The Williams Companies, Inc. (WMB) 8-K Williams Reports Fourth-Quarter and Full-Year 2008 Financial Results

Exhibit 99.1

News Release

NYSE: WMB

Date:     Feb. 19, 2009

Williams Reports Fourth-Quarter and Full-Year 2008 Financial Results

• ’08 Net Income Rises 43% to $1,418 Million, $2.40 EPS

• Recurring Adjusted EPS Up 24% to $2.15 for the Year

• ’08 U.S. Natural Gas Production Climbs 20%; Proved Reserves Rise 200 Bcfe to 4.5 Tcfe

• 4Q Results and ’09 Outlook Hit by Steep Decline in Commodity Prices

• Company Cuts Expected ’09 Capital Expenditures by $650 Million on Expectation of Sharply Lower Energy Prices

• Company Decides Current Structure Best to Manage Risk, Create Value

• Financial Condition Remains Strong, Company Poised to Benefit Upon Economic Recovery

Year-End Summary Financial Information	2008						2007
Per share amounts are reported on a fully diluted basis	millions			per share			millions		per share
Income from continuing operations	$	1,334		$	2.26		$	847	$	1.40
Income from discontinued operations		84			0.14			143		0.23
Net income	$	1,418		$	2.40		$	990	$	1.63
Recurring income from continuing operations*	$	1,318		$	2.23		$	873	$	1.44
After-tax mark-to-market adjustments		(47	)		(0.08	)		178		0.29
Recurring income from continuing operations — after mark-to-market adjustments*	$	1,271		$	2.15		$	1,051	$	1.73

Quarterly Summary Financial Information	4Q 2008						4Q 2007
Per share amounts are reported on a fully diluted basis	millions			per share			millions		per share
Income from continuing operations	$	130		$	0.23		$	206	$	0.34
Income (loss) from discontinued operations		(15	)		(0.03	)		19		0.03
Net income	$	115		$	0.20		$	225	$	0.37
Recurring income from continuing operations*	$	208		$	0.35		$	267	$	0.44
After-tax mark-to-market adjustments		(16	)		(0.02	)		91		0.15
Recurring income from continuing operations — after mark-to-market adjustments*	$	192		$	0.33		$	358	$	0.59

* A schedule reconciling income from continuing operations to recurring income from continuing operations and mark-to-market adjustments (non-GAAP measures) is available at www.williams.com and as an attachment to this press release.

     TULSA, Okla. – Williams (NYSE:WMB) announced 2008 unaudited net income of $1,418 million, or $2.40 per share on a diluted basis, compared with net income of $990 million, or $1.63 cents per share on a

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 1 of 11

diluted basis for 2007.

     Strong performance in Williams’ exploration and production and gas pipeline businesses drove the improved results. In 2008, the company received higher net realized average prices for its natural gas production and produced more; both factors contributed to the increased income. Another driver of the improved results was the absence in 2008 of the significant level of mark-to-market losses in Gas Marketing the previous year.

     While the full-year 2008 results are favorable compared with 2007, the sharp decline in energy commodity prices during the fourth quarter had a negative effect on results in the Exploration & Production and Midstream businesses. Results for both business segments in the last quarter of 2008 were significantly lower than the same period in 2007. There is more detail on the effect to each business in their respective sections of this news release.

     Strong earnings from Gas Pipeline partially offset the negative effect of declining energy commodity prices. Gas Pipeline benefited from a full year of higher rates on the Transco system that went into effect early in 2007 and from the nature of its contracts, which are insulated from near-term commodity price volatility. Other factors that served to mitigate the effect of falling commodity prices include Exploration & Production’s hedge positions, which cover a significant portion of its production, and fee-based revenues from certain of Midstream’s gathering and processing services. The results also benefited from a reduction in the company’s estimate of the effective deferred state tax rate during the fourth quarter.

Recurring Results Adjusted for Effect of Mark-to-Market Accounting

     Recurring income from continuing operations, after adjustments to remove the effect of mark-to-market accounting for certain hedges and other derivatives in Gas Marketing Services, was $1,271 million, or $2.15 per share for 2008. On the same adjusted basis, recurring income from continuing operations was $1,051 million, or $1.73 per share, for 2007.

     Favorable performances in Williams’ exploration and production and gas pipeline businesses drove the improved results for the year. Declining energy commodity prices led to much lower fourth-quarter results in Exploration & Production and Midstream, which partially offset these benefits.

     For fourth-quarter 2008, recurring income from continuing operations after mark-to-market adjustments was $192 million, or $0.33 per share, compared with $358 million, or $0.59 per share for fourth-quarter 2007.

     Reduced segment profit in Exploration & Production and Midstream was the key driver of the lower recurring adjusted results in the fourth quarter. The less favorable energy commodity environment during the 2008 period was a key factor in the reduction.

     A reconciliation of the company’s income from continuing operations to recurring income from continuing operations and mark-to-market adjustments is available atwww.williams.com and as an attachment to this news release.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 2 of 11

2009 Outlook Down on Expected Very Low Commodity Prices

     Williams has updated its outlook for commodity price assumptions and its earnings, cash flow and capital expenditure outlook for 2009. The table below illustrates the economic recession-driven downward movement in the company’s expectation for energy commodity prices and the corresponding effect on its results. Presented for comparison are the company’s expectations as of Nov. 6 when it reported third-quarter results, its current expectations, and actuals from 2008.

	2009 Assumptions		2009 Assumptions		2008
	as of Nov. 6, 2008		as of Feb. 19, 2009		Actuals
Natural Gas (Henry Hub)	$	6.00 - $8.00	$	4.50 - $6.00	$	9.03
Crude Oil: WTI (reference only)	$	60 - $90	$	40 - $60	$	104.34
Crude-to-Natural Gas Ratio		10.0x - 11.3x		8.9x - 10.0x		11.6x
Average NGL Margins ($/gallon)	$	0.29 - $0.57	$	0.22 - $0.35	$	0.61
Capital and Investment Expenditures*	$	2,800 - $3,100	$	2,150 - $2,450	$	3,586
Cash Flow from Operations*	$	2,400 - $3,100	$	1,900 - $2,200	$	3,355
Recurring Adjusted EPS	$	1.25 - $2.05	$	0.60 - $1.10	$	2.15

* Capital and Investment Expenditures and Cash Flow from Operations are in millions of dollars.

     Guidance for consolidated segment profit includes results for Exploration & Production, Midstream and Gas Pipeline, as well as Gas Marketing and the Other segment. All consolidated segment profit and earnings per share ranges are presented on a recurring basis adjusted to remove the effect of mark-to-market accounting.

     For 2009, Williams has lowered its consolidated segment profit guidance to a range of $1,350 million to $1,925 million and earnings per share of $0.60 to $1.10. The previous ranges were $1,950 million to $2,900 million and earnings per share of $1.25 to $2.05. The updated expectations for 2009 reflect the effect of sharply lower commodity prices as well as a modestly reduced rate of natural gas production.

     Williams is reducing its previous capital expenditure guidance for 2009 by $650 million. The new range is $2,150 million to $2,450 million. The previous range was $2,800 million to $3,100 million. Williams’ total capital and investment expenditures in 2008 were $3,586 million.

