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ONEOK Partners’ Third-Quarter 2008 Results More Than Double; Raises 2008 Earnings Guidance

November 5, 2008

TULSA, Okla., Nov. 5 /PRNewswire-FirstCall/ — ONEOK Partners, L.P. today announced that its third-quarter 2008 net income more than doubled to $203.9 million, or $1.97 per unit, compared with net income of $95.9 million, or 98 cents per unit, for the third quarter 2007.

For the nine-month period ended Sept. 30, 2008, ONEOK Partners reported a 76 percent increase in net income to $503.4 million, or $4.93 per unit, compared with $286.3 million, or $2.94 per unit, for the same period in 2007.

The partnership also raised its 2008 net income guidance to the range of $5.95 to $6.15 per unit, reflecting stronger performance in the natural gas liquids gathering and fractionation segment primarily as a result of wider natural gas liquids (NGL) product price differentials. Distributable cash flow is now expected to be in the range of $625 million to $655 million.

ONEOK Partners’ previous net income guidance was estimated to be in the range of $5.20 to $5.60 per unit, with distributable cash flow in the range of $585 million to $625 million. Additional information is available in Exhibits A and B.

“We had exceptional third-quarter performance across all of our business segments. Our natural gas liquids businesses benefited from increased NGL volumes and wider NGL product price differentials, and our natural gas gathering and processing segment experienced higher commodity prices and volumes,” said John W. Gibson, chairman and chief executive officer of ONEOK Partners.

“Also, natural gas liquids began flowing through the Overland Pass Pipeline, the largest pipeline construction project undertaken in our company’s history. Hundreds of employees and contractors worked together to construct this pipeline, and we’re extremely proud and appreciative of their accomplishments.”

Cash flow, as measured by earnings before interest, taxes, depreciation and amortization (EBITDA), rose 61 percent to $252.6 million in the third quarter 2008, compared with $156.9 million in the third quarter 2007. Distributable cash flow (DCF) in the third quarter 2008 was $191.0 million, or $1.85 per unit, compared with $107.1 million, or $1.11 per unit, in the third quarter 2007.

Year-to-date 2008 EBITDA rose 43 percent to $672.8 million, compared with $470.6 million in the same period last year. DCF for the nine months 2008 increased to $526.7 million, or $5.23 per unit, compared with $346.0 million, or $3.66 per unit, in the same period last year.

Operating income for the third quarter 2008 was $197.5 million, compared with $105.1 million for the third quarter 2007. For the nine months 2008, operating income increased to $511.8 million, compared with $317.1 million in the same period last year.

The partnership’s operating income increase in both the three- and nine-month 2008 periods reflected wider NGL product price differentials and increased volumes in the natural gas liquids gathering and fractionation segment, and higher realized commodity prices and increased volumes in the natural gas gathering and processing segment. In addition, the natural gas liquids pipelines segment earned incremental income from the North System, an interstate natural gas liquids and refined petroleum products pipeline system that was acquired in October 2007.

“We realized higher margins in the favorable commodity price environment in the first nine months of 2008. In the fourth quarter, we are experiencing a return to more normal NGL product price differentials and commodity prices,” Gibson added.

Operating costs were $97.5 million in the third quarter 2008, compared with $80.1 million in the same period last year. For the nine months 2008, operating costs were $272.7 million, compared with $237.4 million in the same period last year. The operating cost increases for both the three- and nine-month periods were primarily due to incremental expenses associated with the acquisition of the North System, as well as increases in employee-related and general operating costs.

Equity earnings from investments were $29.4 million in the third quarter 2008, compared with $22.2 million in the same period last year. For the nine months 2008, equity earnings from investments were $74.8 million, compared with $65.0 million in the same period last year. The equity earnings from investment increases for both the three- and nine-month periods were primarily due to a gain on the sale of Bison Pipeline LLC by Northern Border Pipeline and higher gathering revenues in various investments, partially offset by lower throughput at Northern Border Pipeline. ONEOK Partners owns a 50 percent interest in Northern Border Pipeline.

In response to uncertainties in the capital markets, ONEOK Partners took proactive measures during October to increase available cash by drawing down its revolving credit facility to provide funding for its growth projects.

At Oct. 31, 2008, the partnership had $870 million outstanding and $130 million available under its revolving credit facility and approximately $396 million in available cash and cash equivalents. These additional funds and remaining borrowing capacity, as well as operating cash flow, will fund the partnership’s capital requirements for the remainder of 2008 and well into 2009.

“Our financial strength and flexibility have enabled us to fund our growth, despite today’s challenging financial markets. Our investment-grade credit rating, well-capitalized balance sheet, strong distribution coverage ratio and stable cash flows position the partnership for continued growth,” Gibson added.

