| 
 
	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)
 
 | 
| 
 
	Common
	stock, par value of $0.01
 
 | 
 
	New
	York Stock Exchange
 
 | 
| 
 
	(Title
	of Each Class)
 
 | 
 
	(Name
	of Each Exchange on which
	Registered)
 
 | 
| 
 | 
 
	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
 
 | 
| 
 | 
 
	TC
	PipeLines
 
 | 
 
	TC
	PipeLines Intermediate Limited Partnership, a subsidiary of TC
 
	   
	 PipeLines,
	LP
 
 | 
| 
 | 
 
	TransCanada
 
 | 
 
	TransCanada
	Corporation
 
 | 
| 
 
	·  
 
 | 
 
	ONEOK
	Partners
 
 | 
| 
 
	·  
 
 | 
 
	Distribution
 
 | 
| 
 
	·  
 
 | 
 
	Energy
	Services
 
 | 
| 
 
	·  
 
 | 
 
	Other
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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.
 
 | 
|||||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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
 
 | 
||
| 
 
	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
 
 | 
||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	ITEM
	4.
 
 | 
 
	SUBMISSION
	OF MATTERS TO A VOTE OF SECURITY
	HOLDERS
 
 | 
| 
 
	ITEM
	5.
 
 | 
 
	MARKET
	FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER
	MATTERS AND ISSUER PURCHASES OF EQUITY
	SECURITIES
 
 | 
| 
 
	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 | ||||||||
| 
 
	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.
 
 | 
|||||||
| 
 
	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.
 
 | 
|||||||||||||||
| 
 
	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.
 
 | 
||||||||||||||||||||||||
| 
 
	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 | ||||||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	earnings
	per share;
 
 | 
| 
 
	·  
 
 | 
 
	return
	on invested capital; and
 
 | 
| 
 
	·  
 
 | 
 
	shareholder
	appreciation.
 
 | 
| 
 
	·  
 
 | 
 
	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.”
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| (Thousands of dollars) | |||||||||
| 
 
	ONEOK
	Partners
 
 | 
$ | 433,537 | |||||||
| 
 
	Distribution
 
 | 
157,953 | ||||||||
| 
 
	Energy
	Services
 
 | 
10,255 | ||||||||
| 
 
	Other
 
 | 
1,099 | ||||||||
| 
 
	Total
	goodwill
 
 | 
$ | 602,844 | |||||||
| 
 
	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 | ) | |||||
| 
 
	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.
 
 | 
|||||||||||||||||||||
| 
 
	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.
 
 | 
|||||||||||||||||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | % | |||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | |||||||||
| 
 
	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 | % | ||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | |||||||||
| 
 
	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 | ||||||
| 
 
	Years
	Ended December 31,
 
 | 
|||||
| 
 
	2008
 
 | 
 
	2007
 
 | 
||||
| 
 
	Long-term
	debt
 
 | 
 
	67%
 
 | 
 
	70%
 
 | 
|||
| 
 
	Equity
 
 | 
 
	33%
 
 | 
 
	30%
 
 | 
|||
| 
 
	Debt
	(including notes payable)
 
 | 
 
	76%
 
 | 
 
	71%
 
 | 
|||
| 
 
	Equity
 
 | 
 
	24%
 
 | 
 
	29%
 
 | 
|||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	2009
	Projected Capital Expenditures
 
 | 
|||||||
| (Millions of dollars) | |||||||
| 
 
	ONEOK
	Partners
 
 | 
$ | 425 | |||||
| 
 
	Distribution
 
 | 
137 | ||||||
| 
 
	Energy
	Services
 
 | 
- | ||||||
| 
 
	Other
 
 | 
19 | ||||||
| 
 
	Total
	projected capital expenditures
 
 | 
$ | 581 | |||||
| 
 
	ONEOK
 
 | 
 
	ONEOK
	Partners
 
 | 
||||||||
| 
 
	Rating
	Agency
 
 | 
 
	Rating
 
 | 
 
	Outlook
 
 | 
 
	Rating
 
 | 
 
	Outlook
 
 | 
|||||
| 
 
	Moody's
 
 | 
 
	Baa2
 
 | 
 
	Stable
 
 | 
 
	Baa2
 
 | 
 
	Stable
 
 | 
|||||
| 
 
	S&P
 
 | 
 
	BBB
 
 | 
 
	Stable
 
 | 
 
	BBB
 
 | 
 
	Stable
 
 | 
|||||
| 
 
	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 | ||||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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.
 