     The reduction in the company’s total potential capital spending for 2009 primarily reflects the company’s expectation for lower spending in Exploration & Production, Midstream and Gas Pipeline, based on lower energy prices, a slower economy, difficult financial markets and lower expected costs.

Company Decides Current Structure Best to Manage Risk, Create Value

     Williams’ management and its board of directors today announced they have completed a review of potential structural changes to the company and determined to leave the structure unchanged.

     The company said the major factors in its decision was the sharp decline in energy commodity prices and further deterioration in the macroeconomic environment since early November when it announced the review. Maintaining the company’s investment-grade credit rating while credit markets remain difficult, as well as the

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 3 of 11

extraordinary costs, risks and lost synergies associated with a potential structure change, were other factors that contributed to the decision.

     When the company announced it was evaluating a variety of structural changes to enhance shareholder value, it said the macroeconomic environment, credit markets and energy prices would be among factors it considered. The company also stated an intention to maintain its strong credit profile and financial flexibility.

     Williams’ business mix and strong credit profile position the company to weather the challenging economic and market conditions in 2009 and benefit as the economy recovers.

     As has been its practice, Williams in the normal course of business will continue to review the benefits and feasibility of strategies designed to create shareholder value.

CEO Perspective

     “Williams delivered very strong performance in 2008, largely on the strength of the first three quarters,” said Steve Malcolm, chairman, president and chief executive officer. “Even with a fourth quarter that suffered from the effects of global economic conditions, our full-year performance still drove a 24-percent increase in adjusted earnings per share.

     “Our 2008 results demonstrate the foundation of value in our businesses. We made significant additions to our reserves while keeping our finding and development costs low and increasing domestic production by 20 percent.

     “We again realized the benefit of our business mix and our strategy to manage the anomaly in the Rockies gas market,” Malcolm said. “Our Midstream business was a buyer of low-cost Rockies natural gas and our Exploration & Production business again sold the vast majority of its Rockies production into higher-priced markets.

     “Again, we benefited from strong cash flows in the parts of our business – our gas pipelines and fee-based midstream services – that are relatively insulated from the effects of commodity price changes.

     “We are not immune from the challenges created by the global economic recession. Given the effects of very low energy commodity prices on our business, we are making adjustments designed to preserve the value-creating capability and future growth of our businesses,” Malcolm said.

     “We expect 2009 to be a challenging year in the industry, but Williams’ liquidity is strong, we have no significant debt payments until 2011 and we are making significant reduction in our capital spending to focus on those areas that best position us to prosper as the economy recovers.”

Company’s Financial Condition Remains Strong

     As of Feb. 16, 2009, Williams had approximately $1.35 billion of cash and cash equivalents and approximately $2.34 billion of available credit capacity under the company’s credit facilities.

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     Williams has no significant debt maturities until 2011 and the company’s $1.43 billion primary credit facility does not expire until May 2012. Additionally, the company has a separate credit facility that expires in 2013 that it uses to support hedging transactions for its exploration and production business. The company also has other shorter-term credit facilities that expire during 2009 and 2010 – $500 million and $700 million, respectively. Williams is rated investment grade by three of the major rating agencies.

     During 2009, the company plans to invest approximately $500 million to $800 million in excess of its expected cash flow. That excess investment will be funded using cash currently on hand as well as expected borrowings. Excluding the Exploration & Production hedging-support facility, the company expects its year-end 2009 total liquidity to be approximately $2 billion — $2.2 billion. The company also expects that it will have the ability to access capital markets, if needed. Williams plans to fund its 2010 capital spending through cash flow from operations. The company may further reduce capital spending if economic conditions and/or energy prices weaken to a substantially greater extent.

     Williams’ risk from its net credit exposure to the company’s derivative counterparties, considering master netting agreements and collateral support, was $447 million on Dec. 31. “A” rated or better counterparties represent more than 99 percent of this total.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 5 of 11

Business Segment Performance

Consolidated Segment Profit (Loss)	Year-End						4Q
Amounts in millions	2008			2007			2008			2007
Exploration & Production	$	1,260		$	756			($27	)	$	190
Midstream Gas & Liquids		963			1,072			153			367
Gas Pipeline		689			673			157			160
	$	2,912		$	2,501		$	283		$	717
Gas Marketing Services	$	3			($337	)	$	12			($177	)
Other		(3	)		(1	)		(1	)		(1	)
Consolidated Segment Profit	$	2,912		$	2,163		$	294		$	539

Recurring Consolidated Segment Profit (Loss)

After Mark-to-Market Adjustments*	Year-End						4Q
Amounts in millions	2008			2007			2008			2007
Exploration & Production	$	1,298		$	760		$	136		$	194
Midstream Gas & Liquids		926			1,071			124			374
Gas Pipeline		670			638			157			160
	$	2,894		$	2,469		$	417		$	728
Gas Marketing after MTM Adjustments		($72	)		($29	)		($14	)		($9	)
Other		(3	)		(1	)		(1	)		(1	)
Recurring Consolidated Segment Profit After Mark-to-Market Adjustments	$	2,819		$	2,439		$	402		$	718

* A schedule reconciling income from continuing operations to recurring income from continuing operations and mark-to-market adjustments (non-GAAP measures) is available at www.williams.com and as an attachment to this press release.

Exploration & Production: Strong Annual Production Growth, First Three Quarters Drive 67%

Increase in Segment Profit

     Exploration & Production includes natural gas production and development in the U.S. Rocky Mountains, San Juan Basin and Mid-Continent, and oil and gas development in South America.

     The business reported segment profit of $1,260 million for 2008, compared with segment profit of $756 million in 2007, an increase of 67 percent.

     Higher net realized average prices for the first three quarters of the year and strong growth in domestic natural gas production volumes for the year and were the primary drivers of the increased segment profit. Increased operating costs, primarily due to increased production volumes and higher well service and lease service costs, partially offset the benefits outlined above.

     The 2008 results also included a one-time gain of $148 million on the sale of certain international interests, as well as impairment charges of $143 million, primarily in the fourth quarter, related to properties

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 6 of 11

in the Arkoma Basin. The results were also negatively affected by higher operating taxes resulting from an adverse state ruling during the fourth quarter associated with prior periods.

     Increased development within the Piceance, Powder River and Fort Worth basins drove the 20 percent growth in domestic production volumes for the year. In the Piceance Basin of western Colorado – the company’s largest production area – average daily production increased 20 percent for the year. In the Powder River Basin in Wyoming, the company’s second-largest production area, average daily production increased 34 percent for the year.

Average Daily Production	Full Year
Amounts in million cubic feet equivalent of natural gas (MMcfe)	2008		2007		Growth rate
Piceance Basin		650		540		20	%
Powder River Basin		228		170		34	%
Other Basins		216		203		6	%
U.S. Interests only		1,094		913		20	%
U.S. & International Interests		1,144		960		19	%

     For fourth-quarter 2008, Exploration & Production reported a segment loss of $27 million, compared with a segment profit of $190 million in fourth-quarter 2007.

     The primary drivers of the fourth-quarter segment loss were the impairment charge and the decline in natural gas prices in the fourth quarter, which led to lower net realized average prices for U.S. production. The higher operating taxes noted above also negatively affected the fourth quarter results.

