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ONEOK Partners Reports Higher Second-Quarter 2008 Results; Raises 2008 Earnings Guidance

August 5, 2008

TULSA, Okla., Aug. 5 /PRNewswire-FirstCall/ — ONEOK Partners, L.P. today announced that its second-quarter 2008 net income rose 63 percent to $154.5 million, or $1.46 per unit, compared with net income of $94.6 million, or 97 cents per unit, for the second quarter 2007.

Year-to-date 2008 net income increased 57 percent to $299.5 million, or $2.94 per unit, compared with $190.4 million, or $1.97 per unit, in the same period last year.

“The partnership had another exceptional quarter, with earnings gains in all four of its business segments,” said John W. Gibson, chairman and chief executive officer of ONEOK Partners. “Second-quarter earnings increased primarily as a result of higher realized commodity prices in our natural gas gathering and processing segment and increased throughput in our natural gas liquids gathering and fractionation segment. We also continue to benefit from the natural gas liquids and refined petroleum products pipeline system we acquired last fall,” Gibson added.

“We are beginning to see the partnership’s current internal growth projects come on line and have identified $300 million to $500 million per year in additional growth projects between 2010 and 2015,” Gibson added. “Two of our largest projects, Overland Pass Pipeline and the Guardian extension, are expected to become operational during the second half of this year.”

ONEOK Partners raised its 2008 net income guidance to the range of $5.20 to $5.60 per unit from the range of $4.10 to $4.60 per unit. The partnership’s distributable cash flow is now expected to be in the range of $585 million to $625 million. Strong results in the first half of 2008, combined with the current commodity price environment and hedges in place, have resulted in increased 2008 income and cash flow guidance in the natural gas gathering and processing segment and natural gas liquids gathering and fractionation segment. The natural gas liquids pipelines segment’s 2008 income has been adjusted to reflect the previously announced delay of the Overland Pass Pipeline, which is expected to become operational in the third quarter 2008. Additional information is available in exhibits A and B.

The 2008 average unhedged prices used in the updated guidance are approximately $120 per barrel for crude oil, $1.65 per gallon for composite natural gas liquids and $9.20 per MMBtu for natural gas.

In the second quarter 2008, cash flow, as measured by earnings before interest, taxes, depreciation and amortization (EBITDA), rose 35 percent to $212.0 million, compared with $156.5 million in the second quarter 2007. Distributable cash flow (DCF) for the second quarter 2008 increased to $176.9 million, or $1.72 per unit, compared with $122.0 million, or $1.30 per unit, in the second quarter 2007.

Year-to-date 2008 EBITDA rose 34 percent to $420.2 million, compared with $313.7 million in the same period last year. DCF for the six months ended June 30, 2008, increased to $335.8 million, or $3.37 per unit, compared with $238.9 million, or $2.55 per unit, in the same period last year.

Second-quarter 2008 operating income increased to $163.7 million, compared with $107.6 million in the same period a year earlier. For the six months 2008, operating income increased 48 percent to $314.3 million.

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

Operating costs were $87.2 million in the second quarter 2008, compared with $81.6 million in the same period last year. Operating costs for the six months ended June 30, 2008, were $175.2 million, compared with $157.3 million in the same period last year. Operating cost increases for the three- and six-month 2008 periods are primarily due to incremental expenses associated with the acquisition of the North System, as well as increases in general operating and employee-related costs.

