As filed with the Securities and Exchange Commission on November 22, 2011

Registration No. 333-173808

 

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

 

Amendment No. 6 to

Form S-1

REGISTRATION STATEMENT

UNDER

THE SECURITIES ACT OF 1933

 

 

 

WPX Energy, Inc.

(Exact name of registrant as specified in its charter)

 

 

 

 

One Williams Center

Tulsa, Oklahoma 74172-0172

(918) 573-2000

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

 

James J. Bender, Esq.

General Counsel and Corporate Secretary

One Williams Center, Suite 4900

Tulsa, Oklahoma 74172-0172

(918) 573-2000

(Name, address, including zip code, and telephone number, including area code, of agent for service)

 

 

 

 

Copies to:

 

 

Approximate date of commencement of proposed sale to the public:  As soon as practicable after the effective date of this registration statement.

 

If any of the securities being registered on this Form are being offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box:  o

 

If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

 

If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

 

If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.  o

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 

 

The registrant hereby amends this registration statement on such date or dates as may be necessary to delay its effective date until the registrant shall file a further amendment which specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933 or until this registration statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.

 

 

Subject to Completion, dated November 22, 2011

 

PROSPECTUS

 

           Shares

 

 

WPX Energy, Inc.

 

Common Stock

 

This is the initial public offering of common stock of WPX Energy, Inc. We are offering           shares of our common stock. No public market currently exists for our common stock. WPX Energy, Inc. is currently a wholly-owned subsidiary of The Williams Companies, Inc. (“Williams”).

 

Our common stock has been approved for listing on the New York Stock Exchange under the symbol “WPX.”

 

We anticipate that the initial public offering price will be between $           and $           per share.

 

Investing in our common stock involves risks. See “Risk Factors” beginning on page 16 of this prospectus.

 

 

We have granted the underwriters a 30-day option to purchase up to an additional           shares of common stock on the same terms and conditions set forth above if the underwriters sell more than      shares of common stock in this offering. Any shares of common stock issued pursuant to this option will not increase the total number of shares of common stock outstanding after this offering, but rather the number of shares of common stock owned by Williams will be reduced share for share by the number of shares of common stock issued pursuant to such option, thus reducing Williams’ ownership interest in us. We will distribute the net proceeds from the sale of shares of common stock pursuant to this option to Williams as part of our restructuring transactions described herein. Williams is deemed to be an underwriter with respect to any shares of common stock issued pursuant to this option.

 

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed on the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

 

Barclays Capital, on behalf of the underwriters, expects to deliver the shares on or about          , 2011.

 

 

 

 

 

 

Prospectus dated          , 2011

 

TABLE OF CONTENTS

 

 

 

 

 

You should rely only on the information contained in this document or any free writing prospectus prepared by or on behalf of us. We have not authorized anyone to provide you with information that is different. This document may only be used where it is legal to sell these securities. The information in this document may only be accurate on the date of this document.

 

 

 

 

Dealer Prospectus Delivery Obligation

 

Until          , 2011 (the 25th day after the date of this prospectus), all dealers that effect transactions in our common shares, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to the dealer’s obligation to deliver a prospectus when acting as an underwriter and with respect to unsold allotments or subscriptions.

 

Industry and Market Data

 

We obtained the market and competitive position data used throughout this prospectus from our own research, surveys or studies conducted by third parties and industry or general publications. Industry publications and surveys generally state that they have obtained information from sources believed to be reliable, but do not guarantee the accuracy and completeness of such information. While we believe that each of these studies and publications is reliable and have no reason to believe they are inaccurate or incomplete, neither we nor the underwriters have independently verified such data and neither we nor the underwriters make any representation as to the accuracy of such information. Similarly, we believe our internal research is reliable but it has not been verified by any independent sources.

 

The following oil and gas measurements and industry and other terms are used in this prospectus. As used herein, production volumes represent sales volumes, unless otherwise indicated.

 

Bakken Shale—means the Bakken Shale oil play in the Williston Basin and can include the Upper Three Forks formation.

 

Barrel—means one barrel of petroleum products that equals 42 U.S. gallons.

 

BBtu—means one billion BTUs.

 

BBtu/d—means one billion BTUs per day.

 

Bcfe—means one billion cubic feet of gas equivalent determined using the ratio of one barrel of oil or condensate to six thousand cubic feet of natural gas.

 

Bcf/d—means one billion cubic feet per day.

 

Boe—means barrels of oil equivalent.

 

Boe/d—means barrels of oil equivalent per day.

 

British Thermal Unit or BTU—means a unit of energy needed to raise the temperature of one pound of water by one degree Fahrenheit.

 

FERC—means the Federal Energy Regulatory Commission.

 

Fractionation—means the process by which a mixed stream of natural gas liquids is separated into its constituent products, such as ethane, propane and butane.

 

LOE—means lease and other operating expense excluding production taxes, ad valorem taxes and gathering, processing and transportation fees.

 

Mbbls—means one thousand barrels.

 

Mboe/d—means thousand barrels of oil equivalent per day.

 

Mcf—means one thousand cubic feet.

 

Mcfe—means one thousand cubic feet of gas equivalent using the ratio of one barrel of oil or condensate to six thousand cubic feet of natural gas.

 

MMbbls—means one million barrels.

 

MMboe—means one million barrels of oil equivalent.

 

MMBtu—means one million BTUs.

 

MMBtu/d—means one million BTUs per day.

 

MMcf—means one million cubic feet.

 

MMcf/d—means one million cubic feet per day.

 

MMcfe—means one million cubic feet of gas equivalent using the ratio of one barrel of oil or condensate to six thousand cubic feet of natural gas.

 

MMcfe/d—means one million cubic feet of gas equivalent per day using the ratio of one barrel of oil or condensate to six thousand cubic feet of natural gas.

 

NGLs—means natural gas liquids; natural gas liquids result from natural gas processing and crude oil refining and are used as petrochemical feedstocks, heating fuels and gasoline additives, among other applications.

 

PROSPECTUS SUMMARY

		Estimated Net								October 2011								2011 Budget Estimate
		Proved Reserves								Average Daily												Drilling
						% Proved				Net Production												Capital(2)				PV-10(3)
Basin/Shale		Bcfe				Developed				(MMcfe/d)(1)				Net Acreage				Gross Wells				(Millions)				(Millions)
Piceance Basin			2,927				53	%			745				211,000				376			$	575			$	2,707
Bakken Shale(4)			136				11	%			41				89,420				41				260				399
Marcellus Shale(5)			28				71	%			19				99,301				62				170				29
Powder River Basin			348				75	%			231				425,550				411				70				317
San Juan Basin			554				79	%			137				120,998				51				40				477
Apco(6)			190				60	%			54				404,304				37				30				358
Other(7)			290				72	%			81				327,390				94				85				257
Total			4,473				59	%			1,308				1,677,963				1,072			$	1,230			$	4,544

(1)		Represents average daily net production of our continuing operations for the month of October 2011.

(2)		Based on the midpoint of our estimated capital spending range.
(3)		PV-10 is a non-GAAP financial measure and generally differs from Standardized Measure of Discounted Future Net Cash Flows (“Standardized Measure”), the most directly comparable GAAP financial measure, because it does not include the effects of income taxes on future net revenues. Neither PV-10 nor Standardized Measure represents an estimate of the fair market value of our oil and natural gas assets. We and others in the industry use PV-10 as a measure to compare the relative size and value of proved reserves held by companies without regard to the specific tax characteristics of such entities. For a

		definition of PV-10 and a reconciliation of PV-10 to Standardized Measure, see “—Summary Combined Historical Operating and Reserve Data—Non-GAAP Financial Measures and Reconciliations” below.

(4)		Our estimated net proved reserves in the Bakken Shale have not been audited by independent reserve engineers.

(5)		Approximately 21 percent of our undeveloped net acres in the Marcellus Shale are located in Columbia County. During the nine months ended September 30, 2011, we recorded a $50 million write-off of leasehold costs associated with approximately 65 percent of our Columbia County acreage that we no longer plan to develop.

(6)		Represents approximately 69 percent of each metric (which corresponds to our ownership interest in Apco) except Percent Proved Developed, Gross Wells and Drilling Capital.

(7)		Other includes Barnett Shale, Arkoma and Green River Basins and miscellaneous smaller properties. October 2011 average daily net production excludes Arkoma production of approximately nine MMcfe/d as our Arkoma Basin operations were classified as held for sale and reported as discontinued operations as of September 30, 2011.