     During fourth-quarter 2008, Williams’ net realized average price for U.S. production was $4.43 per thousand cubic feet of natural gas equivalent (Mcfe), which was 12 percent lower than the $5.06 per Mcfe realized in fourth-quarter 2007.

     In a separate announcement today, Williams reported year-end 2008 domestic proved U.S. natural gas reserves of 4.34 trillion cubic feet equivalent (Tcfe), up 5 percent from year-end 2007 reserves of 4.14 Tcfe. Including its international interests, Williams had total proved natural gas and oil reserves of 4.5 Tcfe at year-end 2008 as compared to 4.3 Tcfe at year-end 2007.

     Williams’ development activities in 2008 resulted in a net addition of 602 billion cubic feet equivalent (Bcfe) in net proved reserves. Based on the higher year-end price in 2007, Williams would have realized a net addition of 714 Bcfe for 2008. Over the past three years, Williams has added approximately 2 Tcfe in domestic net reserves from drilling activity.

     In 2008, Williams replaced its U.S. wellhead production of 406 Bcfe at a rate of 148 percent. Adding back revisions of 112 Bcfe that were not recognized due to lower year- end prices in 2008, Williams would have replaced 176 percent of its U.S. wellhead production.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 7 of 11

U.S. Proved Reserves Reconciliation

Amounts in billion cubic feet equivalent of natural gas

Proved reserves Dec. 31, 2007	4,143
Acquisitions	31
Additions and revisions	571
Wellhead Production	(406	)
Proved reserves Dec. 31, 2008	4,339

     In 2008, Williams drilled 1,787 gross wells, achieving a success rate exceeding 99 percent. During the year, the company continued to be an industry leader in cost performance, as its three-year domestic average finding and developing cost was $2.57 per thousand cubic feet equivalent (Mcfe) of natural gas. Excluding 2008 acquisitions, which were heavily weighted toward unproved properties, the three-year domestic average finding and development cost was $2.32 per Mcfe of natural gas.

Midstream Gas & Liquids: Falling Commodity Prices, Hurricanes Impact 2008 Segment Profit

     Midstream provides natural gas gathering and processing, natural gas liquids (NGL) fractionation and storage services and olefins production.

     The business reported segment profit of $963 million for 2008, compared with segment profit of $1,072 million for 2007.

     The decline in segment profit for the year is primarily because of lower NGL sales volumes and margins and higher operating expenses.

     A lack of third-party NGL pipeline transportation capacity in the West Region during the third quarter and the steep decline in NGL prices in the fourth quarter were the key drivers of the lower NGL margins for the year.

     The restricted transportation capacity in the West Region resulted in reduced recovery of ethane, which reduced total sales volumes. These restrictions were alleviated during the fourth quarter when NGL volumes from the company’s Wyoming plants began flowing into the new Overland Pass NGL pipeline.

     The steep decline in NGL prices in the fourth quarter also created unfavorable ethane economics, which resulted in the temporary suspension of ethane recoveries at certain plants. This further reduced the company’s NGL sales volumes for the year.

     Two major hurricanes in the Gulf of Mexico also negatively affected sales volumes and Midstream’s full-year 2008 results. Hurricane-related disruptions not only contributed to lower sales volumes in the Gulf Region, but also intensified the NGL pipeline capacity problem in the West Region when operations were suspended at a third-party fractionation facility at Mont Belvieu, Texas. Williams estimates that the hurricane-related downtime and costs related to repairs and property insurance deductibles reduced Midstream’s 2008 segment profit by $60 million to $85 million.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 8 of 11

     Higher per-unit NGL margins and higher fee-based revenues for the year partially offset these negative impacts. More favorable commodity prices during the first half of the year drove the higher per-unit NGL margins and fee revenues were higher across all regions.

     For fourth-quarter 2008, Midstream reported segment profit of $153 million, compared with $367 million in fourth-quarter 2007. The decline in segment profit during the fourth quarter was due to the sharp decline in NGL prices and to lower NGL sales volumes as outlined above.

Gas Pipeline: New Transco Rates, Higher Gulfstream Earnings Drive Improved Segment Profit for Year

     Gas Pipeline, which primarily delivers natural gas to markets along the Eastern Seaboard, in Florida and in the Pacific Northwest, reported 2008 segment profit of $689 million, compared with $673 million for 2007.

     On a recurring basis, Gas Pipeline’s segment profit for 2008 was $670 million, compared with $638 million for 2007.

     The 5-percent improvement in recurring segment profit for the year was due to revenues from expansion projects placed in service during fourth-quarter 2007, increased revenues from new rates on the Transco system effective March 1, 2007, and increased earnings from the company’s 50 percent interest in Gulfstream Natural Gas Systems. These increases were partially offset by lower production area revenues on the Transco system and higher operating costs resulting primarily from additional project development costs.

     For fourth-quarter 2008, Gas Pipeline reported segment profit of $157 million, compared with $160 million for fourth-quarter 2007.

Gas Marketing Services: Supporting Natural Gas Businesses with Marketing, Risk Management

     Gas Marketing Services is responsible for supporting Williams’ natural gas businesses by providing marketing and risk management services. These services primarily include marketing and hedging the gas produced by Exploration & Production, and procuring fuel and shrink gas and hedging NGLs for Midstream.

     In addition, Gas Marketing manages various natural-gas related contracts, such as transportation, storage, and related hedges, and proprietary trading positions. It also provides marketing services to third-party customers and suppliers. The segment also manages certain legacy natural gas contracts and positions that previously were reported in the former power business, which have been reduced to a minimal level.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 9 of 11

Gas Marketing Recurring Segment Profit (Loss) Adjusted for Mark-to-Market Effect*

	Year-End						4Q
Amounts in millions	2008			2007			2008			2007
Segment profit (loss)	$	3			($337	)	$	12			($177	)
Nonrecurring adjustments		–			20			–			20
Recurring segment profit (loss)	$	3			($317	)	$	12			($157	)
Mark-to-market adjustments		(75	)		288			(26	)		148
Recurring segment loss after MTM adjustments		($72	)		($29	)		($14	)		($9	)

* A schedule reconciling income from continuing operations to recurring income from continuing operations and mark-to-market adjustments (non-GAAP measures) is available at www.williams.com and as an attachment to this press release.

     The $72 million recurring segment loss after mark-to-market adjustments for 2008 is comprised primarily of a $35 million write-down of storage inventory to market prices, $43 million of realized losses associated with certain legacy and proprietary positions, which were recognized in earnings in prior periods, and $20 million of general and administrative costs. These losses were offset by $34 million in realized gains associated with storage and transportation contracts.

     Although not significant for the full-year or fourth-quarter 2008 results, the company expects in the future to have some level of mark-to-market volatility in Gas Marketing Services, primarily from natural gas storage hedging.

Today’s Analyst Call

     Management will discuss the year-end 2008 results and outlook for 2009 during a live webcast beginning at 9:30 a.m. EST today. Participants are encouraged to access the webcast and corresponding slides for viewing, downloading and printing atwww.williams.com.

     A limited number of phone lines also will be available at (877) 719-9791. International callers should dial (719) 325-4808. Replays of the year-end webcast, in both streaming and downloadable podcast formats, will be available for two weeks atwww.williams.com following the event.

Form 10-K

     The company plans to file its Form 10-K with the Securities and Exchange Commission during the week of Feb. 23. The document will be available on both the SEC and Williams websites.