   SECOND-QUARTER 2008 SUMMARY INCLUDES:    --  Operating income of $163.7 million, compared with $107.6 million in       the second quarter 2007;   --  Natural gas gathering and processing segment operating income of $76.2       million, compared with $46.3 million in the second quarter 2007;   --  Natural gas pipelines segment operating income of $37.7 million,       compared with $25.1 million in the second quarter 2007;   --  Natural gas liquids gathering and fractionation segment operating       income of $41.7 million, compared with $31.8 million in the second       quarter 2007;   --  Natural gas liquids pipelines segment operating income of $9.9       million, compared with $8.4 million in the second quarter 2007;   --  Equity earnings from investments of $17.6 million, compared with $18.8       million in the second quarter 2007;   --  Capital expenditures of $257.5 million, compared with $131.8 million       in the second quarter 2007, primarily due to internally generated       growth projects;   --  Completing the expansion of Fort Union Gas Gathering in July, which       doubles the capacity of the system located in the Powder River Basin       that gathers coal bed methane natural gas;   --  Increasing the quarterly distribution to $1.06 per unit, marking the       10th consecutive quarter to raise the distribution;   --  Appointing James C. Kneale president and chief operating officer of       ONEOK Partners, in addition to his duties as president and chief       operating officer of ONEOK, Inc.; and   --  Receiving an award for achieving three years of excellence in employee       health and safety at the partnership's Mont Belvieu fractionator from       the Occupational Safety and Health Administration.     SECOND-QUARTER 2008 BUSINESS UNIT RESULTS    Natural Gas Gathering and Processing Segment  

The natural gas gathering and processing segment reported increased operating income for the second quarter 2008 of $76.2 million, compared with $46.3 million for the second quarter 2007.

Second-quarter 2008 operating income increased $23.4 million from higher realized commodity prices, $5.2 million from higher volumes sold and processed, and $4.1 million from improved contract terms. Operating costs for the segment were $32.8 million, compared with $30.6 million in the second quarter 2007.

Operating income for the six months increased to $135.2 million, compared with $76.7 million in 2007. The increase was due to $47.9 million in higher realized commodity prices, $9.2 million from higher volumes sold and processed, and $6.2 million from improved contract terms. Operating costs for the segment were $65.9 million, compared with $64.6 million in the six-month period in 2007.

Equity earnings from investments increased for both the three- and six- months ended 2008, compared with 2007, primarily from higher gathering revenues in various investments in the Rocky Mountain region.

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     Six Months Ended                                         June 30,               June 30,                                      2008       2007       2008       2007   Percent of proceeds     Wellhead purchases (MMBtu/d)    69,389     86,281     69,960     91,325     NGL sales (Bbl/d)                6,475      6,113      6,107      6,044     Residue sales (MMBtu/d)         36,947     30,441     36,776     30,406     Condensate sales (Bbl/d)         1,070        740      1,092        711     Percentage of total net margin     64%        57%        62%        57%   Fee-based     Wellhead volumes (MMBtu/d)   1,184,654  1,188,139  1,188,169  1,178,325     Average rate ($/MMBtu)           $0.26      $0.25      $0.26      $0.25     Percentage of total net margin     21%        32%        22%        33%   Keep-whole     NGL shrink (MMBtu/d)            22,433     23,837     22,970     24,351     Plant fuel (MMBtu/d)             2,313      2,788      2,400      2,924     Condensate shrink (MMBtu/d)      2,242      2,223      2,127      2,546     Condensate sales (Bbl/d)           454        450        430        515     Percentage of total net margin     15%        11%        16%        10%     

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

                                                  Six Months Ending                                                  December 31, 2008                                         Volumes                    Percentage                                        Hedged     Average Price     Hedged    Natural gas liquids (Bbl/d) (a)       8,560     $1.31 / gallon      74%   Condensate (Bbl/d) (a)                  748     $2.16 / gallon      78%   Total liquid sales (Bbl/d)            9,308     $1.38 / gallon      74%    Natural gas (MMBtu/d) (a)             5,500     $9.35 / MMBtu       54%    (a) - Hedged with fixed-price swaps.                                                       Year Ending                                                  December 31, 2009                                         Volumes                    Percentage                                        Hedged      Average Price    Hedged    Natural gas liquids (Bbl/d) (a)       3,313     $2.01 / gallon      28%   Condensate (Bbl/d) (a)                  666     $3.23 / gallon      47%   Total liquid sales (Bbl/d)            3,979     $2.22 / gallon      30%    (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 $1.6 million. A $1.00 per barrel increase in the price of crude oil would increase annual net margin by approximately $0.7 million. Also, a 10 cent per MMBtu increase in the price of natural gas would increase annual net margin by approximately $0.2 million. All these sensitivities exclude the effects of hedging and assume normal operating conditions.