	•	Efficiently Allocate Capital for Optimal Portfolio Returns.  We expect to allocate capital to the most profitable opportunities in our portfolio based on commodity price cycles and other market conditions, enabling us to continue to grow our reserves and production in a manner that maximizes our return on investment. In determining which drilling opportunities to pursue, we target a minimum after-tax internal rate of return on each operated well we drill of 15 percent. While we have a significant portfolio of drilling opportunities that we believe meet or exceed our return targets even in challenging commodity price environments, we are disciplined in our approach to capital spending and will adjust our drilling capital expenditures based on our level of expected cash flows, access to capital and overall liquidity position. For example, in 2009 we demonstrated our capital discipline by reducing drilling expenditures in response to prevailing commodity prices and their impact on these factors.
	•	Continue Our Cost-Efficient Development Approach.  We focus on developing properties where we can apply development practices that result in cost efficiencies. We manage costs by focusing on establishing large scale, contiguous acreage blocks where we can operate a majority of the properties. We believe this strategy allows us to better achieve economies of scale and apply continuous technological improvements in our operations. We intend to replicate these cost-efficient approaches in our recently acquired growth positions in the Bakken Shale and the Marcellus Shale.
	•	Pursue Strategic Acquisitions with Significant Resource Potential.  We have a history of acquiring undeveloped properties that meet our disciplined return requirements and other acquisition criteria to expand upon our existing positions as well as acquiring undeveloped acreage in new geographic areas that offer significant resource potential. This is illustrated by our recent acquisitions in the Bakken Shale and the Marcellus Shale. We seek to continue expansion of current acreage positions and opportunistically acquire acreage positions in new areas where we feel we can establish significant scale and replicate our cost-efficient development approach.
	•	Target a More Balanced Commodity Mix in Our Production Profile.  With our Bakken Shale acquisition in December 2010 and our liquids-rich Piceance Basin assets, we have a significant drilling inventory of oil- and liquids-rich opportunities that we intend to develop rapidly in order to achieve a more balanced commodity mix in our production. We refer to the Piceance Basin as “liquids-rich” because our proved reserves in that basin consist of “wet,” as opposed to “dry,” gas and have a significant liquids component. Our current estimated proved reserves of NGLs and condensate in the Piceance Basin are 95 MMbbl and 3 MMbbl, respectively. We will continue to pursue other oil- and liquids-rich organic development and acquisition opportunities that meet our investment returns and strategic criteria.

	•	Maintain Substantial Financial Liquidity and Manage Commodity Price Sensitivity.  We plan to conservatively manage our balance sheet and maintain substantial liquidity through a mix of cash on hand and availability under our credit facility. In addition, we have engaged and will continue to engage in commodity hedging activities to maintain a degree of cash flow stability. Typically, we target hedging approximately 50 percent of expected revenue from domestic production during a current calendar year in order to strike an appropriate balance of commodity price upside with cash flow protection, although we may vary from this level based on our perceptions of market risk. At

		October 31, 2011, our estimated domestic natural gas production revenues were 67 percent hedged for 2011 and 48 percent hedged for 2012. Estimated domestic oil production revenues were 48 percent hedged for 2011 and 49 percent hedged for 2012 as of the same date.

	•	A Leading Piceance Basin Cost Structure.  We have a large position in the lower cost valley area of the Piceance Basin, which we believe provides us economies associated with lower elevation drilling and large contiguous operations, allowing us to continuously drive down operating costs and increase efficiencies. The existing substantial midstream infrastructure in the Piceance Basin contributes to our cost-efficient structure and provides take-away capacity for our natural gas and NGLs. Because of this cost-efficient structure in the Piceance Basin, we have the ability to generate returns that we believe are in excess of those typically associated with Rockies producers.
	•	Attractive Asset Base Across a Number of High Growth Areas.  In addition to our large scale Piceance Basin properties, our assets include emerging, high growth opportunities such as our Bakken Shale and Marcellus Shale positions. Based on our subsurface geological and engineering analysis of available well data, we believe our Bakken Shale and Marcellus Shale positions are located in core areas of these plays, which have associated historic drilling results that we believe offer highly attractive economic returns.
	•	Extensive Drilling Inventory.  As of December 31, 2010, we have identified approximately 2,900 proved undeveloped drilling locations. We have budgeted drilling approximately 500 gross operated wells during 2011. We have established significant scale in each of our core areas of operation that support multi-year development plans and allow us to optimally leverage our cost-efficient development approach. Our drilling inventory provides opportunities across diverse geographic markets and products including natural gas, oil and NGLs.
	•	Significant Operating Flexibility.  In the Piceance Basin, Bakken Shale and Marcellus Shale, our three primary basins, we operate substantially all of our production. We expect approximately 91 percent of our projected 2011 domestic drilling capital will be spent on projects we operate. We believe acting as operator on our properties allows us to better control costs and capital expenditures, manage efficiencies, optimize development pace, ensure safety and environmental stewardship and, ultimately, maximize our return on investment. As operator, we are also able to leverage our experience and expertise across all basins and transfer technology advances between them as applicable. In addition, substantially all of our Piceance Basin properties are held by producing wells, which allows us to adjust our level of drilling activity in response to changing market conditions.

	•	Significant Financial Flexibility.  Our capital structure is intended to provide a high degree of financial flexibility to grow our asset base, both through organic projects and opportunistic acquisitions. We retained $500 million of the net proceeds of our issuance of debt securities in November 2011 and have a $1.5 billion credit facility (the “Credit Facility”), although our future borrowing capacity under the Credit Facility will be reduced by letters of credit issued under that facility and is subject to debt ratio tests. See “Description of Material Indebtedness.” We believe our level of debt to proved reserves is low relative to a majority of other publicly traded, independent oil and gas producers.

	•	Management Team with Broad Unconventional Resource Experience.  Our management and operating team has significant experience acquiring, operating and developing natural gas and oil reserves from tight-sands and shale formations. Our Chief Executive Officer and his direct reports have in excess of 238 collective years of experience running large scale drilling programs and drilling vertical and horizontal wells requiring complex well design and completion methods. Our team has demonstrated the ability to manage large scale operations and apply current technological successes to new

		development opportunities. We have deployed members of our successful Piceance Basin, Powder River Basin and Barnett Shale teams to the Bakken Shale and Marcellus Shale teams to help replicate our cost-efficient model and to apply our highly specialized technical expertise in the development of those resources.

	•	Focused management attention.  Our separation from Williams will allow us to focus managerial attention solely on our business, resulting in stream-lined decision making, more efficient deployment of resources and increased operational flexibility.
	•	Direct access to the debt and equity capital markets.  As a separate public company, we will have direct access to the capital markets, thereby enabling us to optimize our capital structure to meet the specific needs of our business.
	•	Enhancing our market recognition with investors.  We believe our simpler corporate structure with a single business segment will allow us to fit more purely into an exploration and production investor sector and attract pure play investors.
	•	Improving our ability to pursue acquisitions.  As a stand alone exploration and production company, we will be better positioned to use our equity securities as capital in pursuing merger and acquisition activities. However, we will be subject to certain requirements, such as (1) prior to the spin-off to Williams’ shareholders of its retained shares in us, Williams must satisfy certain 80% ownership thresholds and (2) after the spin-off, we must avoid a 50% or greater change in our ownership in transactions related to the spin-off. Both of these limitations are necessary in order to maintain the tax-free treatment of our separation from Williams. See “Risk Factors—Risks Related to our Relationship with Williams—Our agreements with Williams may limit our ability to obtain additional financing or make acquisitions,” and “Risk Factors—Risks Related to our Relationship with Williams—Our tax sharing agreement with Williams may limit our ability to take certain actions and may require us to indemnify Williams for significant tax liabilities.”

	•	Williams will contribute and transfer to us the assets and liabilities associated with our business and will contribute to our capital all intercompany debt associated with our business; and
	•	we will amend and restate our certificate of incorporation and bylaws.

	•	Our business requires significant capital expenditures and we may be unable to obtain needed capital or financing on satisfactory terms.
	•	Failure to replace reserves may negatively affect our business.
	•	Exploration and development drilling may not result in commercially productive reserves.
	•	Estimating reserves and future net revenues involves uncertainties. Decreases in natural gas and oil prices, or negative revisions to reserve estimates or assumptions as to future natural gas and oil prices may lead to decreased earnings, losses or impairment of natural gas and oil assets.
	•	Prices for natural gas, oil and NGLs are volatile, and this volatility could adversely affect our financial results, cash flows, access to capital and ability to maintain our existing business.
	•	Our business depends on access to natural gas, oil and NGL transportation systems and facilities.
	•	Our risk management and measurement systems and hedging activities might not be effective and could increase the volatility of our results.
	•	Our operations are subject to operational hazards and unforeseen interruptions for which they may not be adequately insured.
	•	Our operations are subject to governmental laws and regulations relating to the protection of the environment, including with respect to hydraulic fracturing, which may expose us to significant costs and liabilities and could exceed current expectations.
	•	Certain of our properties, including our operations in the Bakken Shale, are located on Native American tribal lands and are subject to various federal and tribal approvals and regulations, which may increase our costs and delay or prevent our efforts to conduct planned operations.
	•	Our acquisition attempts may not be successful or may result in completed acquisitions that do not perform as anticipated.
	•	Our historical and pro forma combined financial information may not be representative of the results we would have achieved as a stand-alone public company and may not be a reliable indicator of our future results.
	•	As long as we are controlled by Williams, your ability to influence the outcome of matters requiring stockholder approval will be limited.

Issuer		WPX Energy, Inc.
Common stock offered		shares.
Option to purchase additional shares		shares.
Common stock to be held by Williams after this offering		shares (           shares if the underwriters exercise their option to purchase additional shares in full). Any shares of common stock issued pursuant to the underwriters’ option to purchase additional common shares will not increase the total number of shares of common stock outstanding after this offering, but rather the number of shares of common stock owned by Williams will be reduced share for share by the number of shares of common stock issued pursuant to such option. Williams is deemed to be an underwriter with respect to any shares of common stock issued pursuant to such option.
Common stock outstanding immediately after this offering		shares.
Use of proceeds		We estimate that our net proceeds from the sale of shares of common stock in this offering, after deducting estimated underwriting discounts and commissions and estimated offering expenses, will be approximately $      million ($      million if the underwriters exercise their option to purchase additional common shares in full), assuming the shares are offered at $      per share of common stock, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus. All the net proceeds of this offering will be distributed to Williams. See “Use of Proceeds.”
Dividend policy		We do not anticipate paying any dividends on our common stock in the foreseeable future. See “Dividend Policy.”
Exchange Listing		We have been approved to list our shares of common stock on the NYSE under the symbol “WPX.”