   THIRD-QUARTER 2008 SUMMARY INCLUDED:    --  Operating income of $197.5 million, compared with $105.1 million in       the third quarter 2007;   --  Natural gas gathering and processing segment operating income of $63.5       million, compared with $44.6 million in the third quarter 2007;   --  Natural gas pipelines segment operating income of $33.3 million,       compared with $28.1 million in the third quarter 2007;   --  Natural gas liquids gathering and fractionation segment operating       income of $89.8 million, compared with $24.6 million in the third       quarter 2007;   --  Natural gas liquids pipelines segment operating income of $11.4       million, compared with $9.3 million in the third quarter 2007;   --  Equity earnings from investments of $29.4 million, compared with $22.2       million in the third quarter 2007;   --  Capital expenditures of $335.6 million, compared with $202.0 million       in the third quarter 2007, increasing as a result of internally       generated growth projects;   --  Announcing the D-J Basin Lateral Pipeline project to connect       additional NGL supplies to the Overland Pass Pipeline;   --  Commissioning the Overland Pass Pipeline that transports       unfractionated NGLs from the Rockies to the Mid-Continent;   --  Completing the NGL pipeline extension into the Woodford Shale, and       beginning construction of the previously announced Arbuckle Pipeline;       and   --  Declaring a quarterly distribution of $1.08 per unit, marking the 11th       consecutive quarter to raise the distribution.     THIRD-QUARTER AND YEAR-TO-DATE 2008 BUSINESS UNIT RESULTS    Natural Gas Gathering and Processing Segment  

The natural gas gathering and processing segment’s operating income for the third quarter 2008 was $63.5 million, compared with $44.6 million for the third quarter 2007.

Third-quarter 2008 operating income increased $18.3 million from higher realized commodity prices, $3.4 million from improved contract terms and $2.3 million from higher volumes sold and processed. Operating costs for the segment were $35.7 million, compared with $31.8 million in the third quarter 2007, increasing primarily as a result of higher employee-related costs and higher costs for chemicals and maintenance materials.

Operating income for the nine-month 2008 period increased to $198.8 million, compared with $121.3 million in the same period in 2007. The increase was due to $66.2 million from higher realized commodity prices, $11.5 million from higher volumes sold and processed, and $9.7 million from improved contract terms. Nine-month 2008 operating costs for the segment were $101.5 million, compared with $96.4 million in the 2007 nine-month period, increasing primarily as a result of higher employee-related costs and higher costs for chemicals and maintenance materials.

Three- and nine-month 2008 results were approximately $1.8 million lower due to operational disruptions as a result of Hurricane Ike.

The following table contains margin information for the periods indicated. NGL shrink, plant fuel and condensate shrink refer to the Btus that are removed from natural gas through the gathering and processing operation.

                                    Three Months Ended    Nine Months Ended                                       September 30,         September 30,                                      2008       2007       2008       2007   Percent of proceeds     Wellhead purchases (MMBtu/d)    65,804     76,841     68,564     86,361     NGL sales (Bbl/d)                5,948      5,680      6,053      5,911     Residue sales (MMBtu/d)         42,119     34,691     38,570     32,252     Condensate sales (Bbl/d)           709        681        964        695     Percentage of total net margin     64%        53%        62%        56%   Fee-based     Wellhead volumes (MMBtu/d)   1,145,656  1,170,030  1,173,894  1,168,360     Average rate ($/MMBtu)           $0.27      $0.26      $0.26      $0.26     Percentage of total net margin     22%        32%        23%        32%   Keep-whole     NGL shrink (MMBtu/d)            20,016     22,056     21,978     23,555     Plant fuel (MMBtu/d)             2,106      2,605      2,301      2,785     Condensate shrink (MMBtu/d)      1,574      1,733      1,941      2,299     Condensate sales (Bbl/d)           318        351        393        465     Percentage of total net margin     14%        15%        15%        12%     

The natural gas gathering and processing segment is exposed to commodity price risk, primarily NGLs, as a result of receiving commodities in exchange for its services. The following table provides hedging information for the remainder of 2008 and for 2009:

                                               Three Months Ending                                                December 31, 2008                                        Volumes     Average       Percentage                                        Hedged       Price         Hedged   Natural gas liquids (Bbl/d) (a)       8,496   $1.30 / gallon       64%   Condensate (Bbl/d) (a)                  773   $2.14 / gallon       53%   Total liquid sales (Bbl/d)            9,269   $1.37 / gallon       63%    Natural gas (MMBtu/d) (a)             5,000   $9.61 / MMBtu        56%   (a) - Hedged with fixed-price swaps.                                                    Year Ending                                                December 31, 2009                                        Volumes     Average      Percentage                                        Hedged      Price          Hedged   Natural gas liquids (Bbl/d) (a)       2,185   $2.08 / gallon       19%   Condensate (Bbl/d) (a)                  666   $3.23 / gallon       30%   Total liquid sales (Bbl/d)            2,851   $2.35 / gallon       21%   (a) - Hedged with fixed-price swaps.     

The partnership currently estimates that a 1 cent per gallon increase in the composite price of natural gas liquids would increase annual net margin by approximately $1.5 million. A $1.00 per barrel increase in the price of crude oil would increase annual net margin by approximately $0.9 million. Also, a 10 cent per MMBtu increase in the price of natural gas would increase annual net margin by approximately $0.4 million. All of these sensitivities exclude the effects of hedging and assume normal operating conditions.