Natural Gas Pipelines Segment

The natural gas pipelines segment reported increased operating income for the second quarter 2008 of $37.7 million, compared with $25.1 million for the second quarter 2007.

Increased operating income during the quarter reflects $5.5 million of increased transportation margins, as a result of the higher natural gas price impact on retained fuel, and higher throughput; and $2.2 million of increased storage margins, as a result of higher storage fees. Operating costs decreased $4.3 million to $20.5 million due to lower general taxes and lower general operating costs.

Operating income for the six months increased to $69.4 million, compared with $57.4 million in the same period in 2007.

Six-month 2008 results reflect a $5.2 million increase in transportation margins as a result of the higher natural gas price impact on retained fuel, and a $4.1 million increase in storage margins as a result of higher storage fees and the higher natural gas price impact on retained fuel. Operating costs for the segment were $44.0 million in the six-month 2008 period, compared with $45.8 million in the same period last year, down primarily due to decreased general taxes.

Second-quarter 2008 equity earnings from investments were $9.2 million, compared with $10.6 million in the second quarter 2007. The decrease was primarily due to lower throughput on Northern Border Pipeline, in which the partnership has a 50 percent interest. Six-month 2008 equity earnings from investments were $29.2 million, compared with $28.8 million in the six months ended 2007.

Natural Gas Liquids Gathering and Fractionation Segment

The natural gas liquids gathering and fractionation segment reported operating income for the second quarter 2008 of $41.7 million, compared with $31.8 million for the second quarter 2007.

During the second quarter 2008, operating income increased $11.7 million from increased throughput due to new supply connections and increased fractionation volumes; $3.2 million from wider regional NGL product price differentials between the NGL market centers in Conway, Kan., and Mont Belvieu, Texas; and $1.4 million from higher storage margins. These increases were partially offset by $3.4 million in lower isomerization volumes as a result of narrower product price differentials between isobutane and normal butane.

Operating costs were $20.0 million in the second quarter 2008, compared with $16.9 million in the second quarter 2007, primarily due to increased costs incurred to comply with regulations at storage facilities, higher employee-related costs and higher maintenance costs at the partnership’s Mont Belvieu fractionator.

Operating income for the six months increased to $87.0 million, compared with $63.8 million in 2007.

Six-month 2008 results reflect a $16.8 million increase from higher throughput due to new supply connections and increased fractionation volumes; $16.0 million from wider regional NGL product price differentials between the NGL market centers in Conway and Mont Belvieu; and $1.9 million from higher storage margins. These increases were partially offset by a $4.4 million decrease from lower isomerization volumes as a result of narrower product price differentials between isobutane and normal butane.

Six-month 2008 operating costs for the segment were $38.6 million, compared with $31.6 million in the same period last year. The increase results from higher costs incurred to comply with regulations at storage facilities, higher employee-related costs and higher maintenance costs at the Mont Belvieu fractionator.

The second-quarter 2008 Conway-to-Mont Belvieu Oil Price Information Service (OPIS) average price differential for ethane/propane mix was 13 cents per gallon, compared with 5 cents per gallon in the same period last year.

Natural Gas Liquids Pipelines Segment

The natural gas liquids pipelines segment reported increased operating income of $9.9 million, compared with $8.4 million for the second quarter 2007.

Second-quarter 2008 operating income improved as a result of $9.4 million from increased margins on the recently acquired North System, as well as $1.1 million from increased throughput due to new supply connections. Operating costs for the segment increased $8.2 million in the second quarter 2008, compared with the second quarter 2007, primarily due to incremental expenses associated with operating the North System, as well as higher employee-related costs.

Operating income for the six months 2008 increased to $23.7 million, compared with $17.0 million in 2007.