	•	gives effect to our restructuring transactions;
	•	assumes no exercise by the underwriters of their option to purchase additional common shares;
	•	gives effect to a one to           stock split that we effected on          , 2011; and
	•	excludes shares of common stock reserved for issuance, if any, under equity incentive plans.

	•	the completion of our restructuring transactions;
	•	the receipt of approximately $718 million from the sale of shares of common stock offered by us at an assumed initial public offering price of $      per share, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus, after deducting estimated underwriting discounts and commissions and estimated offering expenses payable by us;

	•	the receipt of $1.479 billion from our offering of the Notes, after deducting the discounts of the initial purchasers of the Notes and estimated expenses payable by us in connection with such offering; and

	•	the distribution of approximately $1.7 billion to Williams from the combined net proceeds from this offering and the offering of the Notes in connection with our restructuring transactions.

		Pro Forma Nine				Pro Forma				Historical Nine
		Months Ended				Year Ended				Months								Historical Year Ended
		September 30,				December 31,				Ended September 30,								December 31,
		2011				2010				2011				2010				2010				2009				2008
		(Millions)
Statement of Operations Data:
Revenues, including affiliate(1)		$	2,996			$	4,034			$	2,996			$	3,074			$	4,034			$	3,681			$	6,184
Costs and expenses:
Lease and facility operating, including affiliate			218				286				218				207				286				263				272
Gathering, processing and transportation, including affiliate			372				326				372				216				326				273				229
Taxes other than income			109				125				109				109				125				93				254
Gas management (including charges for unutilized pipeline capacity)			1,122				1,771				1,122				1,385				1,771				1,495				3,248
Exploration			107				73				107				45				73				54				37
Depreciation, depletion and amortization			703				875				703				655				875				887				738
Impairment of producing properties and costs of acquired unproved reserves			—				678				—				678				678				15				—
Goodwill impairment			—				1,003				—				1,003				1,003				—				—
General and administrative, including affiliate			208				253				208				183				253				251				247
Gain on sale of contractual right to international production payment			—				—				—				—				—				—				(148	)
Other—net			4				(19	)			4				(6	)			(19	)			33				6
Total costs and expenses			2,843				5,371				2,843				4,475				5,371				3,364				4,883
Operating income (loss)			153				(1,337	)			153				(1,401	)			(1,337	)			317				1,301
Interest expense, including affiliate			(74	)			(101	)			(97	)			(88	)			(124	)			(100	)			(74	)
Interest capitalized			8				16				8				12				16				18				20
Investment income and other			19				21				19				15				21				8				22
Income (loss) from continuing operations before income taxes			106				(1,401	)			83				(1,462	)			(1,424	)			243				1,269
Provision (benefit) for income taxes			37				(142	)			29				(167	)			(150	)			94				452
Income (loss) from continuing operations(2)			69				(1,259	)			54				(1,295	)			(1,274	)			149				817
Loss from discontinued operations(3)			(11	)			(8	)			(11	)			(2	)			(8	)			(7	)			(87	)
Net income (loss)		$	58			$	(1,267	)			43				(1,297	)			(1,282	)			142				730
Less: Net income attributable to noncontrolling interests											7				6				8				6				8
Net income (loss) attributable to WPX Energy										$	36			$	(1,303	)		$	(1,290	)		$	136			$	722
Income (loss) from continuing operations per share(4):
Basic and diluted		$				$

(1)		Includes gas management revenues of $1,092 million and $1,357 million for the nine months ended September 30, 2011 and 2010, respectively and $1,742 million, $1,456 million and $3,241 million for the years ended December 31, 2010, 2009 and 2008, respectively. These revenues were offset by the gas management

		expenses shown in the table above. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Results of Operations.”
(2)		Loss from continuing operations for the nine months ended September 30, 2010 and for the year ended December 31, 2010 includes $1.7 billion of impairment charges related to goodwill, producing properties in the Barnett Shale and costs of acquired unproved reserves in the Piceance Basin. Income from continuing operations in 2008 includes a $148 million gain related to the sale of a right to an international production payment. See Notes 6 and 14 of Notes to Combined Financial Statements for further discussion of asset sales, impairments and other accruals in 2010, 2009 and 2008.

(3)		Loss from discontinued operations includes our Arkoma operations which were classified as held for sale in the first quarter of 2011 and activities associated with Williams’ former power business that was substantially disposed of in 2007. The loss in 2008 includes a $148 million pre-tax impairment of the Arkoma producing properties.

(4)		Historical earnings per share are not presented since the Company’s common stock was not part of the capital structure of Williams for the periods presented.

		Pro Forma				Historical				Historical
		At September 30,				At September 30,				At December 31,
		2011				2011				2010				2009
		(Millions)
Balance Sheet Data:
Cash and cash equivalents		$	550			$	50			$	37			$	34
Properties and equipment, net			8,729				8,729				8,449				7,662
Total assets			10,662				10,141				9,846				10,553
Unsecured notes payable to Williams—current			—				—				2,261				1,216
Senior unsecured notes			1,500				—				—				—
Total equity			5,981				7,007				4,500				5,405
Total liabilities and equity			10,662				10,141				9,846				10,553

		Pro Forma
		Nine Months				Pro Forma
		Ended				Year Ended				Historical Nine Months
		September 30,				December 31,				Ended September 30,								Historical Year Ended December 31,
		2011				2010				2011				2010				2010				2009				2008
		(Millions)
Other Financial Data:
Net cash provided by operating activities										$	888			$	852			$	1,056			$	1,181			$	2,009
Net cash used in investing activities											(1,056	)			(1,433	)			(2,337	)			(1,435	)			(2,252	)
Net cash provided (used) by financing activities											181				582				1,284				256				225
Adjusted EBITDAX(1)		$	990			$	1,329				990				1,007				1,329				1,299				1,970
Capital expenditures											(1,088	)			(1,460	)			(1,856	)			(1,434	)			(2,467	)

(1)		Adjusted EBITDAX is a non-GAAP financial measure. For a definition of Adjusted EBITDAX and a reconciliation of Adjusted EBITDAX to our net income (loss), see “—Summary Combined Historical Operating and Reserve Data—Non-GAAP Financial Measures and Reconciliations” below.

		At December 31,
		2010				2009
Estimated Proved Reserves(1):
Natural Gas (Bcf)(2)			4,214				4,316
Oil (MMbbls)			43				23
Total (Bcfe)			4,473				4,452
PV-10 (in millions)		$	4,544			$	2,620
Standardized Measure of Discounted Future Net Cash Flows (in millions)(3)		$	3,080			$	1,923

(1)		Includes approximately 69 percent of Apco’s reserves, which corresponds to our ownership interest in Apco. Our estimated proved reserves for domestic properties, PV-10 and Standardized Measure were derived using an average price of $3.36 per Mcf of natural gas and $48.63 per barrel of oil during 2009 and $4.31 per Mcf of natural gas and $68.89 per barrel of oil during 2010. Our prices were calculated using the 12-month average, first-of-the-month price for the applicable indices for each basin as adjusted for locational price differentials. The 12-month average beginning of the month price for Apco properties was $1.93 per MMbtu of natural gas and $43.62 per barrel of oil for 2009 and $1.63 per MMbtu of natural gas and $52.11 per barrel of oil for 2010.
(2)		Net wellhead natural gas reserves at December 31, 2010 and 2009 included approximately 99 MMbbls and 69 MMbbls, respectively, of NGLs to be extracted downstream at processing plants. The gas volume shrink associated with this processing is approximately 216 Bcf and 164 Bcf, respectively, or approximately 4.8 percent and 3.7 percent, respectively, of our total proved reserves volumes.
(3)		Standardized Measure represents the present value of estimated future cash inflows from proved natural gas and oil reserves, less future development and production costs and income tax expenses, discounted at ten percent per annum to reflect timing of future cash flows and using the same pricing assumptions as were used to calculate PV-10. Standardized Measure differs from PV-10 because Standardized Measure includes the effect of future income taxes. For a reconciliation of the non-GAAP financial measure of PV-10 to Standardized Measure, the most directly comparable GAAP financial measure, see “—Non-GAAP Financial Measures and Reconciliations” below.

		Year Ended December 31,
		2010				2009				2008
Production Data:
Natural Gas (MMcf)
U.S.
Piceance Basin			241,371				252,387				240,285
Other(1)			162,571				171,691				156,497
Argentina(2)			7,304				7,728				6,392
Total			411,246				431,806				403,174
Oil (MBbls)
U.S.			857				803				731
Argentina(2)			2,035				1,998				1,991
Total			2,892				2,801				2,722
Combined Equivalent Volumes (MMcfe)(2)			428,598				448,612				419,506
Combined Equivalent Volumes (MBoe)			71,433				74,769				69,918
Average Daily Combined Equivalent Volumes (MMcfe/d)
U.S.
Piceance Basin			674				703				666
Other(1)			447				472				430
Argentina(2)			53				54				50
Total			1,174				1,229				1,146

(1)		Excludes production from our Arkoma Basin operations which were classified as held for sale and reported as discontinued operations as of September 30, 2011 and comprised less than one percent of our total production.

