award, the Plan or any other compensatory plan, program, or arrangement maintained by the Corporation , (iii) by withholding payment of future increases in compensation (including the payment of any discretionary bonus amount) or grants of compensatory awards that would otherwise have been made in accordance with the Corporation's  otherwise applicable compensation practices, or (iv) by any combination of the foregoing. The determination regarding the Grantee’s conduct, and repayment or reduction under this provision shall be within the sole discretion of the Committee and shall be final and binding on the Grantee  and the Corporation. The Grantee, in consideration of the grant of the Award, and by the Grantee's execution of this instrument, acknowledges the Grantee's understanding of and agreement to this provision, and hereby agrees to make and allow an immediate and complete repayment or reduction in accordance with this provision in the event of a call for repayment or other action by the Corporation or Committee to effect its terms with respect to the Grantee, the Award and/or any other compensation described herein.
 
11.   Stock Reserved .  The Corporation shall at all times during the term of the Award reserve and keep available such number of shares of its Common Stock as will be sufficient to satisfy the Award issued and granted to Grantee and the terms stated in this instrument, and shall pay all original issue taxes, if any, on the transfer of the Common Stock to the Grantee and all other fees and expenses necessarily incurred by the Corporation in connection therewith.
 
12.   Rights of Shareholder .  Except as otherwise provided in this instrument, the Grantee shall have no rights as a shareholder of the Corporation in respect of the Restricted Units or Common Stock for which the Award is granted; and the Grantee shall not be considered or
 

 
- 10 -

 

treated as a record owner of shares of Common Stock with respect to the Restricted Units until the Common Stock is issued to Grantee and no longer subject to any of the restrictions imposed under the Award indicated in this instrument, and Common Stock is actually issued and transferred to Grantee.
 
13.   Entire Agreement .  This instrument contains the entire terms of the Award, and may not be changed orally or other than by a written instrument issued and approved by the Corporation pursuant to the Plan.  This instrument supersedes any agreements or understandings that may have previously existed, and there are no other agreements or understandings, relating to its subject matter.
 
14.   Successors and Assigns .  The Award evidenced by this instrument shall inure to the benefit of and be binding upon the heirs, legatees, legal representatives, successors, and assigns of the parties hereto.
 
The Grantee hereby acknowledges receipt of this instrument, the Notice of Restricted Unit Award Agreement and a copy of the Plan, and accepts the Award under the terms and conditions stated in this instrument, subject to all terms and provisions of the Plan, by signing this instrument in duplicate originals, as of the date first stated above.
 
      
 
                                    
Date
 
«Officer_Name»
   
Grantee

 

 
- 11 -

 
 
 
Exhibit 12
 
 
                       
ONEOK, Inc.
Computation of Ratio of Earnings to Fixed Charges
                         
   
Years Ended December 31,
 
                         
(Unaudited)
 
2008
   
2007
 
2006
 
2005
 
2004
 
   
(Thousands of dollars)
 
                         
Fixed Charges, as defined
                       
Interest on long-term debt
  $ 254,765     $ 249,925   $ 233,152   $ 117,365   $ 79,318  
Other interest
    44,858       16,115     4,493     27,031     5,239  
Amortization of debt discount, premium
   and expense
    4,421       5,710     4,115     3,935     3,713  
Interest on lease agreements
    29,524       37,448     12,738     20,781     21,638  
Total Fixed Charges
    333,568       309,198     254,498     169,112     109,908  
Earnings before income taxes and undistributed
income of equity method investees
    771,239       681,169     747,950     647,308     314,714  
Earnings available for fixed charges
  $ 1,104,807     $ 990,367   $ 1,002,448   $ 816,420   $ 424,622  
Ratio of earnings to fixed charges
    3.31 x     3.20 x   3.94 x   4.83 x   3.86 x
                                   
                                   
For purposes of computing the ratio of earnings to fixed charges, "earnings" consists of income before cumulative effect of a change in accounting principle plus fixed charges, minority interests in income of consolidated subsidiaries, income taxes and distributed income of equity method investees, less capitalized interest and undistributed income of equity method investees. "Fixed charges" consists of interest expensed and capitalized, the amortization of debt discounts and issue costs and the representative interest portion of operating leases.
 
 
 
Exhibit 21
 

 
ONEOK, Inc.
 