Six-month 2008 results benefited from $22.0 million of increased margins from the North System and $2.7 million from increased throughput due to new NGL supply connections and increased production from existing supply connections. Operating costs for the segment were $27.2 million in the six months ended June 30, 2008, compared with $10.9 million in the same period last year. The increase was due primarily to incremental expenses associated with operating the North System, as well as higher employee-related costs.

GROWTH ACTIVITIES

In the second 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 June, construction was completed on much of the $230 million to $240 million of projects that increase existing NGL fractionation and distribution pipeline capacity. The project costs have increased from $216 million, primarily as a result of increasing the Bushton, Kan., fractionator capacity by an additional 30,000 barrels per day (bpd) from initial design specifications of 120,000 bpd, as well as higher construction labor costs and weather delays. The projects include expanding the Bushton fractionator from 80,000 bpd to 150,000 bpd; upgrading the NGL storage at Bushton; constructing a 135-mile pipeline from Bushton to Medford, Okla.; and expanding distribution pipeline capacity by 60,000 bpd from Medford to Mont Belvieu.

The partnership is nearing completion of a $30 million to $35 million, 78-mile NGL pipeline extension of the 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 partnership has experienced increases in construction costs from the original estimate of $25 million due to an unanticipated pipeline reroute, numerous weather delays and rock-filled terrain encountered during construction.

Other NGL growth projects include a joint venture to build Overland Pass Pipeline, a 760-mile natural gas liquids pipeline extending from Opal, Wyo., to Conway, Kan., currently estimated to cost $575 million to $590 million. 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. Construction on the pipeline began in the fall of 2007 and is currently expected to begin operating during the third quarter of 2008, with final completion expected in the fourth quarter. Severe winter weather conditions in southern Wyoming and construction interruptions this spring and summer, due to restrictions in state and federally regulated wildlife areas, have increased estimated costs from $535 million and have affected the construction schedule.

The Overland Pass Pipeline project economics remain favorable as the volume forecast continues to increase, driven by new drilling and processing plant development. 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.

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 second quarter of 2009.

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 is expected to go into service in early 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. Cost increases from the original estimate of $260 million on the Arbuckle Pipeline are a result of higher right-of-way, labor and material costs, primarily valves and fittings. Project economics remain favorable as the volume forecast continues to increase, driven by new drilling and processing plant development. Supply commitments from producers are in place for 65,000 bpd, and there are indications of interest with other producers that could add an additional 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, construction on the Fort Union Gas Gathering expansion project was completed. The project doubles the 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 current cost projection is unchanged, but various factors including weather, the amount of rock-filled terrain encountered and increasing right-of-way costs could impact the estimated project costs.

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 expansion project is becoming operational in phases, with the final phase currently expected to come on line in the second half of 2008. The project is currently estimated to cost $40 million to $45 million, increasing from the original estimate of $30 million, as a result of increased construction labor and equipment costs.

CONFERENCE CALL AND WEBCAST

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

To participate in the telephone conference call, dial 866-847-7861, pass code 1250710, or log on to http://www.oneokpartners.com/ or http://www.oneok.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 1250710.