About Williams (NYSE: WMB)

Williams, through its subsidiaries, finds, produces, gathers, processes and transports natural gas. Williams’ operations are concentrated in the Pacific Northwest, Rocky Mountains, Gulf Coast, and Eastern Seaboard. More information is available athttp://www.williams.com. Go tohttp://www.b2i.us/irpass.asp?BzID=630&to=ea&s=0 to join our e-mail list.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 10 of 11

Contact:	Jeff Pounds
	Williams (media relations)
	(918) 573-3332
	Travis Campbell
	Williams (investor relations)
	(918) 573-2944
	Richard George
	Williams (investor relations)
	(918) 573-3679
	Sharna Reingold
	Williams (investor relations)
	(918) 573-2078

# # #

     Our reports, filings, and other public announcements may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. You typically can identify forward-looking statements by the use of forward-looking words, such as “anticipate,” believe,” “could,” “continue,” “estimate,” “expect,” “forecast,” “may,” “plan,” “potential,” “project,” “schedule,” “will,” and other similar words. These statements are based on our present intentions and our assumptions about future events and are subject to risks, uncertainties, and other factors. In addition to any assumptions, risks, uncertainties or other factors referred to specifically in connection with such statements, other factors not specifically referenced could cause our actual results to differ materially from the results expressed or implied in any forward-looking statements. Those factors include, among others:

• availability of supplies (including the uncertainties inherent in assessing, estimating, acquiring and developing future natural gas reserves), market demand, volatility of prices, and the availability and costs of capital;

• inflation, interest rates, fluctuation in foreign exchange, and general economic conditions (including the recent economic slowdown and the disruption of global credit markets and the impact of these events on our customers and suppliers);

• the strength and financial resources of our competitors;

• development of alternative energy sources;

• the impact of operational and development hazards;

• costs of, changes in, or the results of laws, government regulations (including proposed climate change legislation), environmental liabilities, litigation, and rate proceedings;

• our costs and funding obligations for defined benefit pension plans and other postretirement benefit plans;

• changes in the current geopolitical situation;

• risks related to strategy and financing, including restrictions stemming from our debt agreements and future changes in our credit ratings;

• risks associated with future weather conditions;

• acts of terrorism, and

• additional risks described in our filings with the Securities and Exchange Commission.

     Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. In addition to causing our actual results to differ, the factors listed above may cause our intentions to change. Such changes in our intentions may also cause our results to differ. We disclaim any obligation to and do not intend to publicly update or revise any forward-looking statements or changes to our intentions, whether as a result of new information, future events or otherwise.

     In regard to the company’s reserves in Exploration & Production, the SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves. We have used certain terms in this presentation such as “probable” reserves and “possible” reserves and “unrisked theoretical resource estimates” that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. The SEC defines proved reserves as estimated hydrocarbon quantities that geological and engineering data demonstrate with reasonable certainty to be recoverable in the future from known reservoirs under the assumed economic conditions. Probable and possible reserves are estimates of potential reserves that are made using accepted geological and engineering analytical techniques, but which are estimated with reduced levels of certainty than for proved reserves. Generally under such techniques, probable reserve estimates are more than 50% certain and possible reserve estimates are less than 50% but more than 10% certain. Unrisked theoretical resource estimates are even less certain than those for possible reserves and are not risk adjusted. Unrisked theoretical resource estimates include (i) an estimate of hydrocarbon quantities for new areas for which we do not have sufficient information to date to classify the resources as probable or even possible reserves and (ii) the amount by which we have reduced our probable and possible reserves for existing areas to take into account the reduced level of certainty of recovery of the resources. Unlike probable and possible reserves, unrisked theoretical resource estimates do not take into account the uncertainty of resource recovery and are therefore not indicative of the expected future recovery and should not be relied upon.

     Reference to “Resource Potential” includes proved, probable and possible reserves as well as unrisked theoretical resource estimates that might never be recoverable and are contingent on exploration success, technical improvements in drilling access, commerciality and other factors.

Williams (NYSE: WMB) Year-End 2008 Financial Results — Feb. 19, 2009 Page 11 of 11

Financial Highlights and Operating Statistics
(UNAUDITED)

Final

December 31, 2008

Reconciliation of Income from Continuing Operations to Recurring Earnings
(UNAUDITED)

	2007															2008
(Dollars in millions, except per-share amounts)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year
Income from continuing operations available to common stockholders	$	170		$	243		$	228		$	206		$	847		$	416		$	419		$	369		$	130		$	1,334
Income from continuing operations — diluted earnings per common share	$	0.28		$	0.40		$	0.38		$	0.34		$	1.40		$	0.70		$	0.70		$	0.62		$	0.23		$	2.26
Nonrecurring items:
Exploration & Production
Accrual for royalty litigation contingency	$	—		$	—		$	—		$	4		$	4		$	—		$	—		$	—		$	—		$	—
Gain on sale of Peru interests		—			—			—			—			—			(118	)		(30	)		—			—			(148	)
Reserve for receivables from bankrupt counterparty		—			—			—			—			—			—			5			4			—			9
Impairment of certain natural gas producing properties		—			—			—			—			—			—			—			14			129			143
Accrual for Wyoming severence taxes		—			—			—			—			—			—			—						34			34
Total Exploration & Production nonrecurring items		—			—			—			4			4			(118	)		(25	)		18			163			38
Gas Pipeline
Change in estimate related to a regulatory liability — NWP		—			(17	)		—			—			(17	)		—			—			—			—			—
Payments received for terminated firm transportation agreement — NWP		—			(6	)		(12	)		—			(18	)		—			—			—			—			—
Gain on sale of excess inventory gas — TGPL		—			—			—			—			—			—			(9	)		—			—			(9	)
Gain on sale of certain south Texas assets — TGPL		—			—			—			—			—			—			—			(10	)		—			(10	)
Total Gas Pipeline nonrecurring items		—			(23	)		(12	)		—			(35	)		—			(9	)		(10	)		—			(19	)
Midstream Gas & Liquids
Reversal of a maintenance accrual		(8	)		—			—			—			(8	)		—			—			—			—			—
Income from a favorable litigation outcome		—			—			—			(12	)		(12	)		—			—			—			—			—
Reserve for international receivables		—			—			—			9			9			—			—			—			—			—
Impairment of Carbonate Trend pipeline		—			—			—			10			10			—			—			—			6			6
Involuntary conversion gain related to Ignacio gas processing plant		—			—			—			—			—			—			(3	)		(6	)		(3	)		(12	)
Reserve for receivables from bankrupt counterparty		—			—			—			—			—			—			1			—			—			1
Final earnout payment from 2005 Gulf Liquids asset sale		—			—			—			—			—			—			—			(8	)		—			(8	)
Charges from Hurricanes Gustav & Ike		—			—			—			—			—			—			—			8			5			13
Involuntary conversion gain from hurricane damage at Cameron		—			—			—			—			—			—			—			—			(5	)		(5	)
Gulf Liquids litigation partial settlement		—			—			—			—			—			—			—			—			(32	)		(32	)
Total Midstream Gas & Liquids nonrecurring items		(8	)		—			—			7			(1	)		—			(2	)		(6	)		(29	)		(37	)
Gas Marketing Services
Accrual for litigation contingencies		—			—			—			20			20			—			—			—			—			—
Total Gas Marketing Services nonrecurring items		—			—			—			20			20			—			—			—			—			—
Nonrecurring items included in segment profit (loss)		(8	)		(23	)		(12	)		31			(12	)		(118	)		(36	)		2			134			(18	)
Nonrecurring items below segment profit (loss)
Early debt retirement costs (Corporate)		—			—			—			19			19			—			—			—			—			—
Interest related to Gulf Liquids litigation contingency ( Interest accrued — Midstream)		1			1			1			—			3			—			—			—			(11	)		(11	)
Interest income related to contract termination gain noted above (Investing income — Gas Pipeline — NWP)		—			—			(2	)		—			(2	)		—			—			—			—			—
Interest related to royalty litigation contingency noted above (Interest accrued — E&P)		—			—			—			1			1			—			—			—			—			—
Interest related to Wyoming severance tax audit noted above (Interest accrued — E&P)		—			—			—			—			—			—			—			—			4			4
Rounding		—			1			(1	)		—			—			—			—			—			—			—
		1			2			(2	)		20			21			—			—			—			(7	)		(7	)
Total nonrecurring items		(7	)		(21	)		(14	)		51			9			(118	)		(36	)		2			127			(25	)
Tax effect for above items(1)(2)		(3	)		1			(5	)		13			6			(45	)		(14	)		1			49			(9	)
Adjustment for nonrecurring tax-related items(3)		—			—			—			23			23			—			—			—			—			—
Recurring income from continuing operations available to common stockholders	$	166		$	221		$	219		$	267		$	873		$	343		$	397		$	370		$	208		$	1,318
Recurring diluted earnings per common share	$	0.27		$	0.36		$	0.36		$	0.44		$	1.44		$	0.57		$	0.67		$	0.63		$	0.35		$	2.23
Weighted-average shares — diluted (thousands)		611,470			613,172			610,651			604,243			609,866			598,627			596,187			589,138			587,057			592,719