 
SUBSIDIARIES OF THE COMPANY
 
 
Divisions
 
Oklahoma Natural Gas Company, a division of ONEOK, Inc.
Kansas Gas Service Company, a division of ONEOK, Inc.
Texas Gas Service Company, a division of ONEOK, Inc.
ONEOK Gas Transportation Company, a division of ONEOK, Inc.
 
 
State of
 
Incorporation
Subsidiaries
or Organization
 
Kansas Gas Marketing Company
Kansas
Mercado Gas Services Inc.
Delaware
ONEOK Partners GP, L.L.C.
Delaware
NBP Services, LLC
Delaware
Northern Border Pipeline Corporation
Delaware
ONEOK NB Company
Delaware
Oklahoma Natural Energy Services Company
Oklahoma
ONEOK Bushton Processing, Inc.
Delaware
ONEOK Energy Marketing Company
Oklahoma
ONEOK Energy Services Canada, Ltd.
Canada
ONEOK Energy Services Company, II
Delaware
ONEOK Energy Services Company, L.P.
Texas
ONEOK Energy Services Holdings, L.L.C.
Oklahoma
ONEOK Field Services Holdings, L.L.C.
Oklahoma
ONEOK Kansas Company
Kansas
ONEOK Kansas Properties, L.L.C.
Kansas
ONEOK Leasing Company
Delaware
ONEOK Parking Company, L.L.C.
Delaware
ONEOK Propane Company
Delaware
ONEOK Services Company
Oklahoma
ONEOK Texas Resources, Inc.
Delaware
ONEOK PB Company, L.L.C.
Delaware
ONEOK Partners, L.P. (45.7%)
Delaware
   
Subsidiaries of ONEOK Partners, L.P.
 
   
ONEOK Partners Intermediate Limited Partnership
Delaware
ONEOK ILP GP, L.L.C.
Delaware
Bear Paw Investments, LLC
Delaware
Bear Paw Energy, LLC
Delaware

 
 

 
 
Bear Paw Processing Company (Canada), Ltd.
Alberta
Brown Bear Enterprises, LLC
Delaware
Border Minnesota Pipeline, LLC
Delaware
Black Mesa Holdings, Inc.
Delaware
Black Mesa Pipeline, Inc.
Delaware
Black Mesa Pipeline Operations, L.L.C.
Delaware
Black Mesa Technologies, Inc.
Oklahoma
Black Mesa Technologies Services, LLC (60%)
Oklahoma
Border Midstream Services, Ltd.
Alberta
Border Midwestern Company
Delaware
Midwestern Gas Marketing Company
Delaware
Midwestern Gas Transmission Company
Delaware
Border Viking Company
Delaware
Viking Gas Transmission Company
Delaware
Crestone Energy Ventures, L.L.C.
Delaware
Crestone Bighorn, L.L.C.
Delaware
Crestone Gathering Services, L.L.C.
Delaware
Crestone Powder River, L.L.C.
Delaware
Crestone Wind River, L.L.C.
Delaware
Northern Border Pipeline Company (general partnership) (50%)
Texas
China Pipeline Holdings Ltd. (0.81%)
Cayman Islands
Guardian Pipeline, L.L.C.
Delaware
Bighorn Gas Gathering, L.L.C. (49.0%)
Delaware
Fort Union Gas Gathering, L.L.C. (37.04%)
Delaware
Lost Creek Gathering Company, L.L.C. (35%)
Delaware
Chisholm Pipeline Company (50%)
Delaware
Chisholm Pipeline Holdings, L.L.C.
Delaware
Mid Continent Market Center, L.L.C.
Kansas
OkTex Pipeline Company, L.L.C.
Delaware
ONEOK Arbuckle Pipeline, L.L.C.
Delaware
ONEOK Arbuckle Land Company
Texas
ONEOK Field Services Company, L.L.C.
Oklahoma
ONEOK Gas Gathering, L.L.C.
Oklahoma
ONEOK Gas Storage Holdings, L.L.C.
Delaware
ONEOK Gas Storage, L.L.C.
Oklahoma
ONEOK Gas Transportation, L.L.C.
Oklahoma
ONEOK Hydrocarbon, L.L.C.
Delaware
ONEOK Hydrocarbon, L.P.
Delaware
ONEOK Hydrocarbon GP, L.L.C.
Delaware
ONEOK Hydrocarbon Holdings, L.L.C.
Delaware
ONEOK Hydrocarbon Southwest, L.L.C.
Delaware
ONEOK MB I, L.P.
Delaware
ONEOK Midstream Gas Supply, L.L.C.
Oklahoma
ONEOK Mont Belvieu Storage Company, L.L.C.
Delaware
ONEOK NGL Pipeline, L.L.C.
Delaware
ONEOK NGL Gathering, L.L.C.
Delaware