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 a wholly owned subsidiary of 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, authorized rates or recovery of gas and gas       transportation costs;   --  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 or changes in       governmental policies and regulations due to climate change       initiatives;   --  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;   --  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       which 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;       -  availability of additional storage capacity;       -  weather conditions; and       -  competitive developments by Canadian and U.S. natural gas          transmission peers;   --  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       pipelines 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;   --  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;   --  our ability to promptly obtain all necessary materials and supplies       required for construction of gathering, processing, storage,       fractionation and transportation facilities;   --  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:    Tom Droege                     918-588-7561      ONEOK Partners, L.P. and Subsidiaries   CONSOLIDATED STATEMENTS OF INCOME                                 Three Months Ended       Six Months Ended                                     June 30,                June 30,   (Unaudited)                   2008        2007        2008        2007                              (Thousands of dollars, except per unit amounts)    Revenues                   $2,143,892  $1,375,314  $4,202,927  $2,543,988   Cost of sales and fuel      1,862,959   1,157,744   3,653,469   2,121,048   Net Margin                    280,933     217,570     549,458     422,940   Operating Expenses     Operations and maintenance   80,532      74,371     157,473     141,047     Depreciation and      amortization                30,033      28,013      59,975      55,526     General taxes                 6,626       7,249      17,767      16,257   Total Operating Expenses      117,191     109,633     235,215     212,830   Gain (Loss) on Sale of    Assets                            (3)       (379)         28       1,824   Operating Income              163,739     107,558     314,271     211,934   Equity earnings from    investments                   17,610      18,758      45,393      42,813   Allowance for equity funds    used during construction      11,676       1,658      20,172       2,995   Other income                      676       2,502       2,734       3,965   Other expense                     (36)       (298)     (2,167)       (511)   Interest expense              (34,705)    (33,503)    (73,234)    (65,803)   Income before Minority    Interests and Income    Taxes                        158,960      96,675     307,169     195,393   Minority interests in    income of consolidated    subsidiaries                    (134)        (92)       (257)       (177)   Income taxes                   (4,305)     (1,964)     (7,373)     (4,841)   Net Income                   $154,521     $94,619    $299,539    $190,375    Limited partners' interest    in net income:   Net income                   $154,521     $94,619    $299,539    $190,375   General partners' interest    in net income                (21,688)    (14,052)    (41,393)    (27,330)     Limited Partners' Interest      in Net Income             $132,833     $80,567    $258,146    $163,045    Limited partners' per unit    net income:     Net income per unit           $1.46       $0.97       $2.94       $1.97   Number of Units Used in    Computation  (Thousands)      90,906      82,891      87,680      82,891    Supplemental Information(1):   EBITDA                       $212,022    $156,533    $420,206    $313,727   Distributable cash flow      $176,902    $121,951    $335,783    $238,934   Distributable cash flow    per unit                       $1.72       $1.30       $3.37       $2.55    (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                                                 June 30,        December 31,   (Unaudited)                                     2008              2007   Assets                                          (Thousands of dollars)    Current Assets     Cash and cash equivalents                    $76,410            $3,213     Accounts receivable, net                     538,185           577,989     Affiliate receivables                         67,294            52,479     Gas and natural gas liquids in storage       331,460           251,219     Commodity exchanges and imbalances           154,359            82,037     Other current assets                          24,934            19,961       Total Current Assets                     1,192,642           986,898    Property, Plant and Equipment     Property, plant and equipment              5,040,688         4,436,371     Accumulated depreciation and      amortization                                826,762           776,185       Net Property, Plant and Equipment        4,213,926         3,660,186    Investments and Other Assets     Investment in unconsolidated affiliates      752,952           756,260     Goodwill and intangible assets               680,369           682,084     Other assets                                  29,651            26,637       Total Investments and Other Assets       1,462,972         1,464,981       Total Assets                            $6,869,540        $6,112,065    Liabilities and Partners' Equity    Current Liabilities     Current maturities of long-term debt         $11,931           $11,930     Notes payable                                120,000           100,000     Accounts payable                             814,638           742,903     Affiliate payables                            52,856            18,298     Commodity exchanges and imbalances           379,619           252,095     Other current liabilities                    136,121           136,664       Total Current Liabilities                1,515,165         1,261,890    Long-term Debt, excluding current maturities 2,597,453         2,605,396    Deferred Credits and Other Liabilities          47,682            43,799    Commitments and Contingencies    Minority Interests in Consolidated    Subsidiaries                                    5,911             5,802    Partners' Equity     General partner                               74,043            58,415     Common units: 54,426,087 units and      46,397,214 units issued and      outstanding at June 30, 2008, and      December 31, 2007, respectively           1,310,567           814,266     Class B units: 36,494,126 units      issued and outstanding at June      30, 2008, and December 31, 2007           1,373,160         1,340,638     Accumulated other comprehensive loss         (54,441)          (18,141)       Total Partners' Equity                   2,703,329         2,195,178       Total Liabilities and Partners'        Equity                                 $6,869,540        $6,112,065      ONEOK Partners, L.P. and Subsidiaries   CONSOLIDATED STATEMENTS OF CASH FLOWS                                                      Six Months Ended                                                          June 30,   (Unaudited)                                     2008              2007                                                   (Thousands of dollars)   Operating Activities   Net income                                    $299,539          $190,375   Depreciation and amortization                   59,975            55,526   Allowance for equity funds used    during construction                           (20,172)           (2,995)   Gain on sale of assets                             (28)           (1,824)   Minority interests in income of    consolidated subsidiaries                         257               177   Equity earnings from investments               (45,393)          (42,813)   Distributions received from    unconsolidated affiliates                      39,904            57,066   Changes in assets and liabilities    (net of acquisition and disposition    effects):     Accounts receivable                           35,134           (69,680)     Affiliate receivables                        (14,815)           21,468     Gas and natural gas liquids in storage      (104,557)            8,637     Accounts payable                              39,225           140,858     Affiliate payables                            34,558           (10,130)     Commodity exchanges and imbalances, net       55,202            14,888     Other assets and liabilities                 (48,886)            3,407     Cash Provided by Operating Activities        329,943           364,960    Investing Activities   Changes in investments in unconsolidated    affiliates                                      6,480            (7,653)   Capital expenditures (less allowance for    equity funds used during construction)       (524,587)         (206,391)   Proceeds from sale of assets                       111             3,753   Changes in short-term investments                    -           (26,038)   Other                                            2,450                 -     Cash Used in Investing Activities           (515,546)         (236,329)    Financing Activities   Cash distributions to:     General and limited partners                (214,794)         (189,008)     Minority interests                              (148)              (73)   Borrowing (repayment) of notes payable, net     20,000            99,000   Issuance of common units, net of discounts     450,198                 -   Contributions from general partner               9,508                 -   Payment of long-term debt                       (5,964)           (2,983)   Other                                                -               (30)     Cash Provided by (Used in) Financing      Activities                                  258,800           (93,094)     Change in Cash and Cash Equivalents           73,197            35,537     Cash and Cash Equivalents at Beginning      of Period                                     3,213            21,102     Cash and Cash Equivalents at End of Period   $76,410           $56,639      ONEOK Partners, L.P. and Subsidiaries   INFORMATION AT A GLANCE                                         Three Months Ended  Six Months Ended                                              June 30,           June 30,   (Unaudited)                             2008     2007     2008      2007                                               (Millions of dollars)   Natural Gas Gathering and Processing   Net margin                              $121.1    $88.4   $225.0   $161.8   Operating costs                          $32.8    $30.6    $65.9    $64.6   Depreciation and amortization            $12.1    $11.1    $23.9    $22.3   Operating income                         $76.2    $46.3   $135.2    $76.7   Equity earnings from investments          $8.1     $7.7    $15.2    $13.3   Natural gas gathered (BBtu/d)            1,185    1,188    1,188    1,178   Natural gas processed (BBtu/d)             651      619      637      614   Natural gas liquids sales (MBbl/d)          40       38       39       37   Natural gas sales (BBtu/d)                 281      273      279      271   Realized composite NGL sales price    ($/gallon)                              $1.49    $0.99    $1.41    $0.91   Realized condensate sales price    ($/Bbl)                               $102.77   $59.79   $95.82   $58.06   Realized natural gas sales price    ($/MMBtu)                               $9.42    $6.83    $8.41    $6.71   Realized gross processing spread    ($/MMBtu)                               $6.69    $4.55    $7.06    $4.08   Capital expenditures - growth            $31.4    $19.4    $54.8    $33.2   Capital expenditures - maintenance        $4.9     $4.2     $8.0     $6.7    Natural Gas Pipelines   Net margin                               $66.7    $57.9   $130.4   $119.4   Operating costs                          $20.5    $24.7    $44.0    $45.8   Depreciation and amortization             $8.5     $8.1    $16.9    $16.2   Operating income                         $37.7    $25.1    $69.4    $57.4   Equity earnings from investments          $9.2    $10.6    $29.2    $28.8   Natural gas transported (MMcf/d)         3,455    3,333    3,706    3,639   Average natural gas price     Mid-Continent region ($/MMBtu)         $9.20    $6.53    $8.19    $6.41   Capital expenditures - growth            $27.6    $25.4    $48.5    $41.8   Capital expenditures - maintenance        $2.2     $3.0     $3.5     $4.2    Natural Gas Liquids Gathering and    Fractionation   Net margin                               $67.3    $54.4   $136.9   $106.5   Operating costs                          $20.0    $16.9    $38.6    $31.6   Depreciation and amortization             $5.7     $5.8    $11.3    $11.1   Operating income                         $41.7    $31.8    $87.0    $63.8   Natural gas liquids gathered (MBbl/d)      253      224      252      217   Natural gas liquids sales (MBbl/d)         265      221      275      221   Natural gas liquids fractionated (MBbl/d)  371      349      381      334   Conway-to-Mont Belvieu OPIS average    price differential     Ethane/Propane mixture ($/gallon)      $0.13    $0.05    $0.11    $0.05   Capital expenditures - growth            $50.8    $12.2    $77.5    $17.3   Capital expenditures - maintenance        $4.2     $2.9     $7.1     $5.3    Natural Gas Liquids Pipelines   Net margin                               $27.4    $16.9    $58.7    $34.0   Operating costs                          $13.8     $5.5    $27.2    $10.9   Depreciation and amortization             $3.7     $3.0     $7.8     $6.0   Operating income                          $9.9     $8.4    $23.7    $17.0   Equity earnings from investments          $0.3     $0.4     $1.0     $0.7   Natural gas liquids transported (MBbl/d)   308      227      305      216   Natural gas liquids gathered (MBbl/d)       96       78       94       74   Capital expenditures - growth           $135.2    $64.6   $323.3    $97.3   Capital expenditures - maintenance        $1.2     $0.1     $1.8     $0.5      ONEOK Partners, L.P. and Subsidiaries   RECONCILIATION OF EBITDA NON-GAAP FINANCIAL MEASURES                                       Three Months Ended   Six Months Ended                                           June 30,            June 30,   (Unaudited)                          2008      2007      2008      2007                                              (Thousands of dollars)   Reconciliation of Net Income to    EBITDA   Net income                         $154,521   $94,619  $299,539  $190,375   Minority interests                      134        92       257       177   Interest expense, net                34,705    33,503    73,234    65,803   Depreciation and amortization        30,033    28,013    59,975    55,526   Income taxes                          4,305     1,964     7,373     4,841   Allowance for equity funds used    during construction                (11,676)   (1,658)  (20,172)   (2,995)     EBITDA                           $212,022  $156,533  $420,206  $313,727    Natural Gas Gathering and    Processing Reconciliation of    Operating Income to EBITDA   Operating income                    $76,183   $46,274  $135,236   $76,726   Depreciation and amortization        12,141    11,145    23,898    22,267   Equity earnings from investments      8,126     7,730    15,170    13,338   Other income (expense)                 (105)      (40)     (937)      203     EBITDA                            $96,345   $65,109  $173,367  $112,534    Natural Gas Pipelines    Reconciliation of Operating    Income to EBITDA   Operating income                    $37,691   $25,077   $69,405   $57,438   Depreciation and amortization         8,522     8,137    16,940    16,157   Equity earnings from investments      9,153    10,614    29,214    28,782   Other income (expense)                  (32)      (19)     (592)      228     EBITDA                            $55,334   $43,809  $114,967  $102,605    Natural Gas Liquids Gathering and    Fractionation Reconciliation of    Operating Income to EBITDA   Operating income                    $41,687   $31,787   $86,974   $63,786   Depreciation and amortization         5,668     5,754    11,287    11,086   Equity earnings from