Natural Gas Pipelines Segment

The natural gas pipelines segment reported third-quarter 2008 operating income of $33.3 million, compared with $28.1 million for the third quarter 2007.

Increased operating income during the quarter reflects $3.4 million of improved transportation margins, as a result of the higher natural gas price impact on retained fuel. Operating costs of $23.9 million remained relatively flat, compared with the same period in 2007.

Operating income for the nine months increased to $102.7 million, compared with $85.6 million in the same period in 2007.

Nine-month 2008 results reflect an $8.5 million increase in transportation margins, primarily as a result of the higher natural gas price impact on retained fuel, and a $4.7 million increase in storage margins as a result of new and renegotiated contracts as well as the higher natural gas price impact on retained fuel. Operating costs for the segment were $67.9 million in the nine-month 2008 period, compared with $70.0 million in the same period last year, down primarily due to lower general taxes and general operating costs.

Third-quarter 2008 equity earnings from investments were $20.2 million, compared with $16.5 million in the third quarter 2007. Nine-month 2008 equity earnings from investments were $49.4 million, compared with $45.3 million in 2007. The increases were primarily due to ONEOK Partners’ share, or $8.3 million, of a third-quarter 2008 gain on the sale of Bison Pipeline LLC by Northern Border Pipeline, in which the partnership has a 50 percent equity interest, partially offset by lower throughput on Northern Border Pipeline.

Natural Gas Liquids Gathering and Fractionation Segment

The natural gas liquids gathering and fractionation segment reported operating income for the third quarter 2008 of $89.8 million, compared with $24.6 million for the third quarter 2007.

During the third quarter 2008, operating income increased $43.7 million as a result of significantly wider regional NGL product price differentials between the market centers in Conway, Kan., and Mont Belvieu, Texas; $13.3 million in operational measurement gains, primarily at NGL storage caverns; $12.5 million due to increased volumes from new supply connections and increased fractionation volumes; and $3.3 million from higher isomerization volumes, driven by wider price differentials between isobutane and normal butane.

Operating costs were $23.0 million in the third quarter 2008, compared with $17.8 million in the second quarter 2007, increasing primarily due to costs associated with the startup of the recently expanded fractionator in Bushton, Kan., higher employee-related costs and higher operating expenses at fractionation facilities due to increased utilization.

Operating income for the nine months 2008 doubled to $176.8 million, compared with $88.4 million in the same period last year.

Nine-month 2008 results reflect a $59.3 million increase from significantly wider regional NGL product price differentials between the market centers in Conway and Mont Belvieu; a $31.8 million increase due to increased volumes from new supply connections and increased fractionation volumes; $11.4 million in operational measurement gains, primarily at NGL storage caverns; and $2.5 million from higher storage margins.

Nine-month 2008 operating costs for the segment were $61.6 million, compared with $49.4 million in the same period last year. The increase resulted from higher costs associated with the startup of the recently expanded Bushton fractionator, higher employee-related costs and higher operating expenses at fractionation facilities due to increased utilization.

Three- and nine-month 2008 results were approximately $3.8 million lower due to operational disruptions as a result of Hurricane Ike.

The Conway-to-Mont Belvieu average price differential in the third quarter 2008 for ethane, based on Oil Price Information Service (OPIS) pricing, increased significantly to 24 cents per gallon, compared with 5 cents per gallon in the same period last year. For the nine-month 2008 period, the average price differential was 15 cents per gallon, compared with 5 cents per gallon in the same period 2007. The prior three-year average Conway-to-Mont Belvieu average price differential for ethane was 5 cents per gallon.

Natural Gas Liquids Pipelines Segment

The natural gas liquids pipelines segment reported operating income of $11.4 million, compared with $9.3 million for the third quarter 2007.

Third-quarter 2008 operating income improved, compared with the same period last year, primarily due to $12.0 million from incremental margins on the acquired North System. Operating costs for the segment increased $9.3 million in the third quarter 2008, compared with the third quarter 2007, primarily due to incremental expenses associated with operating the North System, as well as higher employee-related costs and costs associated with the startup of Overland Pass Pipeline operations.

Operating income for the nine-month 2008 period increased to $35.1 million, compared with $26.4 million during the same period in 2007.

Nine-month 2008 results improved, compared with the same period last year, primarily from $34.0 million of incremental margins from the North System and $2.5 million from increased throughput due to new NGL supply connections, as well as increased NGL production from existing supply connections. Operating costs for the segment were $42.2 million in the nine months ended Sept. 30, 2008, compared with $16.6 million in the same period last year, increasing primarily due to incremental expenses associated with operating the North System. Costs related to the startup of the Overland Pass Pipeline, higher employee-related costs and higher outside service expenses also contributed to the increase in operating costs.

Three- and nine-month 2008 results were approximately $2.2 million lower due to operational disruptions as a result of Hurricane Ike.

GROWTH ACTIVITIES

In the third quarter 2008, the partnership continued executing approximately $2 billion of internally generated growth projects that are expected to be completed in 2008 and 2009.