 
- 2 -

 

ONEOK North System, L.L.C.
Delaware
ONEOK Overland Pass Holdings, L.L.C.
Oklahoma
ONEOK Pipeline Holdings, L.L.C.
Delaware
ONEOK Texas Gas Storage, L.L.C.
Texas
ONEOK Transmission Company, L.L.C.
Delaware
ONEOK Underground Storage Company, L.L.C.
Kansas
ONEOK VESCO Holdings, L.L.C.
Delaware
ONEOK WesTex Transmission, L.L.C.
Delaware
Overland Pass Pipeline Company LLC
Delaware
Potato Hills Gas Gathering System (joint venture) (51%)
Oklahoma
Sycamore Gas System (general partnership) (48.445%)
Oklahoma
Venice Energy Services Company, L.L.C. (10.1765%)
Delaware
Mont Belvieu I Fractionation Facility (joint venture)(80%)
Texas
Heartland Pipeline Company (general partnership) (50%)
Texas

 
- 3 -


 
 
Exhibit 23.1
 
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM


We hereby consent to the incorporation by reference in the Registration Statements on Form S-3 (Nos. 333-155592 and 333-155593) and Form S-8 (Nos. 333-152748, 333-41263, 333-41265, 333-41267, 333-42094, 333-95039, 333-130070, 333-130067, 333-140629, 333-75768 and 333-121769) of ONEOK, Inc. of our report dated February 24, 2009 relating to the consolidated financial statements and the effectiveness of internal control over financial reporting, which appears in this Form 10-K.


/s/ PricewaterhouseCoopers LLP

Tulsa, Oklahoma
February 24, 2009
 
 
 
Exhibit 23.2

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM



The Board of Directors
ONEOK Inc.
 

 
We consent to the incorporation by reference in registration statements (Nos. 333-152748, 333-75768, 333-41263, 333-41265, 333-41267, 333-42094, 333-95039, 333-121769, 333-130070, 333-130067 and 333-140629) on Form S-8 and (Nos. 333-155593 and 333-155592) on Form S-3 of ONEOK, Inc. of our report dated February 28, 2007, with respect to the consolidated statements of income, shareholders’ equity and comprehensive income, and cash flows for the year ended December 31, 2006 of ONEOK, Inc. and subsidiaries, which report appears in the December 31, 2008, annual report on Form 10-K of ONEOK, Inc. Our report refers to a change in accounting for defined benefit pension and other postretirement plans, the consolidation of limited partnerships or similar entities when limited partners have certain rights, and stock based compensation expense in 2006.
 
/s/ KPMG LLP
 
February 24, 2009
Tulsa, OK
 
 
Exhibit 31.1


Certification

I, John W. Gibson, certify that:

I have reviewed this annual report on Form 10-K of ONEOK, Inc.;

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;

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;

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

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: February 24, 2009

/s/ John W. Gibson                                            
John W. Gibson
Chief Executive Officer
 
 
Exhibit 31.2


Certification

I, Curtis L. Dinan, certify that:

I have reviewed this annual report on Form 10-K of ONEOK, Inc.;

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;

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;

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

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: February 24, 2009

/s/ Curtis L. Dinan                                            
Curtis L. Dinan
Chief Financial Officer
 
Exhibit 32.1
 
 
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of ONEOK, Inc. (the “Company”) for the period ending December 31, 2008 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John W. Gibson, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)           the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)           the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ John W. Gibson
John W. Gibson
Chief Executive Officer

February 24, 2009


A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ONEOK, Inc. and will be retained by ONEOK, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.
 
Exhibit 32.2
 
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of ONEOK, Inc. (the “Company”) for the period ending December 31, 2008 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Curtis L. Dinan, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1)           the Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)           the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


/s/ Curtis L. Dinan
Curtis L. Dinan
Chief Financial Officer

February 24, 2009



A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to ONEOK, Inc. and will be retained by ONEOK, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.