(2)		Includes approximately 69 percent of Apco’s production (which corresponds to our ownership interest in Apco) and other minor directly held interests.

		Year Ended December 31,
		2010				2009				2008
Realized average price per unit(1):
Natural gas, without hedges (per Mcf)(2)		$	4.33			$	3.39			$	6.84
Impact of hedges (per Mcf)(2)			0.82				1.45				0.09
Natural gas, with hedges (per Mcf)(2)		$	5.15			$	4.84			$	6.93
Oil, without hedges (per Bbl)		$	66.32			$	47.39			$	84.63
Impact of hedges (per Bbl)			—				—				—
Oil, with hedges (per Bbl)		$	66.32			$	47.39			$	84.63
Price per Boe, without hedges(3)		$	26.44			$	20.63			$	41.52
Price per Boe, with hedges(3)		$	31.32			$	29.23			$	42.03
Price per Mcfe, without hedges(3)		$	4.41			$	3.44			$	6.92
Price per Mcfe, with hedges(3)		$	5.22			$	4.87			$	7.00

(1)		Excludes our Arkoma Basin operations, which were classified as held for sale and reported as discontinued operations as of September 30, 2011 and comprised less than one percent of our total revenues.

(2)		Includes NGLs.
(3)		Realized average prices reflect realized market prices, net of fuel and shrink.

		Year Ended December 31,
		2010				2009				2008
Expenses per Mcfe(1):
Operating expenses:
Lifting costs and workovers		$	0.46			$	0.39			$	0.45
Facilities operating expense			0.14				0.14				0.15
Other operating and maintenance			0.05				0.05				0.04
Total LOE		$	0.65			$	0.58			$	0.64
Gathering, processing and transportation charges			0.80				0.64				0.57
Taxes other than income			0.27				0.19				0.60
Production cost		$	1.72			$	1.41			$	1.81
General and administrative		$	0.60			$	0.56			$	0.60
Depreciation, depletion and amortization		$	2.10			$	2.03			$	1.80

(1)		Excludes our Arkoma Basin operations, which were classified as held for sale and reported as discontinued operations as of September 30, 2011.

		Pro Forma Nine				Pro Forma				Historical
		Months Ended				Year Ended				Nine Months								Historical
		September 30,				December 31,				Ended September 30,								Year Ended December 31,
		2011				2010				2011				2010				2010				2009				2008
		(Millions)
Adjusted EBITDAX Reconciliation to Net Income (Loss):
Net income (loss)		$	58			$	(1,267	)		$	43			$	(1,297	)		$	(1,282	)		$	142			$	730
Interest expense			74				101				97				88				124				100				74
Provision (benefit) for income taxes			37				(142	)			29				(167	)			(150	)			94				452
Depreciation, depletion and amortization			703				875				703				655				875				887				738
Exploration expenses			107				73				107				45				73				54				37
EBITDAX			979				(360	)			979				(676	)			(360	)			1,277				2,031
Gain on sale of contractual right to international production payment			—				—				—				—				—				—				(148	)
Impairments of goodwill, producing properties and cost of acquired unproved reserves			—				1,681				—				1,681				1,681				15				—
Loss from discontinued operations			11				8				11				2				8				7				87
Adjusted EBITDAX		$	990			$	1,329			$	990			$	1,007			$	1,329			$	1,299			$	1,970

		At December 31,
		2010				2009
		(Millions)
Standardized Measure of Discounted Future Net Cash Flows		$	3,080			$	1,923
Present value of future income tax discounted at 10%			1,464				697
PV-10		$	4,544			$	2,620

 

Investing in our common stock involves substantial risk. You should carefully consider the following risk factors and the other information in this prospectus before investing in our common stock. If any of the following risks actually occur, our business, financial condition, cash flows and results of operations could suffer materially and adversely. In that case, the trading price of our common stock could decline, and you might lose all or part of your investment.

 

Risks Related to Our Business

 

Our business requires significant capital expenditures and we may be unable to obtain needed capital or financing on satisfactory terms.

 

Our exploration, development and acquisition activities require substantial capital expenditures. Historically, we have funded our capital expenditures through a combination of cash flows from operations, capital contributions or borrowings from Williams and sales of assets. Future cash flows are subject to a number of variables, including the level of production from existing wells, prices of natural gas and oil and our success in developing and producing new reserves. If our cash flow from operations is not sufficient to fund our capital expenditure budget, we may have limited ability to obtain the additional capital necessary to sustain our operations at current levels. We may not be able to obtain debt or equity financing on terms favorable to us or at all. The failure to obtain additional financing could result in a curtailment of our operations relating to exploration and development of our prospects, which in turn could lead to a decline in our natural gas and oil production or reserves, and in some areas a loss of properties.

 

Failure to replace reserves may negatively affect our business.

 

The growth of our business depends upon our ability to find, develop or acquire additional natural gas and oil reserves that are economically recoverable. Our proved reserves generally decline when reserves are produced, unless we conduct successful exploration or development activities or acquire properties containing proved reserves, or both. We may not always be able to find, develop or acquire additional reserves at acceptable costs. If natural gas or oil prices increase, our costs for additional reserves would also increase; conversely if natural gas or oil prices decrease, it could make it more difficult to fund the replacement of our reserves.

 

Exploration and development drilling may not result in commercially productive reserves.

 

Our past success rate for drilling projects should not be considered a predictor of future commercial success. Our decisions to purchase, explore, develop or otherwise exploit prospects or properties will depend in part on the evaluation of data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often inconclusive or subject to varying interpretations. The new wells we drill or participate in may not be commercially productive, and we may not recover all or any portion of our investment in wells we drill or participate in. Our efforts will be unprofitable if we drill dry wells or wells that are productive but do not produce enough reserves to return a profit after drilling, operating and other costs. The cost of drilling, completing and operating a well is often uncertain, and cost factors can adversely affect the economics of a project. Further, our drilling operations may be curtailed, delayed, canceled or rendered unprofitable or less profitable than anticipated as a result of a variety of other factors, including:

 

 

 

We expect to invest approximately 35 percent of our drilling capital during 2011 in two relatively new unconventional projects, the Bakken Shale in western North Dakota and the Marcellus Shale in Pennsylvania. Due to limited production history from the relatively few number of wells drilled in these projects, we are unable to predict with certainty the quantity of future production from wells to be drilled in those projects.

 

If natural gas and oil prices decrease, we may be required to take write-downs of the carrying values of our natural gas and oil properties.

 

Accounting rules require that we review periodically the carrying value of our natural gas and oil properties for possible impairment. Based on specific market factors and circumstances at the time of prospective impairment reviews and the continuing evaluation of development plans, production data, economics and other factors, we may be required to write down the carrying value of our natural gas and oil properties. A writedown constitutes a non-cash charge to earnings. For example, as a result of significant declines in forward natural gas prices, we recorded impairments of capitalized costs of certain natural gas properties of $678 million in 2010. In addition, following a weighted average decline in the forward prices for the Powder River Basin from December 31, 2010 to September 30, 2011, we conducted an impairment assessment of our proved producing oil and gas properties in that basin as of September 30, 2011. No impairment was required as of September 30, 2011; however, in this assessment, we noted that the producing assets could be at risk of future impairment if the weighted average forward price across all periods used in our cash flow estimates were to decline by approximately six percent on average, absent changes in other factors. The weighted average decline in these forward prices from September 30, 2011 to November 21, 2011, as it relates to the Powder River basin projections, was approximately 8.5 percent. These properties will be part of our annual impairment assessment for all properties in the fourth quarter of 2011 and could be subject to impairment. If the recording of an impairment charge becomes necessary for the Powder River properties as of December 31, 2011, it is reasonably possible that the amount of such charge could be at least $200 million. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Overview of the nine months ended September 30, 2011 and 2010.” We may incur impairment charges for these or other properties in the future, which could have a material adverse effect on our results of operations for the periods in which such charges are taken.

 

Estimating reserves and future net revenues involves uncertainties. Decreases in natural gas and oil prices, or negative revisions to reserve estimates or assumptions as to future natural gas and oil prices may lead to decreased earnings, losses or impairment of natural gas and oil assets.

 

Reserve estimation is a subjective process of evaluating underground accumulations of oil and gas that cannot be measured in an exact manner. Reserves that are “proved reserves” are those estimated quantities of crude oil, natural gas and NGLs that geological and engineering data demonstrate with reasonable certainty are recoverable in future years from known reservoirs under existing economic and operating conditions and relate to projects for which the extraction of hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time.

 

The process relies on interpretations of available geological, geophysical, engineering and production data. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting future rates of production and timing of developmental expenditures, including many factors beyond the control of the producer. The reserve data included in this prospectus represent estimates. In addition, the estimates of future net revenues from our proved reserves and the present value of such estimates are based upon certain assumptions about future production levels, prices and costs that may not prove to be correct.

Quantities of proved reserves are estimated based on economic conditions in existence during the period of assessment. Changes to oil and gas prices in the markets for such commodities may have the impact of shortening the economic lives of certain fields because it becomes uneconomic to produce all recoverable reserves on such fields, which reduces proved property reserve estimates.