Natural Gas Liquids Projects

The natural gas liquids projects account for approximately $1.4 billion of the current growth projects.

In September, the partnership announced plans to construct a 125-mile natural gas liquids pipeline lateral from the Denver-Julesburg Basin in northeastern Colorado to the Overland Pass Pipeline. The pipeline is estimated to cost between $70 million and $80 million and is designed with the capacity to transport as much as 55,000 bpd of unfractionated NGLs. Supply commitments from producers are in place for approximately 33,000 bpd of unfractionated NGLs, with a potential for an additional 10,000 bpd of supply from new drilling and plant upgrades in the next two years. The pipeline is currently expected to be partially in-service in the fourth quarter of 2008, with completion expected in the first quarter of 2009.

Also in September, the partnership placed into service a 78-mile NGL pipeline extension of its Oklahoma gathering system in the Woodford Shale in southeast Oklahoma. The pipeline connects two natural gas processing plants that have the ability to produce approximately 25,000 bpd of natural gas liquids. The pipeline extension is estimated to cost approximately $36 million.

In early October, natural gas liquids began flowing into the Overland Pass Pipeline from Echo Springs, Wyo., to the Mid-Continent region at a rate of approximately 30,000 bpd. The 760-mile natural gas liquids pipeline extending from Opal, Wyo., to Conway, Kan., is estimated to cost in the range of $575 million to $590 million, as previously stated. Overland Pass is designed to transport approximately 110,000 bpd of NGLs, and capacity can be increased to 255,000 bpd with additional pump facilities. The remaining portion of the pipeline, from Opal to Echo Springs, is substantially complete and scheduled for startup during the fourth quarter 2008.

As part of a long-term agreement, The Williams Companies, Inc. dedicated its NGL production of approximately 60,000 bpd from two of its natural gas processing plants in Wyoming to the Overland Pass Pipeline. In addition, agreements have been reached for supply commitments of up to an additional 80,000 bpd, and additional agreements are being negotiated with other producers for supply commitments that could add another 60,000 bpd of NGL supply to this pipeline within the next three to five years.

In conjunction with Overland Pass, the partnership also completed much of the construction on $230 million to $240 million of projects that increase existing NGL fractionation and distribution pipeline capacity.

The $110 million to $140 million, 150-mile lateral pipeline connecting the Piceance Basin with Overland Pass Pipeline is currently expected to be in service during the third quarter of 2009. The startup date was revised to the third quarter from the second quarter 2009 due to a delay in receiving a construction permit from the federal Bureau of Land Management, which has since been received.

The $340 million to $360 million, 440-mile Arbuckle Pipeline, extending from southern Oklahoma through the Barnett Shale of North Texas and on to the partnership’s fractionation and storage facilities at Mont Belvieu on the Texas Gulf Coast, is currently under construction and expected to go into service during the first quarter of 2009. The pipeline will have the capacity to transport 160,000 bpd of unfractionated natural gas liquids, expandable to 210,000 bpd with additional pump facilities. Supply commitments from producers are in place for 65,000 bpd, and there are indications of interest from other producers that could add another 145,000 bpd of supply within the next three to five years. These additional supply commitments are in various stages of negotiation.

Natural Gas Projects

In July 2008, the Fort Union Gas Gathering expansion project was completed. The project doubled the natural gas gathering pipeline capacity of Fort Union Gas Gathering by adding approximately 150 miles of new gathering lines and approximately 650 million cubic feet per day of additional capacity. ONEOK Partners owns approximately 37 percent of Fort Union Gas Gathering, L.L.C.

Construction is under way on the $277 million to $305 million, 119-mile Guardian expansion and extension project, which is currently targeted to be in service in the fourth quarter of 2008. The capacity on the pipeline extension is fully subscribed under 15-year agreements.

The expansion of the partnership’s Grasslands natural gas processing facility in the highly active Williston Basin will increase the plant’s processing capacity by nearly 60 percent and its fractionation capacity by 50 percent. The project is currently estimated to cost $40 million to $45 million and is currently expected to come on line in the fourth quarter of 2008.

CONFERENCE CALL AND WEBCAST

ONEOK Partners and ONEOK management will conduct a joint conference call on Thursday, Nov. 6, 2008, at 11 a.m. Eastern Standard Time (10 a.m. Central Standard Time). The call will also be carried live on ONEOK Partners’ and ONEOK’s Web sites.

To participate in the telephone conference call, dial 866-835-8907, pass code 1292355, or log on to http://www.oneok.com/ or http://www.oneokpartners.com/.

If you are unable to participate in the conference call or the webcast, the replay will be available on ONEOK Partners’ Web site, http://www.oneokpartners.com/, and ONEOK’s Web site, http://www.oneok.com/, for 30 days. A recording will be available by phone for seven days. The playback call may be accessed at 866-837-8032, pass code 1292355.

NON-GAAP FINANCIAL MEASURES

The partnership has disclosed in this news release EBITDA and DCF amounts that are non-GAAP financial measures. Management believes EBITDA and DCF provide useful information to investors as a measure of comparison with peer companies. However, these calculations may vary from company to company, so the partnership’s computations may not be comparable with those of other companies. DCF is not necessarily the same as available cash as defined in the Partnership Agreement. Management further uses EBITDA to compare the financial performance of its segments and to internally manage those business segments. Reconciliations of EBITDA to net income and operating income and computations of DCF are included in the financial tables attached to this release.