(1)	The tax rate applied to nonrecurring items for 2nd quarter 2007 has been adjusted to reverse the effect of certain previous adjustments for nondeductible expenses associated with securities litigiation and related costs, as these expenses are now considered deductible based on an IRS ruling.
(2)	The tax rate applied to nonrecurring items 4th quarter 2007 has been adjusted to reverse the effect of early debt retirement costs considered deductible in 2004 as these expenses are now considered nondeductible.
(3)	The 4th quarter of 2007 includes an adjustment for an income tax contingency.

Note:	The sum of earnings per share for the quarters may not equal the total earnings per share for the year due to changes in the weighted-average number of common shares outstanding.
	The sum of amounts for the quarters may not equal the totals for the year due to rounding.

Consolidated Statement of Income
(UNAUDITED)

	2007															2008
(Dollars in millions, except per-share amounts)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year
Revenues(1)	$	2,348		$	2,805		$	2,844		$	2,489		$	10,486		$	3,204		$	3,701		$	3,245		$	2,202		$	12,352
Segment costs and expenses:
Costs and operating expenses(1)		1,823			2,161			2,206			1,817			8,007			2,353			2,719			2,364			1,720			9,156
Selling, general and administrative expenses		102			108			107			154			471			111			131			133			129			504
Other (income) expense-net		(18	)		(18	)		(2	)		20			(18	)		(117	)		(35	)		—			70			(82	)
Total segment costs and expenses		1,907			2,251			2,311			1,991			8,460			2,347			2,815			2,497			1,919			9,578
Equity earnings		21			23			52			41			137			36			37			54			10			137
Income from investments		—			—			—			—			—			—			—			—			1			1
Total segment profit		462			577			585			539			2,163			893			923			802			294			2,912
Reclass equity earnings		(21	)		(23	)		(52	)		(41	)		(137	)		(36	)		(37	)		(54	)		(10	)		(137	)
Reclass income from investments		—			—			—			—			—			—			—			—			(1	)		(1	)
General corporate expenses		(40	)		(36	)		(40	)		(45	)		(161	)		(42	)		(42	)		(34	)		(31	)		(149	)
Operating income		401			518			493			453			1,865			815			844			714			252			2,625
Interest accrued		(172	)		(172	)		(171	)		(170	)		(685	)		(165	)		(165	)		(166	)		(157	)		(653	)
Interest capitalized		5			7			9			11			32			8			16			16			19			59
Investing income		52			66			78			61			257			55			55			65			16			191
Early debt retirement costs		—			—			—			(19	)		(19	)		—			—			—			(1	)		(1	)
Minority interest in income of consolidated subsidiaries		(14	)		(25	)		(29	)		(22	)		(90	)		(39	)		(63	)		(55	)		(17	)		(174	)
Other income (expense) — net		2			2			8			(1	)		11			5			—			2			(7	)		—
Income from continuing operations before income taxes		274			396			388			313			1,371			679			687			576			105			2,047
Provision (benefit) for income taxes		104			153			160			107			524			263			268			207			(25	)		713
Income from continuing operations		170			243			228			206			847			416			419			369			130			1,334
Income (loss) from discontinued operations		(36	)		190			(30	)		19			143			84			18			(3	)		(15	)		84
Net income	$	134		$	433		$	198		$	225		$	990		$	500		$	437		$	366		$	115		$	1,418
Diluted earnings (loss) per common share:
Income from continuing operations	$	0.28		$	0.40		$	0.38		$	0.34		$	1.40		$	0.70		$	0.70		$	0.62		$	0.23		$	2.26
Income (loss) from discontinued operations		(0.06	)		0.31			(0.05	)		0.03			0.23			0.14			0.03			—			(0.03	)		0.14
Net income	$	0.22		$	0.71		$	0.33		$	0.37		$	1.63		$	0.84		$	0.73		$	0.62		$	0.20		$	2.40
Weighted-average number of shares used in computation (thousands)		611,470			613,172			610,651			604,243			609,866			598,627			596,187			589,138			587,057			592,719
Common shares outstanding at end of period (thousands)		598,492			599,781			593,016			586,148			586,148			584,025			579,117			578,641			579,052			579,052
Market price per common share (end of period)	$	28.46		$	31.62		$	34.06		$	35.78		$	35.78		$	32.98		$	40.31		$	23.65		$	14.48		$	14.48
Common dividends per share	$	0.09		$	0.10		$	0.10		$	0.10		$	0.39		$	0.10		$	0.11		$	0.11		$	0.11		$	0.43

Note:	The sum of earnings (loss) per share for the quarters may not equal the total earnings (loss) per share for the year due to changes in the weighted-average number of common shares outstanding.
(1)	Prior period amounts reported for Exploration & Production have been adjusted to reflect the presentation of certain revenues and costs on a net basis. These adjustments reducedrevenuesand reducedcosts and operating expenses by the same amount, with no net impact on segment profit.