investments          -         -         -         -   Other income (expense)                 (340)     (158)   (1,070)     (267)     EBITDA                            $47,015   $37,383   $97,191   $74,605    Natural Gas Liquids Pipelines    Reconciliation of Operating    Income to EBITDA   Operating income                     $9,890    $8,412   $23,703   $17,047   Depreciation and amortization         3,697     2,991     7,839     6,003   Equity earnings from investments        331       414     1,009       693   Other income (expense)                  (26)      (42)     (450)      126     EBITDA                            $13,892   $11,775   $32,101   $23,869      ONEOK Partners, L.P. and Subsidiaries   RECONCILIATION OF DISTRIBUTABLE CASH FLOW NON-GAAP FINANCIAL MEASURES                                       Three Months Ended   Six Months Ended                                           June 30,            June 30,   (Unaudited)                          2008      2007      2008      2007                                     (Thousands of dollars, except per unit                                                    amounts)    Reconciliation of EBITDA to    Distributable Cash Flow   EBITDA                             $212,022  $156,533  $420,206  $313,727   (Gain)/loss on sale of assets             3       379       (28)   (1,824)   Interest expense                    (34,705)  (33,503)  (73,234)  (65,803)   Maintenance capital                 (12,492)  (10,216)  (20,418)  (16,850)   Distributions to minority    interests                              (74)      (73)     (148)      (73)   Equity earnings from investments    (17,610)  (18,758)  (45,393)  (42,813)   Distributions received from    unconsolidated affiliates           33,214    30,611    60,627    57,066   Current income tax expense and    other                               (3,456)   (3,022)   (5,829)   (4,496)     Distributable Cash Flow          $176,902  $121,951  $335,783  $238,934     Distributions to General Partner    (20,920)  (14,099)  (40,022)  (27,369)   Distributable Cash Flow to Limited    Partners                          $155,982  $107,852  $295,761  $211,565    Distributable Cash Flow per    Limited Partner Unit                 $1.72     $1.30     $3.37     $2.55    Number of Units Used in    Computation (Thousands)             90,906    82,891    87,680    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         $269        $217         $52     Natural Gas Pipelines                       142         110          32     Natural Gas Liquids Gathering &      Fractionation                              153         105          48     Natural Gas Liquids Pipelines                68          92         (24)     Other                                        (8)         (3)         (5)   Operating Income                              624         521         103   Equity earnings from investments               81          90          (9)   Other income (expense)                         42          35           7   Interest expense                             (161)       (182)         21   Income taxes and other                        (15)         (7)         (8)   Net Income                                   $571        $457        $114     Net Income Per Unit                         $5.40       $4.35       $1.05    Number of Units Used in Computation    (Millions)                                  89.3        86.5         2.8     Capital Expenditures      Natural Gas Gathering & Processing         $150        $105         $45     Natural Gas Pipelines                       245         216          29     Natural Gas Liquids Gathering &      Fractionation                              172         128          44     Natural Gas Liquids Pipelines               747         496         251   Total Capital Expenditures                 $1,314        $945        $369    Growth                                     $1,230        $854        $376   Maintenance                                    84          91          (7)   Total Capital Expenditures                 $1,314        $945        $369    *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                                  $571        $457        $114   Interest expense                             161         182         (21)   Depreciation and amortization                132         142         (10)   Income taxes and other                        15           7           8   Equity AFUDC                                 (41)        (33)         (8)     EBITDA                                    $838        $755         $83    Reconciliation of EBITDA to Distributable    Cash Flow   EBITDA                                      $838        $755         $83   Interest expense                            (161)       (182)         21   Maintenance capital                          (84)        (91)          7   Equity earnings from investments             (81)        (90)          9   Distributions received from investments      105         111          (6)   Current income tax expense and other         (12)         (3)         (9)     Distributable Cash Flow                   $605        $500        $105    *Amounts shown are midpoints of ranges provided.  

ONEOK Partners, L.P.

CONTACT: Analysts, Christy Williamson, +1-918-588-7163, or Media, TomDroege, +1-918-588-7561, both of ONEOK Partners, L.P.

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




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