ONEOK Partners, L.P. is one of the largest publicly traded limited partnerships, and is a leader in the gathering, processing, storage and transportation of natural gas in the U.S. and owns one of the nation’s premier natural gas liquids (NGL) systems, connecting much of the natural gas and NGL supply in the Mid-Continent with key market centers. Our general partner is ONEOK, Inc. , a diversified energy company, which owns 47.7 percent of the overall partnership interest. ONEOK is one of the largest natural gas distributors in the United States, and its energy services operation focuses primarily on marketing natural gas and related services throughout the U.S.

For more information, visit the Web sites at http://www.oneokpartners.com/ or http://www.oneok.com/.

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

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

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

   --  the effects of weather and other natural phenomena on our operations,       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;   --  the capital intensive nature of our businesses;   --  the profitability of assets or businesses acquired by us;   --  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, 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;   --  actions by rating agencies concerning the credit ratings of us or our       general partner;   --  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 control 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 rights-of-way permits and       consents 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;   --  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 significant slowdown in growth or decline in the U.S.       economy or the risk of delay in growth recovery in the U.S. economy,       including increasing liquidity risks in U.S. 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 impact of unsold pipeline capacity being greater or less than       expected;   --  the ability to recover operating costs and amounts equivalent to       income taxes, costs of property, plant and equipment and regulatory       assets in our state and FERC-regulated rates;   --  the composition and quality of the natural gas and NGLs we gather and       process in our plants and transport on our pipelines;   --  the efficiency of our plants in processing natural gas and extracting       and fractionating NGLs;   --  the impact of potential impairment charges;   --  the risk inherent in the use of information systems in our respective       businesses, implementation of new software and hardware, and the       impact on the timeliness of information for financial reporting;   --  our ability to control construction costs and completion schedules of       our pipelines and other projects; and   --  the risk factors listed in the reports we have filed and may file with       the SEC, which are incorporated by reference.    

These factors are not necessarily all of the important factors that could cause actual results to differ materially from those expressed in any of our forward-looking statements. Other factors could also have material adverse effects on our future results. These and other risks are described in greater detail in Part I, Item 1A, Risk Factors, in our Annual Report on Form 10-K for the year ended December 31, 2007. All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these factors. Other than as required under securities laws, we undertake no obligation to update publicly any forward-looking statement whether as a result of new information, subsequent events or change in circumstances, expectations or otherwise. OKS-FE