2

Reconciliation of Segment Profit to Recurring Segment Profit
(UNAUDITED)

	2007															2008
(Dollars in millions)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year
Segment profit (loss):
Exploration & Production	$	188		$	209		$	169		$	190		$	756		$	430		$	496		$	361		$	(27	)	$	1,260
Gas Pipeline		150			180			183			160			673			180			179			173			157			689
Midstream Gas & Liquids		154			251			300			367			1,072			261			295			254			153			963
Gas Marketing Services		(30	)		(63	)		(67	)		(177	)		(337	)		21			(46	)		16			12			3
Other		—			—			—			(1	)		(1	)		1			(1	)		(2	)		(1	)		(3	)
Total segment profit	$	462		$	577		$	585		$	539		$	2,163		$	893		$	923		$	802		$	294		$	2,912
Nonrecurring adjustments:
Exploration & Production	$	—		$	—		$	—		$	4		$	4		$	(118	)	$	(25	)	$	18		$	163		$	38
Gas Pipeline		—			(23	)		(12	)		—			(35	)		—			(9	)		(10	)		—			(19	)
Midstream Gas & Liquids		(8	)		—			—			7			(1	)		—			(2	)		(6	)		(29	)		(37	)
Gas Marketing Services		—			—			—			20			20			—			—			—			—			—
Other		—			—			—			—			—			—			—			—			—			—
Total segment nonrecurring adjustments	$	(8	)	$	(23	)	$	(12	)	$	31		$	(12	)	$	(118	)	$	(36	)	$	2		$	134		$	(18	)
Recurring segment profit (loss):
Exploration & Production	$	188		$	209		$	169		$	194		$	760		$	312		$	471		$	379		$	136		$	1,298
Gas Pipeline		150			157			171			160			638			180			170			163			157			670
Midstream Gas & Liquids		146			251			300			374			1,071			261			293			248			124			926
Gas Marketing Services		(30	)		(63	)		(67	)		(157	)		(317	)		21			(46	)		16			12			3
Other		—			—			—			(1	)		(1	)		1			(1	)		(2	)		(1	)		(3	)
Total recurring segment profit	$	454		$	554		$	573		$	570		$	2,151		$	775		$	887		$	804		$	428		$	2,894

Note: Segment profit (loss) includes equity earnings and income from investments reported in Investing income in the Consolidated Statement of Income. Equity earnings results from investments accounted for under the equity method. Income from investments results from the management of certain equity investments.

3

Exploration & Production
(UNAUDITED)

	2007															2008
(Dollars in millions)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr		4th Qtr			Year
Revenues:
Production	$	413		$	449		$	399		$	464		$	1,725		$	617		$	826		$	715	$	486		$	2,644
Gas management (1)		36			48			48			72			204			86			106			95		68			355
Net nonqualified hedge derivative income (loss)		(2	)		(5	)		8			(17	)		(16	)		(2	)		(14	)		18		(1	)		1
International		15			16			16			17			64			17			19			18		18			72
Other		1			12			12			19			44			10			11			15		13			49
Total revenues		463			520			483			555			2,021			728			948			861		584			3,121
Segment costs and expenses:
Depreciation, depletion and amortization (including International)		114			131			139			151			535			166			182			187		202			737
Lease and other operating expenses		44			49			54			58			205			60			61			72		73			266
Operating taxes		34			35			30			22			121			49			69			65		56			239
Exploration expense		7			5			4			4			20			2			1			3		21			27
Third party gathering expense		9			7			9			8			33			10			13			12		15			50
Selling, general and administrative expenses (including International)		36			32			35			45			148			37			44			49		46			176
Gas management expenses (1)		35			48			47			70			200			84			105			94		65			348
International (excluding DD&A and SG&A)		4			6			7			7			24			6			10			9		11			36
Other (income) expense — net		(3	)		3			(1	)		5			4			(113	)		(27	)		14		128			2
Total segment costs and expenses		280			316			324			370			1,290			301			458			505		617			1,881
Equity earnings		5			5			10			5			25			3			6			5		6			20
Reported segment profit		188			209			169			190			756			430			496			361		(27	)		1,260
Nonrecurring adjustments		—			—			—			4			4			(118	)		(25	)		18		163			38
Recurring segment profit	$	188		$	209		$	169		$	194		$	760		$	312		$	471		$	379	$	136		$	1,298
Operating statistics
Domestic:
Total domestic net volumes (Bcfe)		76.1			81.7			85.2			90.1			333.1			92.2			101.0			100.8		106.4			400.4
Net domestic volumes per day (MMcfe/d)		845			898			926			979			913			1,013			1,110			1,096		1,156			1,094
Net domestic realized price ($/Mcfe) (2)	$	5.318		$	5.390		$	4.587		$	5.057		$	5.078		$	6.580		$	8.056		$	6.971	$	4.428		$	6.479
Production taxes per Mcfe	$	0.440		$	0.439		$	0.343		$	0.253		$	0.364		$	0.529		$	0.683		$	0.648	$	0.525		$	0.597
Lease and other operating expense per Mcfe	$	0.574		$	0.598		$	0.639		$	0.645		$	0.616		$	0.653		$	0.606		$	0.712	$	0.685		$	0.664
(2) Net realized price is calculated the following way:production revenues(including hedging activities and incremental margins related to gas management activities) lessthird party gathering expensedivided by net volumes.
International:
Total volumes including Equity Investee (Bcfe)		5.2			5.4			5.6			5.8			22.0			5.7			5.7			5.9		6.0			23.3
Volumes per day (MMcfe/d)		58			59			61			63			60			63			62			64		66			64
Volumes net to Williams (after minority interest) (Bcfe)		4.1			4.2			4.4			4.6			17.3			4.5			4.4			4.6		4.8			18.3
Volumes net to Williams per day (MMcfe/d)		46			46			48			50			47			49			49			50		52			50
Total Domestic and International:
Volumes net to Williams (after minority interest) (Bcfe)		80.2			85.9			89.7			94.6			350.4			96.7			105.4			105.4		111.2			418.7
Volumes net to Williams per day (MMcfe/d)		891			945			974			1,028			960			1,062			1,159			1,146		1,208			1,144

(1) Prior period amounts reported for Exploration & Production have been adjusted to reflect the presentation of certain revenues and costs on a net basis. These adjustments reducedrevenues and reducedcosts and operating expensesby the same amount, with no net impact on segment profit.

4

Gas Pipeline
(UNAUDITED)

	2007													2008
(Dollars in millions)	1st Qtr		2nd Qtr			3rd Qtr			4th Qtr		Year			1st Qtr		2nd Qtr			3rd Qtr			4th Qtr		Year
Revenues:
Northwest Pipeline	$	103	$	103		$	106		$	110	$	422		$	107	$	107		$	108		$	113	$	435
Transcontinental Gas Pipe Line		268		312			286			321		1,187			306		298			300			295		1,199
Other		—		—			—			1		1			—		1			(1	)		—		—
Total revenues		371		415			392			432		1,610			413		406			407			408		1,634
Segment costs and expenses:
Costs and operating expenses		195		224			203			229		851			201		207			210			222		840
Selling, general and administrative expenses		35		38			37			51		161			36		40			42			39		157
Other (income) expense — net		—		(17	)		(10	)		3		(24	)		6		(5	)		3			3		7
Total segment costs and expenses		230		245			230			283		988			243		242			255			264		1,004
Equity earnings		9		10			21			11		51			10		15			21			13		59
Reported segment profit:
Northwest Pipeline		55		75	*		66			52		248			53		52			56			57		218
Transcontinental Gas Pipe Line		87		98			97			101		383			122		120			108			93		443
Other		8		7			20			7		42			5		7			9			7		28
Total reported segment profit		150		180			183			160		673			180		179			173			157		689
Nonrecurring adjustments:
Northwest Pipeline		—		(23)	*		(12	)		—		(35	)		—		—			—			—		—
Transcontinental Gas Pipe Line		—		—			—			—		—			—		(9	)		(10	)		—		(19	)
Total nonrecurring adjustments		—		(23	)		(12	)		—		(35	)		—		(9	)		(10	)		—		(19	)
Recurring segment profit:
Northwest Pipeline		55		52			54			52		213			53		52			56			57		218
Transcontinental Gas Pipe Line		87		98			97			101		383			122		111			98			93		424
Other		8		7			20			7		42			5		7			9			7		28
Total recurring segment profit	$	150	$	157		$	171		$	160	$	638		$	180	$	170		$	163		$	157	$	670

* Includes $6 million of income associated with payments received for a terminated firm transportation agreement on Gas Pipeline’s Grays Harbor lateral that was reclassified fromother income — netbelowoperating incometoother (income) expense — net withinsegment costs and expenses.