 | 
|||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | ||||
| 
 
	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
	Partners
 
 | 
| 
 
	·  
 
 | 
 
	Distribution
 
 | 
| 
 
	·  
 
 | 
 
	Energy
	Services
 
 | 
| 
 
	·  
 
 | 
 
	Other
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | ||||
| 
 
	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 | % | ||||||
| 
 
	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 | ||||
| 
 
	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.
 
 | 
||||||||||||||||||||
| 
 
	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.
 
 | 
||||||||||||||||
| 
 
	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.
 
 | 
||||||||||||
| 
 
	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 | ||||||
| 
 
	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 | ||||
| 
 
	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 | |||||
| 
 
	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 | ) | |||
| 
 
	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)
 
 | 
||||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | ||||
| 
 
	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
 
 | 
||||
| 
 
	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 | ) | ||||
| 
 
	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 | ||||||
| 
 
	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 | |||
| 
 
	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 | ) | ||||
| 
 
	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 | ||||
| 
 
	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%
 
 | 
||||||
| 
 
	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%
 
 | 
||||||
| 
 
	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
 
 | 
|||
| 
 
	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 | ) | |||
| 
 
	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
 
 | 
||||||||||||||||
| 
 
	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 | % | 
| 
 
	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
 
 | 
|||
| 
 
	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
 
 | 
||
| 
 
	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 | ||||||
| 
 
	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 | ||||||
| 
 
	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 | ||||
| 
 
	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 | |||||
| 
 
	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
 
 | 
$ | - | |||||||||
| 
 
	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 | ||||||
| 
 
	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
 
 | 
- | $ | - | |||||
| 
 
	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 | ||||||
| 
 
	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.
 
 | 
||||||||||||||
| 
 
	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 | ||||||
| 
 
	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 | |||||||
| 
 
	·  
 
 | 
 
	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.
 
 | 
| 
 
	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 | ||||||
| 
 
	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 | ||||||
| 
 
	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
	10.
 
 | 
 
	   
	DIRECTORS
	, EXECUTIVE OFFICERS AND CORPORATE
	GOVERNANCE
 
 | 
| 
 
	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
 
 | 
| 
 
	(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
 
 | 
| 
 | 
 
	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.
 
 | 
| 
 | 
 
	4.21
 
 | 
 
	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)).
 
 | 
| 
 
	/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
 
 | 
| 
 
	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
 
 | 
| 
 
	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%
 
 | 
| 
 
	Retirement
	Age
 
 | 
 
	Benefit
	Factor
 
	Percentage
 
 | 
| 
 
	62
 
	63
 
	64
 
	65
	& over
 
 | 
 
	60%
 
	60%
 
	60%
 
	60%
 
 | 
| 
 
	Part
	B Participant
 
	Age
	At Commencement
 
 | 
 
	Early
	Commencement Reduced
 
	Payout
	Percentage Factor
 
 | 
| 
 
	Under
	50
 
	50
 
	51
 
 | 
 
	0
 
	50%
 
	55%
 
 | 
| 
 
	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%
 
 | 
| 
 | 
 
	ADOPTION OF PLAN BY
	SUBSIDIARY,
 
 | 
| 
 | 
 
	AFFILIATED OR
	ASSOCIATED COMPANIES
 
 | 
| 
 
	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
 
 | 
| 
 
	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
 
 | 
| 
 
	EXHIBIT
	A
 
 | 
 
	34
 
 | 
| 
 
	EXHIBIT
	B
 
 | 
 
	35
 
 | 
| 
 
	EXHIBIT
	C
 
 | 
 
	36
 
 | 
| 
 
	EXHIBIT
	D
 
 | 
 
	38
 
 | 
| 
 
	1.1  
 
 | 
 
	Statement of Purpose;
	Effective Date
 
 | 
| 
 
	2.1  
 
 | 
 
	Definitions
 
 | 
| 
 
	3.1
 
 | 
 
	Eligibility
 
 | 
| 
 
	(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;
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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
 
 | 
| 
 | 
 
	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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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
 
 | 
| 
 
	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.
 