 

If negative revisions in the estimated quantities of proved reserves were to occur, it would have the effect of increasing the rates of depreciation, depletion and amortization on the affected properties, which would decrease earnings or result in losses through higher depreciation, depletion and amortization expense. These revisions, as well as revisions in the assumptions of future cash flows of these reserves, may also be sufficient to trigger impairment losses on certain properties which would result in a noncash charge to earnings.

 

The development of our proved undeveloped reserves may take longer and may require higher levels of capital expenditures than we currently anticipate.

 

Approximately 41 percent of our total estimated proved reserves at December 31, 2010 were proved undeveloped reserves and may not be ultimately developed or produced. Recovery of proved undeveloped reserves requires significant capital expenditures and successful drilling operations. The reserve data included in the reserve engineer reports assumes that substantial capital expenditures are required to develop such reserves. We cannot be certain that the estimated costs of the development of these reserves are accurate, that development will occur as scheduled or that the results of such development will be as estimated. Delays in the development of our reserves or increases in costs to drill and develop such reserves will reduce the PV-10 value of our estimated proved undeveloped reserves and future net revenues estimated for such reserves and may result in some projects becoming uneconomic. In addition, delays in the development of reserves could cause us to have to reclassify our proved reserves as unproved reserves.

 

The present value of future net revenues from our proved reserves will not necessarily be the same as the value we ultimately realize of our estimated natural gas and oil reserves.

 

You should not assume that the present value of future net revenues from our proved reserves is the current market value of our estimated natural gas and oil reserves. For the year ended December 31, 2008, we based the estimated discounted future net revenues from our proved reserves on prices and costs in effect on the day of the estimate in accordance with previous SEC requirements. In accordance with new SEC requirements for the years ended December 31, 2009 and 2010, we have based the estimated discounted future net revenues from our proved reserves on the 12-month unweighted arithmetic average of the first-day-of-the-month price for the preceding twelve months without giving effect to derivative transactions. Actual future net revenues from our natural gas and oil properties will be affected by factors such as:

 

 

The timing of both our production and our incurrence of expenses in connection with the development and production of natural gas and oil properties will affect the timing and amount of actual future net revenues from proved reserves, and thus their actual present value. In addition, the 10 percent discount factor we use when calculating discounted future net revenues may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the natural gas and oil industry in general.

 

Certain of our domestic undeveloped leasehold assets are subject to leases that will expire over the next several years unless production is established on units containing the acreage.

 

The majority of our acreage in the Marcellus Shale and Bakken Shale is not currently held by production. Unless production in paying quantities is established on units containing these leases during their terms, the leases will expire. If our leases expire and we are unable to renew the leases, we will lose our right to develop

the related properties. Our drilling plans for these areas are subject to change based upon various factors, including drilling results, natural gas and oil prices, availability and cost of capital, drilling and production costs, availability of drilling services and equipment, gathering system and pipeline transportation constraints and regulatory and lease issues.

 

Prices for natural gas, oil and NGLs are volatile, and this volatility could adversely affect our financial results, cash flows, access to capital and ability to maintain our existing business.

 

Our revenues, operating results, future rate of growth and the value of our business depend primarily upon the prices of natural gas, oil and NGLs. Price volatility can impact both the amount we receive for our products and the volume of products we sell. Prices affect the amount of cash flow available for capital expenditures and our ability to borrow money under our Credit Facility or raise additional capital.

 

The markets for natural gas, oil and NGLs are likely to continue to be volatile. Wide fluctuations in prices might result from relatively minor changes in the supply of and demand for these commodities, market uncertainty and other factors that are beyond our control, including:

 

 

Our business depends on access to natural gas, oil and NGL transportation systems and facilities.

 

The marketability of our natural gas, oil and NGL production depends in large part on the operation, availability, proximity, capacity and expansion of transportation systems and facilities owned by third parties. For example, we can provide no assurance that sufficient transportation capacity will exist for expected production from the Bakken Shale and Marcellus Shale or that we will be able to obtain sufficient transportation capacity on economic terms.

 

A lack of available capacity on transportation systems and facilities or delays in their planned expansions could result in the shut-in of producing wells or the delay or discontinuance of drilling plans for properties. A lack of availability of these systems and facilities for an extended period of time could negatively affect our revenues. In addition, we have entered into contracts for firm transportation and any failure to renew those contracts on the same or better commercial terms could increase our costs and our exposure to the risks described above.

We may have excess capacity under our firm transportation contracts, or the terms of certain of those contracts may be less favorable than those we could obtain currently.

 

We have entered into contracts for firm transportation that may exceed our transportation needs. Any excess transportation commitments will result in excess transportation costs that could negatively affect our results of operations. In addition, certain of the contracts we have entered into may be on terms less favorable to us than we could obtain if we were negotiating them at current rates, which also could negatively affect our results of operations.

 

We have limited control over activities on properties we do not operate, which could reduce our production and revenues.

 

If we do not operate the properties in which we own an interest, we do not have control over normal operating procedures, expenditures or future development of underlying properties. The failure of an operator of our wells to adequately perform operations or an operator’s breach of the applicable agreements could reduce our production and revenues or increase our costs. As of December 31, 2010, we were not the operator of approximately 17 percent of our total domestic net production. Apco generally has outside-operated interests in its properties. The success and timing of our drilling and development activities on properties operated by others depend upon a number of factors outside of our control, including the operator’s timing and amount of capital expenditures, expertise and financial resources, inclusion of other participants in drilling wells and use of technology. Because we do not have a majority interest in most wells we do not operate, we may not be in a position to remove the operator in the event of poor performance.

 

We might not be able to successfully manage the risks associated with selling and marketing products in the wholesale energy markets.

 

Our portfolio of derivative and other energy contracts includes wholesale contracts to buy and sell natural gas, oil and NGLs that are settled by the delivery of the commodity or cash. If the values of these contracts change in a direction or manner that we do not anticipate or cannot manage, it could negatively affect our results of operations. In the past, certain marketing and trading companies have experienced severe financial problems due to price volatility in the energy commodity markets. In certain instances this volatility has caused companies to be unable to deliver energy commodities that they had guaranteed under contract. If such a delivery failure were to occur in one of our contracts, we might incur additional losses to the extent of amounts, if any, already paid to, or received from, counterparties. In addition, in our business, we often extend credit to our counterparties. We are exposed to the risk that we might not be able to collect amounts owed to us. If the counterparty to such a transaction fails to perform and any collateral that secures our counterparty’s obligation is inadequate, we will suffer a loss. Downturns in the economy or disruptions in the global credit markets could cause more of our counterparties to fail to perform than we expect.

 

Our risk management and measurement systems and hedging activities might not be effective and could increase the volatility of our results.

 

The systems we use to quantify commodity price risk associated with our businesses might not always be followed or might not always be effective. Further, such systems do not in themselves manage risk, particularly risks outside of our control, and adverse changes in energy commodity market prices, volatility, adverse correlation of commodity prices, the liquidity of markets, changes in interest rates and other risks discussed in this prospectus might still adversely affect our earnings, cash flows and balance sheet under applicable accounting rules, even if risks have been identified. Furthermore, no single hedging arrangement can adequately address all commodity price risks present in a given contract. For example, a forward contract that would be effective in hedging commodity price volatility risks would not hedge the contract’s counterparty credit or performance risk. Therefore, unhedged risks will always continue to exist.

 

Our use of hedging arrangements through which we attempt to reduce the economic risk of our participation in commodity markets could result in increased volatility of our reported results. Changes in the fair values (gains and losses) of derivatives that qualify as hedges under GAAP to the extent that such hedges

are not fully effective in offsetting changes to the value of the hedged commodity, as well as changes in the fair value of derivatives that do not qualify or have not been designated as hedges under GAAP, must be recorded in our income. This creates the risk of volatility in earnings even if no economic impact to us has occurred during the applicable period.

 

The impact of changes in market prices for natural gas, oil and NGLs on the average prices paid or received by us may be reduced based on the level of our hedging activities. These hedging arrangements may limit or enhance our margins if the market prices for natural gas, oil or NGLs were to change substantially from the price established by the hedges. In addition, our hedging arrangements expose us to the risk of financial loss if our production volumes are less than expected.

 

The adoption and implementation of new statutory and regulatory requirements for derivative transactions could have an adverse impact on our ability to hedge risks associated with our business and increase the working capital requirements to conduct these activities.

 

In July 2010, federal legislation known as the Dodd-Frank Wall Street Reform and Consumer Protection Act (the “Dodd-Frank Act”) was enacted. The Dodd-Frank Act provides for new statutory and regulatory requirements for derivative transactions, including oil and gas hedging transactions. Among other things, the Dodd-Frank Act provides for the creation of position limits for certain derivatives transactions, as well as requiring certain transactions to be cleared on exchanges for which cash collateral will be required. The final impact of the Dodd-Frank Act on our hedging activities is uncertain at this time due to the requirement that the SEC and the Commodities Futures Trading Commission (“CFTC”) promulgate rules and regulations implementing the new legislation within 360 days from the date of enactment. These new rules and regulations could significantly increase the cost of derivative contracts, materially alter the terms of derivative contracts or reduce the availability of derivatives. Although we believe the derivative contracts that we enter into should not be impacted by position limits and should be exempt from the requirement to clear transactions through a central exchange or to post collateral, the impact upon our businesses will depend on the outcome of the implementing regulations adopted by the CFTC.