Operating statistics
Northwest Pipeline
Throughput (TBtu)	200.2	159.8	176.5	220.4	756.9	219.8	171.0	179.5	211.1	781.4
Average daily transportation volumes (TBtu)	2.2	1.8	1.9	2.4	2.1	2.4	1.9	2.0	2.3	2.1
Average daily firm reserved capacity (TBtu)	2.5	2.5	2.5	2.6	2.5	2.6	2.5	2.5	2.5	2.5
Transcontinental Gas Pipe Line
Throughput (TBtu)	525.2	427.6	477.4	473.2	1,903.4	536.5	443.0	448.5	482.4	1,910.4
Average daily transportation volumes (TBtu)	5.8	4.7	5.2	5.1	5.2	5.9	4.9	4.9	5.2	5.2
Average daily firm reserved capacity (TBtu)	6.8	6.4	6.4	6.7	6.6	7.0	6.7	6.6	6.8	6.8

5

Midstream Gas & Liquids
(UNAUDITED)

	2007															2008
(Dollars in millions)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr				4th Qtr			Year
Revenues:
Gathering & processing	$	104		$	102		$	106		$	102		$	414		$	97		$	108		$	105			$	104		$	414
Venezuela fee revenue		37			38			38			35			148			40			44			43				39			166
NGL sales from gas processing		260			319			346			435			1,360			383			473			397				270			1,523
Production handling and transportation		29			28			26			25			108			27			29			24				28			108
Olefins sales (including Gulf and Canada)		131			176			287			321			915			325			335			319				146			1,125
Marketing sales		792			1,007			1,063			1,297			4,159			1,178			1,372			1,094				533			4,177
Other revenues		33			40			31			33			137			51			57			50				58			216
		1,386			1,710			1,897			2,248			7,241			2,101			2,418			2,032				1,178			7,729
Intrasegment eliminations		(384	)		(467	)		(537	)		(673	)		(2,061	)		(544	)		(664	)		(596	)			(283	)		(2,087	)
Total revenues		1,002			1,243			1,360			1,575			5,180			1,557			1,754			1,436				895			5,642
Segment costs and expenses:
NGL cost of goods sold		166			149			124			140			579			187			286			196				101			770
Olefins cost of goods sold		114			147			239			267			767			280			279			288				132			979
Marketing cost of goods sold		787			996			1,058			1,285			4,126			1,180			1,357			1,118				615			4,270
Venezuela operating costs		19			19			20			20			78			21			22			20				23			86
Operating costs		141			128			139			146			554			168			157			165				172			662
Other
Selling, general and administrative expenses		27			29			32			49			137			34			39			36				35			144
Other (income) expense — net		(15	)		(1	)		6			(1	)		(11	)		(7	)		(1	)		(17	)			(61	)		(86	)
Intrasegment eliminations		(384	)		(467	)		(537	)		(673	)		(2,061	)		(544	)		(664	)		(596	)			(283	)		(2,087	)
Total segment costs and expenses		855			1,000			1,081			1,233			4,169			1,319			1,475			1,210				734			4,738
Equity earnings		7			8			21			25			61			23			16			28				(9	)		58
Income from investments		—			—			—			—			—			—			—			—				1			1
Reported segment profit		154			251			300			367			1,072			261			295			254				153			963
Nonrecurring adjustments		(8	)		—			—			7			(1	)		—			(2	)		(6	)			(29	)		(37	)
Recurring segment profit	$	146		$	251		$	300		$	374		$	1,071		$	261		$	293		$	248			$	124		$	926
Operating statistics
Domestic Gathering and Processing
Gathering volumes (TBtu)		269			259			266			251			1,045			234			268			254		��		257			1,013
Plant inlet natural gas volumes (TBtu)		316			316			325			318			1,275			325			337			328				321			1,311
NGL equity sales (million gallons) *		345			359			358			356			1,418			308			366			272				285			1,231
NGL margin ($/gallon)	$	0.27		$	0.47		$	0.62		$	0.83		$	0.55		$	0.64		$	0.51		$	0.74			$	0.59		$	0.61
NGL production (million gallons) *		594			619			640			642			2,495			634			645			555				538			2,372
Olefins
Canadian NGL equity sales (million gallons)		35			33			35			33			136			33			22			20				37			112
Olefins sales (Ethylene & Propylene) (million lbs)		213			274			473			441			1,401			457			428			407				313			1,605
Discovery Producer Services L.L.C. (equity investment) - 100%
NGL equity sales (million gallons)		18			25			22			34			99			37			23			21				4			85
NGL production (million gallons)		56			66			61			69			252			70			58			43				10			181

* Excludes volumes associated with partially owned assets that are not consolidated for financial reporting purposes.

6

Gas Marketing Services
(UNAUDITED)

	2007															2008
(Dollars in millions)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr		2nd Qtr			3rd Qtr		4th Qtr		Year
Revenues	$	1,288		$	1,394		$	1,247		$	704		$	4,633		$	1,650	$	2,010		$	1,716	$	1,036	$	6,412
Segment costs and expenses:
Costs and operating expenses		1,316			1,452			1,312			857			4,937			1,625		2,049			1,695		1,019		6,388
Selling, general and administrative expenses		2			5			2			4			13			4		7			4		5		20
Other expense — net		—			—			—			20			20			—		—			1		—		1
Total segment costs and expenses		1,318			1,457			1,314			881			4,970			1,629		2,056			1,700		1,024		6,409
Reported segment profit (loss)		(30	)		(63	)		(67	)		(177	)		(337	)		21		(46	)		16		12		3
Nonrecurring adjustments		—			—			—			20			20			—		—			—		—		—
Recurring segment profit (loss)	$	(30	)	$	(63	)	$	(67	)	$	(157	)	$	(317	)	$	21	$	(46	)	$	16	$	12	$	3

7

Capital Expenditures and Investments
(UNAUDITED)

