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.
|