 

Depending on the rules and definitions adopted by the CFTC or similar rules that may be adopted by other regulatory bodies, we might in the future be required to provide cash collateral for our commodities hedging transactions under circumstances in which we do not currently post cash collateral. Posting of such additional cash collateral could impact liquidity and reduce our cash available for capital expenditures. A requirement to post cash collateral could therefore reduce our ability to execute hedges to reduce commodity price uncertainty and thus protect cash flows. If we reduce our use of derivatives as a result of the Dodd-Frank Act and regulations, our results of operations may become more volatile and our cash flows may be less predictable.

 

We are exposed to the credit risk of our customers and counterparties, and our credit risk management may not be adequate to protect against such risk.

 

We are subject to the risk of loss resulting from nonpayment and/or nonperformance by our customers and counterparties in the ordinary course of our business. Our credit procedures and policies may not be adequate to fully eliminate customer and counterparty credit risk. We cannot predict to what extent our business would be impacted by deteriorating conditions in the economy, including declines in our customers’ and counterparties’ creditworthiness. If we fail to adequately assess the creditworthiness of existing or future customers and counterparties, unanticipated deterioration in their creditworthiness and any resulting increase in nonpayment and/or nonperformance by them could cause us to write-down or write-off doubtful accounts. Such write-downs or write-offs could negatively affect our operating results in the periods in which they occur and, if significant, could have a material adverse effect on our business, results of operations, cash flows and financial condition.

We face competition in acquiring new properties, marketing natural gas and oil and securing equipment and trained personnel in the natural gas and oil industry.

 

Our ability to acquire additional drilling locations and to find and develop reserves in the future will depend on our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment for acquiring properties, marketing natural gas and oil and securing equipment and trained personnel. We may not be able to compete successfully in the future in acquiring prospective reserves, developing reserves, marketing hydrocarbons, attracting and retaining quality personnel and raising additional capital, which could have a material adverse effect on our business.

 

Our operations are subject to operational hazards and unforeseen interruptions for which they may not be adequately insured.

 

There are operational risks associated with drilling for, production, gathering, transporting, storage, processing and treating of natural gas and oil and the fractionation and storage of NGLs, including:

 

 

Any of these risks could result in loss of human life, personal injuries, significant damage to property, environmental pollution, impairment of our operations and substantial losses to us. In accordance with customary industry practice, we maintain insurance against some, but not all, of these risks and losses, and only at levels we believe to be appropriate. The location of certain segments of our facilities in or near populated areas, including residential areas, commercial business centers and industrial sites, could increase the level of damages resulting from these risks. In spite of our precautions, an event such as those described above could cause considerable harm to people or property and could have a material adverse effect on our financial condition and results of operations, particularly if the event is not fully covered by insurance. Accidents or other operating risks could further result in loss of service available to our customers.

 

We do not insure against all potential losses and could be seriously harmed by unexpected liabilities or by the inability of our insurers to satisfy our claims.

 

We are not fully insured against all risks inherent to our business, including environmental accidents. We do not maintain insurance in the type and amount to cover all possible risks of loss.

 

We currently maintain excess liability insurance with limits of $610 million per occurrence and in the annual aggregate with a $2 million per occurrence deductible. This insurance covers us, our parent, our subsidiaries and certain of our affiliates for legal and contractual liabilities arising out of bodily injury or property damage, including resulting loss of use to third parties. This excess liability insurance includes coverage for sudden and accidental pollution liability for full limits, with the first $135 million of insurance also providing gradual pollution liability coverage for natural gas and NGL operations.

 

Although we maintain property insurance on property we own, lease or are responsible to insure, the policy may not cover the full replacement cost of all damaged assets or the entire amount of business interruption loss we may experience. In addition, certain perils may be excluded from coverage or sub-limited.

We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. We may elect to self insure a portion of our risks. We do not insure our underground pipelines for physical damage, except at certain locations. All of our insurance is subject to deductibles. If a significant accident or event occurs for which we are not fully insured it could adversely affect our operations and financial condition.

 

In addition, any insurance company that provides coverage to us may experience negative developments that could impair their ability to pay any of our claims. As a result, we could be exposed to greater losses than anticipated and may have to obtain replacement insurance, if available, at a greater cost.

 

Potential changes in accounting standards might cause us to revise our financial results and disclosures in the future, which might change the way analysts measure our business or financial performance.

 

Regulators and legislators continue to take a renewed look at accounting practices, financial and reserves disclosures and companies’ relationships with their independent public accounting firms and reserves consultants. It remains unclear what new laws or regulations will be adopted, and we cannot predict the ultimate impact of that any such new laws or regulations could have. In addition, the Financial Accounting Standards Board or the SEC could enact new accounting standards that might impact how we are required to record revenues, expenses, assets, liabilities and equity. Any significant change in accounting standards or disclosure requirements could have a material adverse effect on our business, results of operations and financial condition.

 

Our investments and projects located outside of the United States expose us to risks related to the laws of other countries, and the taxes, economic conditions, fluctuations in currency rates, political conditions and policies of foreign governments. These risks might delay or reduce our realization of value from our international projects.

 

We currently own and might acquire and/or dispose of material energy-related investments and projects outside the United States, principally Argentina and Colombia. The economic, political and legal conditions and regulatory environment in the countries in which we have interests or in which we might pursue acquisition or investment opportunities present risks that are different from or greater than those in the United States. These risks include delays in construction and interruption of business, as well as risks of war, expropriation, nationalization, renegotiation, trade sanctions or nullification of existing contracts and changes in law or tax policy, including with respect to the prices we realize for the commodities we produce and sell. The uncertainty of the legal environment in certain foreign countries in which we develop or acquire projects or make investments could make it more difficult to obtain nonrecourse project financing or other financing on suitable terms, could adversely affect the ability of certain customers to honor their obligations with respect to such projects or investments and could impair our ability to enforce our rights under agreements relating to such projects or investments.

 

Operations and investments in foreign countries also can present currency exchange rate and convertibility, inflation and repatriation risk. In certain situations under which we develop or acquire projects or make investments, economic and monetary conditions and other factors could affect our ability to convert to U.S. dollars our earnings denominated in foreign currencies. In addition, risk from fluctuations in currency exchange rates can arise when our foreign subsidiaries expend or borrow funds in one type of currency, but receive revenue in another. In such cases, an adverse change in exchange rates can reduce our ability to meet expenses, including debt service obligations. We may or may not put contracts in place designed to mitigate our foreign currency exchange risks. We have some exposures that are not hedged and which could result in losses or volatility in our results of operations.

 

Our operating results might fluctuate on a seasonal and quarterly basis.

 

Our revenues can have seasonal characteristics. In many parts of the country, demand for natural gas and other fuels peaks during the winter. As a result, our overall operating results in the future might fluctuate substantially on a seasonal basis. Demand for natural gas and other fuels could vary significantly from our expectations depending on the nature and location of our facilities and the terms of our natural gas transportation arrangements relative to demand created by unusual weather patterns.

Our debt agreements impose restrictions on us that may limit our access to credit and adversely affect our ability to operate our business.

 

Our Credit Facility contains various covenants that restrict or limit, among other things, our ability to grant liens to support indebtedness, merge or sell substantially all of our assets, make investments, loans, or advances and enter into certain hedging agreements, make certain distributions, incur additional debt and enter into affiliate transactions. In addition, our Credit Facility contains financial covenants and other limitations with which we will need to comply and which may limit our ability to borrow under the facility. Similarly, the indenture governing the Notes restricts our ability to grant liens to secure certain types of indebtedness and merge or sell substantially all of our assets. These covenants could adversely affect our ability to finance our future operations or capital needs or engage in, expand or pursue our business activities and prevent us from engaging in certain transactions that might otherwise be considered beneficial to us. Our ability to comply with these covenants may be affected by events beyond our control, including prevailing economic, financial and industry conditions. If market or other economic conditions deteriorate, our current assumptions about future economic conditions turn out to be incorrect or unexpected events occur, our ability to comply with these covenants may be significantly impaired.

 

Our failure to comply with the covenants in our debt agreements could result in events of default. Upon the occurrence of such an event of default, the lenders could elect to declare all amounts outstanding under a particular facility to be immediately due and payable and terminate all commitments, if any, to extend further credit. Certain payment defaults or an acceleration under one debt agreement could cause a cross-default or cross-acceleration of another debt agreement. Such a cross-default or cross-acceleration could have a wider impact on our liquidity than might otherwise arise from a default or acceleration of a single debt instrument. If an event of default occurs, or if other debt agreements cross-default, and the lenders under the affected debt agreements accelerate the maturity of any loans or other debt outstanding to us, we may not have sufficient liquidity to repay amounts outstanding under such debt agreements. For more information regarding our anticipated debt agreements, please read “Description of Material Indebtedness.”

 

Our ability to repay, extend or refinance our debt obligations and to obtain future credit will depend primarily on our operating performance, which will be affected by general economic, financial, competitive, legislative, regulatory, business and other factors, many of which are beyond our control. Our ability to refinance our debt obligations or obtain future credit will also depend upon the current conditions in the credit markets and the availability of credit generally. If we are unable to meet our debt service obligations or obtain future credit on favorable terms, if at all, we could be forced to restructure or refinance our indebtedness, seek additional equity capital or sell assets. We may be unable to obtain financing or sell assets on satisfactory terms, or at all.