	2007												2008
(Dollars in millions)	1st Qtr		2nd Qtr		3rd Qtr			4th Qtr		Year			1st Qtr		2nd Qtr			3rd Qtr			4th Qtr			Year
Capital expenditures:
Exploration & Production	$	343	$	386	$	467		$	495	$	1,691		$	391	$	711		$	800		$	617		$	2,519
Gas Pipeline:
Northwest Pipeline		49		21		37			52		159			13		16			29			21			79
Transcontinental Gas Pipe Line		59		119		139			43		360			53		43			53			78			227
Other		—		—		—			—		—			1		(1	)		—			—			—
Total		108		140		176			95		519			67		58			82			99			306
Midstream Gas & Liquids		55		185		227			120		587			105		205			141			157			608
Gas Marketing Services		—		—		—			—		—			—		—			1			—			1
Other		4		6		4			5		19			16		8			8			9			41
Total	$	510	$	717	$	874		$	715	$	2,816		$	579	$	982		$	1,032		$	882		$	3,475
Purchase of investments:
Exploration & Production		—		—		(2	)		—		(2	)		—		3			3			(3	)		3
Gas Pipeline		1		3		15			23		42			20		28			36			8			92
Other		19		1		—			—		20			—		16			(1	)		1			16
Total	$	20	$	4	$	13		$	23	$	60		$	20	$	47		$	38		$	6		$	111
Summary:
Exploration & Production	$	343	$	386	$	465		$	495	$	1,689		$	391	$	714		$	803		$	614		$	2,522
Gas Pipeline		109		143		191			118		561			87		86			118			107			398
Midstream Gas & Liquids		55		185		227			120		587			105		205			141			157			608
Gas Marketing Services		—		—		—			—		—			—		—			1			—			1
Other		23		7		4			5		39			16		24			7			10			57
Total	$	530	$	721	$	887		$	738	$	2,876		$	599	$	1,029		$	1,070		$	888		$	3,586
Cumulative summary:
Exploration & Production	$	343	$	729	$	1,194		$	1,689	$	1,689		$	391	$	1,105		$	1,908		$	2,522		$	2,522
Gas Pipeline		109		252		443			561		561			87		173			291			398			398
Midstream Gas & Liquids		55		240		467			587		587			105		310			451			608			608
Gas Marketing Services		—		—		—			—		—			—		—			1			1			1
Other		23		30		34			39		39			16		40			47			57			57
Total	$	530	$	1,251	$	2,138		$	2,876	$	2,876		$	599	$	1,628		$	2,698		$	3,586		$	3,586

8

Depreciation, Depletion and Amortization and Other Selected Financial Data

(UNAUDITED)

	2007															2008
(Dollars in millions)	1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year			1st Qtr			2nd Qtr			3rd Qtr			4th Qtr			Year
Depreciation, depletion and amortization:
Exploration & Production	$	114		$	131		$	139		$	151		$	535		$	165		$	180		$	190		$	202		$	737
Gas Pipeline:
Northwest Pipeline		23			22			21			22			88			22			21			21			22			86
Transcontinental Gas Pipe Line		54			58			58			57			227			55			59			59			62			235
Total		77			80			79			79			315			77			80			80			84			321
Midstream Gas & Liquids		53			54			52			55			214			55			55			58			65			233
Gas Marketing Services		1			1			2			3			7			1			—			—			—			1
Other		3			3			3			1			10			4			3			5			6			18
Total	$	248		$	269		$	275		$	289		$	1,081		$	302		$	318		$	333		$	357		$	1,310
Other selected financial data:
Cash and cash equivalents	$	1,811		$	1,739		$	1,455		$	1,699		$	1,699		$	2,240		$	1,937		$	1,524		$	1,439		$	1,439
Total assets	$	25,936		$	26,046		$	25,837		$	25,061		$	25,061		$	27,172		$	31,216		$	26,893		$	26,006		$	26,006
Capital structure:
Debt
Current	$	388		$	468		$	466		$	143		$	143		$	85		$	83		$	84		$	196		$	196
Noncurrent	$	7,507		$	7,443		$	7,425		$	7,757		$	7,757		$	7,799		$	7,869		$	7,827		$	7,683		$	7,683
Stockholders’ equity	$	6,192		$	6,423		$	6,456		$	6,375		$	6,375		$	7,801		$	7,652		$	8,574		$	8,440		$	8,440
Debt to debt-plus-equity ratio		56.0	%		55.2	%		55.0	%		55.3	%		55.3	%		50.3	%		51.0	%		48.0	%		48.3	%		48.3	%

9

Adjustment to remove MTM effect

Dollars in millions except for per share amounts

	4th Quarter						YTD
	2008			2007			2008			2007
Recurring income from cont. ops available to common shareholders	$	208		$	267		$	1,318		$	873
Recurring diluted earnings per common share	$	0.35		$	0.44		$	2.23		$	1.44
Mark-to-Market (MTM) adjustments for Gas Marketing		(26	)		148			(75	)		288
Tax effect of total MTM adjustments		10			(57	)		28			(110	)
After tax MTM adjustments	$	(16	)	$	91		$	(47	)	$	178
Recurring income from cont. ops available to common shareholders after MTM adjust.	$	192		$	358		$	1,271		$	1,051
Recurring diluted earnings per share after MTM adj.	$	0.33		$	0.59		$	2.15		$	1.73
weighted average shares — diluted (thousands)		587,057			604,243			592,719			609,866

Adjustments have been made to reverse estimated forward unrealized MTM gains/losses and add estimated realized gains/losses from MTM previously recognized, i.e. assumes MTM accounting had never been applied to designated hedges and other derivatives.

Some annual figures may differ from sum of quarterly figures due to rounding.

Non-GAAP Measures:

     This press release includes certain financial measures, recurring earnings and recurring segment profit that are non-GAAP financial measures as defined under the rules of the Securities and Exchange Commission. Recurring earnings exclude items of income or loss that the company characterizes as unrepresentative of its ongoing operations. Recurring earnings and recurring segment profit provide investors meaningful insight into the company’s results from ongoing operations. This press release is accompanied by a reconciliation of these non-GAAP financial measures to their nearest GAAP financial measures. Management uses these financial measures because they are widely accepted financial indicators used by investors to compare a company’s performance. In addition, management believes that these measures provide investors an enhanced perspective of the operating performance of the company. Neither recurring earnings nor recurring segment profit are intended to represent an alternative to net income or segment profit. They should not be considered in isolation or as substitutes for a measure of performance prepared in accordance with United States generally accepted accounting principles.

     Certain financial information in this press release is also shown including Gas Marketing Services mark-to-market adjustments. This press release is accompanied by a reconciliation of these non-GAAP financial measures to their nearest GAAP financial measures. Management uses the mark-to-market adjustments to better reflect Gas Marketing’s results on a basis that is more consistent with Gas Marketing’s portfolio cash flows and to aid investor understanding. The adjustments reverse forward unrealized mark-to-market gains or losses from derivatives and add realized gains or losses from derivatives for which mark-to-market income has been previously recognized, with the effect that the resulting adjusted segment profit is presented as if mark-to-market accounting had never been applied to Gas Marketing Services’ derivatives. The measure is limited by the fact that it does not reflect potential unrealized future losses or gains on derivative contracts. However, management compensates for this limitation since derivative assets and liabilities do reflect unrealized gains and losses of derivative contracts. Overall, management believes the mark-to-market adjustments provide an alternative measure that more closely matches realized cash flows for the Gas Marketing segment but does not substitute for actual cash flows. We also apply the mark-to-market adjustment and the recurring adjustments to present a measure referred to as recurring income from continuing operations after mark-to-market adjustments.