    Analyst Contact:    Christy Williamson                        918-588-7163    Media Contact:      Megan Washbourne                        918-588-7572       ONEOK Partners, L.P. and Subsidiaries   CONSOLIDATED STATEMENTS OF INCOME                                  Three Months Ended      Nine Months Ended                                    September 30,           September 30,   (Unaudited)                    2008        2007        2008        2007                             (Thousands of dollars, except per unit amounts)   Revenues                   $2,241,107  $1,410,257  $6,444,034  $3,954,245   Cost of sales and fuel      1,915,707   1,196,373   5,569,176   3,317,421   Net Margin                    325,400     213,884     874,858     636,824   Operating Expenses     Operations and maintenance   86,456      71,470     243,929     212,517     Depreciation and      amortization                30,408      28,800      90,383      84,326     General taxes                11,032       8,609      28,799      24,866   Total Operating Expenses      127,896     108,879     363,111     321,709   Gain (Loss) on Sale of    Assets                            22         111          50       1,935   Operating Income              197,526     105,116     511,797     317,050   Equity earnings from    investments                   29,412      22,162      74,805      64,975   Allowance for equity funds    used during construction      15,616       3,691      35,788       6,686   Other income                      990         905       3,724       4,870   Other expense                  (5,784)       (125)     (7,951)       (636)   Interest expense              (34,447)    (33,510)   (107,681)    (99,313)   Income before Minority    Interests and Income    Taxes                        203,313      98,239     510,482     293,632   Minority interests in    income of consolidated    subsidiaries                    (111)       (125)       (368)       (302)   Income taxes                      670      (2,198)     (6,703)     (7,039)   Net Income                   $203,872     $95,916    $503,411    $286,291    Limited partners' interest    in net income:   Net income                   $203,872     $95,916    $503,411    $286,291   General partners' interest    in net income                (24,397)    (14,872)    (65,790)    (42,203)     Limited Partners' Interest      in Net Income             $179,475     $81,044    $437,621    $244,088    Limited partners' per unit    net income:     Net income per unit           $1.97       $0.98       $4.93       $2.94   Number of Units Used in    Computation (Thousands)       90,920      82,891      88,768      82,891    Supplemental Information (1):   EBITDA                       $252,552    $156,858    $672,758    $470,585   Distributable cash flow      $190,955    $107,084    $526,738    $346,018   Distributable cash flow    per unit                       $1.85       $1.11       $5.23       $3.66    (1)  Reconciliations of non-GAAP financial measures are included in the        financial tables attached to this release.      ONEOK Partners, L.P. and Subsidiaries   CONSOLIDATED BALANCE SHEETS                                           September 30,   December 31,   (Unaudited)                                 2008           2007   Assets                                    (Thousands of dollars)    Current Assets     Cash and cash equivalents                $15,803        $3,213     Accounts receivable, net                 475,105       577,989     Affiliate receivables                     43,234        52,479     Gas and natural gas liquids in      storage                                 265,824       251,219     Commodity exchanges and imbalances        79,345        82,037     Other current assets                      49,691        19,961       Total Current Assets                   929,002       986,898    Property, Plant and Equipment     Property, plant and equipment          5,444,041     4,436,371     Accumulated depreciation and      amortization                            849,699       776,185       Net Property, Plant and Equipment    4,594,342     3,660,186    Investments and Other Assets     Investment in unconsolidated      affiliates                              756,449       756,260     Goodwill and intangible assets           678,453       682,084     Other assets                              34,049        26,637       Total Investments and Other Assets   1,468,951     1,464,981       Total Assets                        $6,992,295    $6,112,065    Liabilities and Partners' Equity    Current Liabilities     Current maturities of long-term debt     $11,931      $11,930     Notes payable                            280,000      100,000     Accounts payable                         759,785      742,903     Affiliate payables                        29,699       18,298     Commodity exchanges and imbalances       245,882      252,095     Other current liabilities                151,058      136,664       Total Current Liabilities            1,478,355    1,261,890    Long-term Debt, excluding current    maturities                              2,593,481    2,605,396    Deferred Credits and Other    Liabilities                                43,744       43,799    Commitments and Contingencies    Minority Interests in Consolidated    Subsidiaries                                5,947        5,802    Partners' Equity     General partner                           77,520       58,415     Common units: 54,426,087 units and      46,397,214 units issued and      outstanding at September 30, 2008,      and December 31, 2007,      respectively                          1,360,311      814,266     Class B units: 36,494,126 units      issued and outstanding at      September 30, 2008, and December      31, 2007                              1,406,515     1,340,638     Accumulated other comprehensive      income (loss)                            26,422       (18,141)       Total Partners' Equity               2,870,768     2,195,178       Total Liabilities and Partners'        Equity                             $6,992,295    $6,112,065      ONEOK Partners, L.P. and Subsidiaries   CONSOLIDATED STATEMENTS OF CASH FLOWS                                                      Nine Months Ended                                                         September 30,   (Unaudited)                                         2008        2007                                                    (Thousands of dollars)   Operating Activities   Net income                                       $503,411      $286,291   Depreciation and amortization                      90,383        84,326   Allowance for equity funds used    during construction                              (35,788)       (6,686)   Gain on sale of assets                                (50)       (1,935)   Minority interests in income of    consolidated subsidiaries                            368           302   Equity earnings from investments                  (74,805)      (64,975)   Distributions received from    unconsolidated affiliates                         67,812        77,144   Changes in assets and liabilities    (net of acquisition and disposition    effects):     Accounts receivable                              98,214       (83,065)     Affiliate receivables                             9,245        45,650     Gas