 | 
| 
 
	(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;
 
 | 
| 
 
	(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
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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
 
 | 
| 
 | 
 
	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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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
 
 | 
| 
 | 
 
	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.
 
 | 
| 
 
	(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.
 
 | 
| 
 
	(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.
 
 | 
| 
 | 
 | 
| 
 
	Re:
 
 | 
 
	Section
	3.1 – Eligible Employees
 
 | 
| 
 | 
 
	Effective
	Date:  December 18, 2008
 
 | 
| 
 | 
 | 
| 
 
	Re:
 
 | 
 
	Section
	4.1 – Amount of Deferral
 
 | 
| 
 | 
 
	Effective
	Date: December 18, 2008
 
 | 
| 
 
	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%
 
 | 
|
| 
 | 
 | 
| 
 
	Re:
 
 | 
 
	Section
	2.1 – Investment Return
 
 | 
| 
 | 
 
	Date:
	December 18, 2008
 
 | 
| 
 
	A.  
 
 | 
 
	Long-Term
	Deferrals
 
 | 
| 
 
	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.
 
 | 
| 
 
	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
 
 | 
| 
 | 
| 
 
	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.
 
 | 
| 
 
	1.  
 
 | 
 
	General
 
 | 
| 
 
	2.  
 
 | 
 
	Definitions
 
 | 
| 
 
	3.  
 
 | 
 
	Grants
	of Stock Incentives
 
 | 
| 
 
	4.  
 
 | 
 
	Stock
	Subject to the Plan
 
 | 
| 
 
	5.  
 
 | 
 
	Eligibility
 
 | 
| 
 
	6.  
 
 | 
 
	Stock
	Bonus Awards, Performance Stock Awards, Performance Unit Awards,
	Restricted Stock Awards and Restricted Unit
	Awards
 
 | 
| 
 
	7.  
 
 | 
 
	Options
 
 | 
| 
 
	8.  
 
 | 
 
	Stock
	Appreciation Rights
 
 | 
| 
 
	9.  
 
 | 
 
	Director
	Stock Awards
 
 | 
| 
 
	10.  
 
 | 
 
	Deferred
	Compensation Program
 
 | 
| 
 
	11.  
 
 | 
 
	Compliance
	With Section 409A
 
 | 
| 
 
	12.  
 
 | 
 
	Certain
	Change in Control, Termination of Employment and Disability
	Provisions
 
 | 
| 
 
	13.  
 
 | 
 
	Adjustment
	Provisions
 
 | 
| 
 
	14.  
 
 | 
 
	Administration
 
 | 
| 
 
	15.  
 
 | 
 
	General
	Provisions
 
 | 
| 
 
	16.  
 
 | 
 
	Plan
	Amendment and Termination
 
 | 
| 
 | 
 
	(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,
 
 | 
| 
 
	Date
 
 | 
 
	«Officer_Name»
 
 | 
|
| 
 
	Grantee
 
 | 
| 
 
	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%
 
 | 
| 
 
	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.]
 
 | 
| 
 
	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
 
 | 
||||
| 
 
	(i)  
 
 | 
 
	Separation
	from Service of the Grantee,
 
 | 
| 
 
	(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.
 
 | 
| 
 
	Date
 
 | 
 
	«Officer_Name»
 
 | 
|
| 
 
	Grantee
 
 | 
| 
 | 
|||||||||||||||||
| 
 
	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.
 
 | 
|||||||||||||||||
| 
 
	State
	of
 
 | 
|
| 
 
	Incorporation
 
 | 
|
| 
 
	Subsidiaries
 
 | 
 
	or
	Organization
 
 | 
| 
 
	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
 
 | 
| 
 
	February 24,
	2009
 
 | 
| 
 
	Tulsa,
	OK
 
 | 
| 
 
	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
 
 | 
| 
 
	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.
 
 | 
| 
 
	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
 
 | 
| 
 
	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.
 
 |