 

Difficult conditions in the global capital markets, the credit markets and the economy in general could negatively affect our business and results of operations

 

Our business may be negatively impacted by adverse economic conditions or future disruptions in global financial markets. Included among these potential negative impacts are reduced energy demand and lower commodity prices, increased difficulty in collecting amounts owed to us by our customers and reduced access to credit markets. Our ability to access the capital markets may be restricted at a time when we would like, or need, to raise financing. If financing is not available when needed, or is available only on unfavorable terms, we may be unable to implement our business plans or otherwise take advantage of business opportunities or respond to competitive pressures.

 

We are subject to risks associated with climate change.

 

There is a growing belief that emissions of greenhouse gases (“GHGs”) may be linked to climate change. Climate change and the costs that may be associated with its impacts and the regulation of GHGs have the potential to affect our business in many ways, including negatively impacting the costs we incur in providing our products and services, the demand for and consumption of our products and services (due to change in both costs and weather patterns), and the economic health of the regions in which we operate, all of which can create financial risks.

In addition, legislative and regulatory responses related to GHGs and climate change create the potential for financial risk. The U.S. Congress has previously considered legislation and certain states have for some time been considering various forms of legislation related to GHG emissions. There have also been international efforts seeking legally binding reductions in emissions of GHGs. In addition, increased public awareness and concern may result in more state, regional and/or federal requirements to reduce or mitigate GHG emissions.

 

Numerous states have announced or adopted programs to stabilize and reduce GHGs. In addition, on December 7, 2009, the EPA issued a final determination that six GHGs are a threat to public safety and welfare. Also in 2009, the EPA finalized a GHG emission standard for mobile sources. On September 22, 2009, the EPA finalized a GHG reporting rule that requires large sources of GHG emissions to monitor, maintain records on, and annually report their GHG emissions. On November 8, 2010, the EPA also issued GHG monitoring and reporting regulations that went into effect on December 30, 2010, specifically for oil and natural gas facilities, including onshore and offshore oil and natural gas production facilities that emit 25,000 metric tons or more of carbon dioxide equivalent per year. The rule requires reporting of GHG emissions by regulated facilities to the EPA by March 2012 for emissions during 2011 and annually thereafter. We are required to report our GHG emissions to the EPA by March 2012 under this rule. The EPA also issued a final rule that makes certain stationary sources and newer modification projects subject to permitting requirements for GHG emissions, beginning in 2011, under the CAA. Several of the EPA’s GHG rules are being challenged in pending court proceedings, and depending on the outcome of such proceedings, such rules may be modified or rescinded or the EPA could develop new rules.

 

The recent actions of the EPA and the passage of any federal or state climate change laws or regulations could result in increased costs to (i) operate and maintain our facilities, (ii) install new emission controls on our facilities and (iii) administer and manage any GHG emissions program. If we are unable to recover or pass through a significant level of our costs related to complying with climate change regulatory requirements imposed on us, it could have a material adverse effect on our results of operations and financial condition. To the extent financial markets view climate change and GHG emissions as a financial risk, this could negatively impact our cost of and access to capital. Legislation or regulations that may be adopted to address climate change could also affect the markets for our products by making our products more or less desirable than competing sources of energy.

 

Our operations are subject to governmental laws and regulations relating to the protection of the environment, which may expose us to significant costs and liabilities that could exceed current expectations.

 

Substantial costs, liabilities, delays and other significant issues could arise from environmental laws and regulations inherent in drilling and well completion, gathering, transportation, and storage, and we may incur substantial costs and liabilities in the performance of these types of operations. Our operations are subject to extensive federal, state and local laws and regulations governing environmental protection, the discharge of materials into the environment and the security of chemical and industrial facilities. These laws include:

 

 

 

Various governmental authorities, including the U.S. Environmental Protection Agency (“EPA”), the U.S. Department of the Interior, the Bureau of Indian Affairs and analogous state agencies and tribal governments, have the power to enforce compliance with these laws and regulations and the permits issued under them, oftentimes requiring difficult and costly actions. Failure to comply with these laws, regulations and permits may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, the imposition of stricter conditions on or revocation of permits, the issuance of injunctions limiting or preventing some or all of our operations, delays in granting permits and cancellation of leases.

 

There is inherent risk of the incurrence of environmental costs and liabilities in our business, some of which may be material, due to the handling of our products as they are gathered, transported, processed and stored, air emissions related to our operations, historical industry operations, and water and waste disposal practices. Joint and several, strict liability may be incurred without regard to fault under certain environmental laws and regulations, including CERCLA, RCRA and analogous state laws, for the remediation of contaminated areas and in connection with spills or releases of natural gas, oil and wastes on, under, or from our properties and facilities. Private parties may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property damage arising from our operations. Some sites at which we operate are located near current or former third-party oil and natural gas operations or facilities, and there is a risk that contamination has migrated from those sites to ours. In addition, increasingly strict laws, regulations and enforcement policies could materially increase our compliance costs and the cost of any remediation that may become necessary. Our insurance may not cover all environmental risks and costs or may not provide sufficient coverage if an environmental claim is made against us.

 

In March 2010, the EPA announced its National Enforcement Initiatives for 2011 to 2013, which includes the addition of “Energy Extraction Activities” to its enforcement priorities list. To address its concerns regarding the pollution risks raised by new techniques for oil and gas extraction and coal mining, the EPA is developing an initiative to ensure that energy extraction activities are complying with federal environmental requirements. This initiative could involve a large scale investigation of our facilities and processes, and could lead to potential enforcement actions, penalties or injunctive relief against us.

 

Our business may be adversely affected by increased costs due to stricter pollution control equipment requirements or liabilities resulting from non-compliance with required operating or other regulatory permits. Also, we might not be able to obtain or maintain from time to time all required environmental regulatory approvals for our operations. If there is a delay in obtaining any required environmental regulatory approvals, or if we fail to obtain and comply with them, the operation or construction of our facilities could be prevented or become subject to additional costs.

 

We are generally responsible for all liabilities associated with the environmental condition of our facilities and assets, whether acquired or developed, regardless of when the liabilities arose and whether they are known or unknown. In connection with certain acquisitions and divestitures, we could acquire, or be required to provide indemnification against, environmental liabilities that could expose us to material losses, which may not be covered by insurance. In addition, the steps we could be required to take to bring certain facilities into compliance could be prohibitively expensive, and we might be required to shut down, divest or alter the operation of those facilities, which might cause us to incur losses.

We make assumptions and develop expectations about possible expenditures related to environmental conditions based on current laws and regulations and current interpretations of those laws and regulations. If the interpretation of laws or regulations, or the laws and regulations themselves, change, our assumptions may change, and any new capital costs may be incurred to comply with such changes. In addition, new environmental laws and regulations might adversely affect our products and activities, including drilling, processing, storage and transportation, as well as waste management and air emissions. For instance, federal and state agencies could impose additional safety requirements, any of which could affect our profitability.

 

Our exploration and production operations outside the United States are subject to various types of regulations similar to those described above imposed by the governments of the countries in which we operate, and may affect our operations and costs within those countries.

 

Legislation and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

 

Legislation has been introduced in the United States Congress called the Fracturing Responsibility and Awareness of Chemicals Act (the “FRAC Act”) to amend the SDWA to eliminate an existing exemption for hydraulic fracturing activities from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as require disclosure of the chemical constituents of the fluids used in the fracturing process. Hydraulic fracturing involves the injection of water, sand and additives under pressure into rock formations in order to stimulate natural gas production. We find that the use of hydraulic fracturing is necessary to produce commercial quantities of natural gas and oil from many reservoirs. If adopted, this legislation could establish an additional level of regulation and permitting at the federal level, and could make it easier for third parties opposed to the hydraulic fracturing process to initiate legal proceedings based on allegations that specific chemicals used in the fracturing process could adversely affect the environment, including groundwater, soil or surface water. At this time, it is not clear what action, if any, the United States Congress will take on the FRAC Act. Scrutiny of hydraulic fracturing activities continues in other ways, with the EPA having commenced a multi-year study of the potential environmental impacts of hydraulic fracturing, the initial results of which are anticipated to be available by late 2012. On October 21, 2011, the EPA announced its intention to propose regulations by 2014 under the CWA to regulate wastewater discharges from hydraulic fracturing and other natural gas production. In addition to the EPA study, the Shale Gas Subcommittee of the Secretary of Energy Advisory Board issued a report on hydraulic fracturing in August 2011, which includes recommendations to address concerns related to hydraulic fracturing and shale gas production, including but not limited to conducting additional field studies on possible methane leakage from shale gas wells to water reservoirs and adopting new rules and enforcement practices to protect drinking and surface waters. The U.S. Government Accountability Office is also examining the environmental impacts of produced water and the White House Counsel for Environmental Quality has been petitioned by environmental groups to develop a programmatic environmental impact statement under NEPA for hydraulic fracturing. Several states have also adopted or considered legislation requiring the disclosure of fracturing fluids and other restrictions on hydraulic fracturing, including states in which we operate (e.g., Wyoming, Pennsylvania, Texas, Colorado, North Dakota and New Mexico). The U.S. Department of the Interior is also considering disclosure requirements or other mandates for hydraulic fracturing on federal land, which, if adopted, would affect our operations on federal lands. If new federal or state laws or regulations that significantly restrict hydraulic fracturing are adopted, such legal requirements could result in delays, eliminate certain drilling and injection activities, make it more difficult or costly for us to perform fracturing and increase our costs of compliance and doing business as well as delay or prevent the development of unconventional gas resources from shale formations which are not commercial without the use of hydraulic fracturing.