and natural gas liquids in storage          (59,690)      (29,357)     Accounts payable                                (52,516)      146,880     Affiliate payables                               11,401         1,734     Commodity exchanges and imbalances, net          (3,521)       22,627     Accrued interest                                 32,117        23,086     Other assets and liabilities                    (17,916)       24,461     Cash Provided by Operating Activities           568,665       526,483    Investing Activities   Changes in investments in    unconsolidated affiliates                          3,063        (5,546)   Capital expenditures (less allowance    for equity funds used during    construction)                                   (860,167)     (408,353)   Proceeds from sale of assets                          133         3,959   Other                                               2,450             -     Cash Used in Investing Activities              (854,521)     (409,940)    Financing Activities   Cash distributions to:     General and limited partners                   (332,090)     (285,998)     Minority interests                                 (223)         (147)   Borrowing (payment) of notes payable, net         180,000       359,000   Issuance of common units, net of discounts        450,198             -   Contributions from general partner                  9,508             -   Issuance of long-term debt                              -       598,146   Payment of long-term debt                          (8,947)       (8,948)   Other                                                   -        (5,280)     Cash Provided by Financing Activities           298,446       656,773       Change in Cash and Cash Equivalents            12,590       773,316       Cash and Cash Equivalents at        Beginning of Period                            3,213        21,102       Cash and Cash Equivalents at End of Period    $15,803      $794,418      ONEOK Partners, L.P. and Subsidiaries   INFORMATION AT A GLANCE                                        Three Months Ended Nine Months Ended                                           September 30,     September 30,   (Unaudited)                             2008     2007     2008     2007                                      (Millions of dollars, except as noted)   Natural Gas Gathering and Processing   Net margin                             $111.7    $87.6   $336.7   $249.4   Operating costs                         $35.7    $31.8   $101.5    $96.4   Depreciation and amortization           $12.5    $11.3    $36.4    $33.5   Operating income                        $63.5    $44.6   $198.8   $121.3   Equity earnings from investments         $8.8     $6.2    $24.0    $19.5   Natural gas gathered (BBtu/d)           1,146    1,170    1,174    1,168   Natural gas processed (BBtu/d)            649      617      641      615   Natural gas liquids sales (MBbl/d)         39       37       39       37   Natural gas sales (BBtu/d)                281      289      280      279   Realized composite NGL sales price    ($/gallon)                             $1.51    $1.09    $1.44    $0.97   Realized condensate sales price    ($/Bbl)                               $99.61   $69.05   $96.91   $61.25   Realized natural gas sales price    ($/MMBtu)                              $8.33    $5.41    $8.39    $6.20   Realized gross processing spread    ($/MMBtu)                              $6.69    $5.54    $6.94    $4.56   Capital expenditures - growth           $27.8    $27.4    $82.6    $60.5   Capital expenditures - maintenance       $8.0     $4.9    $16.0    $11.7    Natural Gas Pipelines   Net margin                              $65.8    $60.2   $196.2   $179.7   Operating costs                         $23.9    $24.1    $67.9    $70.0   Depreciation and amortization            $8.6     $8.1    $25.5    $24.2   Operating income                        $33.3    $28.1   $102.7    $85.6   Equity earnings from investments        $20.2    $16.5    $49.4    $45.3   Natural gas transported (MMcf/d)        3,500    3,378    3,637    3,524   Average natural gas price     Mid-Continent region ($/MMBtu)        $8.44    $5.42    $8.27    $6.08   Capital expenditures - growth           $97.7    $39.5   $146.2    $81.3   Capital expenditures - maintenance      $10.1     $5.1    $13.6     $9.3    Natural Gas Liquids Gathering and    Fractionation   Net margin                             $118.6    $48.8   $255.5   $155.3   Operating costs                         $23.0    $17.8    $61.6    $49.4   Depreciation and amortization            $5.9     $6.4    $17.2    $17.5   Operating income                        $89.8    $24.6   $176.8    $88.4   Natural gas liquids gathered (MBbl/d)     243      232      249      222   Natural gas liquids sales (MBbl/d)        273      223      275      221   Natural gas liquids fractionated    (MBbl/d)                                 375      370      379      346   Conway-to-Mont Belvieu OPIS average    price differential    Ethane ($/gallon)                      $0.24    $0.05    $0.15    $0.05   Capital expenditures - growth           $46.3    $17.5   $123.8    $34.7   Capital expenditures - maintenance       $6.3     $3.1    $13.4     $8.5    Natural Gas Liquids Pipelines   Net margin                              $29.8    $18.0    $88.5    $51.9   Operating costs                         $15.0     $5.6    $42.2    $16.6   Depreciation and amortization            $3.4     $3.0    $11.2     $9.0   Operating income                        $11.4     $9.3    $35.1    $26.4   Equity earnings from investments         $0.4    $(0.5)    $1.4     $0.2   Natural gas liquids transported    (MBbl/d)                                 331      225      314      219   Natural gas liquids gathered (MBbl/d)      88       84       92       78   Capital expenditures - growth          $137.7   $103.0   $461.0   $200.3   Capital expenditures - maintenance       $1.7     $1.4     $3.5     $1.9      ONEOK Partners, L.P. and Subsidiaries   RECONCILIATION OF EBITDA NON-GAAP FINANCIAL MEASURES                                       Three Months Ended  Nine Months Ended                                        September 30,       September 30,   (Unaudited)                          2008      2007      2008      2007                                              (Thousands of dollars)   Reconciliation of Net Income to    EBITDA   Net income                         $203,872   $95,916  $503,411  $286,291   Minority interests                      111       125       368       302   Interest expense, net                34,447    33,510   107,681    99,313   Depreciation and amortization        30,408    28,800    90,383    84,326   Income taxes                           (670)    2,198     6,703     7,039   Allowance for equity funds used    during construction                (15,616)   (3,691)  (35,788)   (6,686)     EBITDA                           $252,552  $156,858  $672,758  $470,585    Natural Gas Gathering and    Processing Reconciliation of    Operating Income to EBITDA   Operating income                    $63,538   $44,550  $198,774  $121,276   Depreciation and amortization        12,533    11,277    36,431    33,544   Equity earnings from investments      8,819     6,180    23,989    19,518   Other income (expense)               (2,191)     (366)   (3,128)     (163)     EBITDA                            $82,699   $61,641  $256,066  $174,175    Natural Gas Pipelines    Reconciliation of Operating    Income to EBITDA   Operating income                    $33,303   $28,122  $102,708   $85,560   Depreciation and amortization         8,607     8,089    25,547    24,246   Equity earnings from investments     20,207    16,493    49,421    45,275   Other income (expense)               (1,391)     (198)   (1,983)       30     EBITDA                            $60,726   $52,506  $175,693  $155,111    Natural Gas Liquids Gathering and    Fractionation Reconciliation of    Operating Income to EBITDA   Operating income                    $89,788   $24,628  $176,762   $88,414   Depreciation and amortization         5,901     6,439    17,188    17,525   Equity earnings from investments          -         -         -         -   Other income (expense)               (1,659)     (304)   (2,729)     (571)     EBITDA                            $94,030   $30,763  $191,221  $105,368    Natural Gas Liquids Pipelines    Reconciliation of Operating    Income to EBITDA   Operating income                    $11,414    $9,347   $35,117   $26,394   Depreciation and amortization         3,361     2,987    11,200     8,990   Equity earnings from investments        386      (511)    1,395       182   Other income (expense)                 (990)     (279)   (1,440)     (153)     EBITDA                            $14,171   $11,544   $46,272   $35,413      ONEOK Partners, L.P. and Subsidiaries   RECONCILIATION OF DISTRIBUTABLE CASH FLOW NON-GAAP FINANCIAL MEASURES                                       Three Months Ended  Nine Months Ended                                          September 30,     September 30,   (Unaudited)                           2008     2007     2008       2007                                            (Thousands of dollars,                                            except per unit amounts)   Reconciliation of EBITDA to    Distributable Cash Flow   EBITDA                             $252,552  $156,858  $672,758  $470,585   (Gain)/loss on sale of assets           (22)     (111)      (50)   (1,935)   Interest expense                    (34,447)  (33,510) (107,681)  (99,313)   Maintenance capital                 (26,146)  (14,593)  (46,564)  (31,443)   Distributions to minority    interests                              (75)      (74)     (223)     (147)   Equity earnings from investments    (29,412)  (22,162)  (74,805)  (64,975)   Distributions received from    unconsolidated affiliates           30,466    20,078    91,093    77,144   Current income tax expense and    other                               (1,961)      598    (7,790)   (3,898)     Distributable Cash Flow          $190,955  $107,084  $526,738  $346,018     Distributions to General Partner    (22,739)  (14,928)  (62,760)  (42,297)   Distributable Cash Flow to Limited    Partners                          $168,216   $92,156  $463,978  $303,721    Distributable Cash Flow per    Limited Partner Unit                 $1.85     $1.11     $5.23     $3.66    Distributions Declared per Limited    Partner Unit                         $1.08     $1.01     $3.18     $3.00    Coverage Ratio                         1.71      1.10      1.64      1.22     Number of Units Used in    Computation (Thousands)             90,920    82,891    88,768    82,891      ONEOK Partners, L.P. and Subsidiaries                        Exhibit A   EARNINGS GUIDANCE*                                              Updated     Previous                                               2008        2008                                             Guidance    Guidance    Change                                                 (Millions of dollars,                                                except per unit amounts)   Operating Income     Natural Gas Gathering & Processing        $254        $269       $(15)     Natural Gas Pipelines                      130         142        (12)     Natural Gas Liquids Gathering &      Fractionation                             214         153         61     Natural Gas Liquids Pipelines               57          68        (11)     Other                                       (2)         (8)         6   Operating Income                             653         624         29   Equity earnings from investments              94          81         13   Other income (expense)                        48          42          6   Interest expense                            (153)       (161)         8   Income taxes and other                       (11)        (15)         4   Net Income                                  $631        $571        $60    Net Income Per Unit                        $6.05       $5.40      $0.65    Number of Units Used in Computation    (Millions)                                 89.3        89.3          -     Capital Expenditures      Natural Gas Gathering & Processing        $150        $150         $-     Natural Gas Pipelines                      245         245          -     Natural Gas Liquids Gathering &      Fractionation                             172         172          -     Natural Gas Liquids Pipelines              747         747          -   Total Capital Expenditures                $1,314      $1,314         $-    Growth                                    $1,230      $1,230         $-   Maintenance                                   84          84          -   Total Capital Expenditures                $1,314      $1,314         $-    *Amounts shown are midpoints of ranges provided.      ONEOK Partners, L.P. and Subsidiaries                        Exhibit B   EARNINGS GUIDANCE*                                              Updated     Previous                                                2008        2008                                              Guidance    Guidance     Change                                                    (Millions of dollars)    Reconciliation of Net Income to EBITDA   Net income                                  $631        $571         $60   Interest expense                             153         161          (8)   Depreciation and amortization                128         132          (4)   Income taxes and other                        11          15          (4)   Equity AFUDC                                 (50)        (41)         (9)     EBITDA                                    $873        $838         $35    Reconciliation of EBITDA to Distributable    Cash Flow   EBITDA                                      $873        $838         $35   Interest expense                            (153)       (161)          8   Maintenance capital                          (84)        (84)          -   Equity earnings from investments             (94)        (81)        (13)   Distributions received from    investments                                 110         105           5   Current income tax expense and other         (12)        (12)          -     Distributable Cash Flow                   $640        $605         $35    *Amounts shown are midpoints of ranges provided.  

ONEOK Partners, L.P.

CONTACT: analysts, Christy Williamson, +1-918-588-7163, or media, MeganWashbourne, +1-918-588-7572, both of ONEOK Partners, L.P.

Web site: http://www.oneokpartners.com/http://www.oneok.com/




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