 

Our ability to produce gas could be impaired if we are unable to acquire adequate supplies of water for our drilling and completion operations or are unable to dispose of the water we use at a reasonable cost and within applicable environmental rules.

 

Our inability to locate sufficient amounts of water, or dispose of or recycle water used in our exploration and production operations, could adversely impact our operations, particularly with respect to our Marcellus Shale, San Juan Basin, Bakken Shale and Piceance Basin operations. Moreover, the imposition of new environmental

initiatives and regulations could include restrictions on our ability to conduct certain operations such as hydraulic fracturing or disposal of waste, including, but not limited to, produced water, drilling fluids and other wastes associated with the exploration, development or production of natural gas. The CWA imposes restrictions and strict controls regarding the discharge of produced waters and other natural gas and oil waste into navigable waters. Permits must be obtained to discharge pollutants to waters and to conduct construction activities in waters and wetlands. The CWA and similar state laws provide for civil, criminal and administrative penalties for any unauthorized discharges of pollutants and unauthorized discharges of reportable quantities of oil and other hazardous substances. Many state discharge regulations and the Federal National Pollutant Discharge Elimination System general permits issued by the EPA prohibit the discharge of produced water and sand, drilling fluids, drill cuttings and certain other substances related to the natural gas and oil industry into coastal waters. The EPA has also adopted regulations requiring certain natural gas and oil exploration and production facilities to obtain permits for storm water discharges. In addition, on October 21, 2011, the EPA announced its intention to propose regulations by 2014 under the CWA to regulate wastewater discharges from hydraulic fracturing and other natural gas production. Compliance with current and future environmental regulations and permit requirements governing the withdrawal, storage and use of surface water or groundwater necessary for hydraulic fracturing of wells may increase our operating costs and cause delays, interruptions or termination of our operations, the extent of which cannot be predicted.

 

Legal and regulatory proceedings and investigations relating to the energy industry, and the complex government regulations to which our businesses are subject, have adversely affected our business and may continue to do so. The operation of our businesses might also be adversely affected by changes in regulations or in their interpretation or implementation, or the introduction of new laws, regulations or permitting requirements applicable to our businesses or our customers.

 

Public and regulatory scrutiny of the energy industry has resulted in increased regulations being either proposed or implemented. Adverse effects may continue as a result of the uncertainty of ongoing inquiries, investigations and court proceedings, or additional inquiries and proceedings by federal or state regulatory agencies or private plaintiffs. In addition, we cannot predict the outcome of any of these inquiries or whether these inquiries will lead to additional legal proceedings against us, civil or criminal fines or penalties, or other regulatory action, including legislation or increased permitting requirements. Current legal proceedings or other matters against us, including environmental matters, suits, regulatory appeals, challenges to our permits by citizen groups and similar matters, might result in adverse decisions against us. The result of such adverse decisions, either individually or in the aggregate, could be material and may not be covered fully or at all by insurance.

 

In addition, existing regulations might be revised or reinterpreted, new laws, regulations and permitting requirements might be adopted or become applicable to us, our facilities, our customers, our vendors or our service providers, and future changes in laws and regulations could have a material adverse effect on our financial condition, results of operations and cash flows. For example, several ruptures on third party pipelines have occurred recently. In response, various legislative and regulatory reforms associated with pipeline safety and integrity have been proposed, including new regulations covering gathering pipelines that have not previously been subject to regulation. Such reforms, if adopted, could significantly increase our costs.

 

Certain of our properties, including our operations in the Bakken Shale, are located on Native American tribal lands and are subject to various federal and tribal approvals and regulations, which may increase our costs and delay or prevent our efforts to conduct planned operations.

 

Various federal agencies within the U.S. Department of the Interior, particularly the Bureau of Indian Affairs, Bureau of Land Management (“BLM”) and the Office of Natural Resources Revenue, along with each Native American tribe, promulgate and enforce regulations pertaining to gas and oil operations on Native American tribal lands. These regulations and approval requirements relate to such matters as lease provisions, drilling and production requirements, environmental standards and royalty considerations. In addition, each Native American tribe is a sovereign nation having the right to enforce laws and regulations and to grant approvals independent from federal, state and local statutes and regulations. These tribal laws and regulations include various taxes, fees, requirements to employ Native American tribal members and other conditions that apply to lessees, operators and contractors conducting operations on Native American tribal lands. Lessees and

operators conducting operations on tribal lands are generally subject to the Native American tribal court system. In addition, if our relationships with any of the relevant Native American tribes were to deteriorate, we could face significant risks to our ability to continue the projected development of our leases on Native American tribal lands. One or more of these factors may increase our costs of doing business on Native American tribal lands and impact the viability of, or prevent or delay our ability to conduct, our natural gas or oil development and production operations on such lands.

 

Tax laws and regulations may change over time, including the elimination of federal income tax deductions currently available with respect to oil and gas exploration and development.

 

Tax laws and regulations are highly complex and subject to interpretation, and the tax laws, treaties and regulations to which we are subject may change over time. Our tax filings are based upon our interpretation of the tax laws in effect in various jurisdictions at the time that the filings were made. If these laws, treaties or regulations change, or if the taxing authorities do not agree with our interpretation of the effects of such laws, treaties and regulations, it could have a material adverse effect on us.

 

Among the changes contained in President Obama’s budget proposal for fiscal year 2012, released by the White House on February 14, 2011, is the elimination of certain U.S. federal income tax provisions currently available to oil and gas exploration and production companies. Such changes include, but are not limited to, (i) the repeal of the percentage depletion allowance for oil and gas properties; (ii) the elimination of current expensing of intangible drilling and development costs; (iii) the elimination of the deduction for certain U.S. production activities; and (iv) an extension of the amortization period for certain geological and geophysical expenditures. Members of Congress have introduced legislation with similar provisions in the current session. It is unclear, however, whether any such changes will be enacted or how soon such changes could be effective.

 

The passage of any legislation as a result of the budget proposal or any other similar change in U.S. federal income tax law could eliminate certain tax deductions that are currently available with respect to oil and gas exploration and development. The elimination of such federal tax deductions, as well as any changes to or the imposition of new state or local taxes (including the imposition of, or increases in production, severance, or similar taxes) could negatively affect our financial condition and results of operations.

 

Our acquisition attempts may not be successful or may result in completed acquisitions that do not perform as anticipated.

 

We have made and may continue to make acquisitions of businesses and properties. However, suitable acquisition candidates may not continue to be available on terms and conditions we find acceptable. The following are some of the risks associated with acquisitions, including any completed or future acquisitions:

 

 

Substantial acquisitions or other transactions could require significant external capital and could change our risk and property profile.

 

In order to finance acquisitions of additional producing or undeveloped properties, we may need to alter or increase our capitalization substantially through the issuance of debt or equity securities, the sale of production payments or other means. These changes in capitalization may significantly affect our risk profile. Additionally, significant acquisitions or other transactions can change the character of our operations and business. The character of the new properties may be substantially different in operating or geological characteristics or geographic location than our existing properties. Furthermore, we may not be able to obtain external funding for future acquisitions or other transactions or to obtain external funding on terms acceptable to us.

 

Failure of our service providers or disruptions to our outsourcing relationships might negatively impact our ability to conduct our business.

 

We rely on Williams for certain services necessary for us to be able to conduct our business. Williams may outsource some or all of these services to third parties, and a failure of all or part of Williams’ relationships with its outsourcing providers could lead to delays in or interruptions of these services. Our reliance on Williams and others as service providers and on Williams’ outsourcing relationships, and our limited ability to control certain costs, could have a material adverse effect on our business, results of operations and financial condition.

 

Some studies indicate a high failure rate of outsourcing relationships. A deterioration in the timeliness or quality of the services performed by the outsourcing providers or a failure of all or part of these relationships could lead to loss of institutional knowledge and interruption of services necessary for us to be able to conduct our business. The expiration of such agreements or the transition of services between providers could lead to similar losses of institutional knowledge or disruptions.

 

Certain of our accounting, information technology, application development and help desk services are currently provided by Williams’ outsourcing provider from service centers outside of the United States. The economic and political conditions in certain countries from which Williams’ outsourcing providers may provide services to us present similar risks of business operations located outside of the United States, including risks of interruption of business, war, expropriation, nationalization, renegotiation, trade sanctions or nullification of existing contracts and changes in law or tax policy, that are greater than in the United States.

 

Our assets and operations can be adversely affected by weather and other natural phenomena.

 

Our assets and operations can be adversely affected by hurricanes, floods, earthquakes, tornadoes and other natural phenomena and weather conditions, including extreme temperatures. Insurance may be inadequate, and in some instances, we have been unable to obtain insurance on commercially reasonable terms, or insurance has not been available at all. A significant disruption in operations or a significant liability for which we were not fully insured could have a material adverse effect on our business, results of operations and financial condition.

 

Our customers’ energy needs vary with weather conditions. To the extent weather conditions are affected by climate change or demand is impacted by regulations associated with climate change, customers’ energy use could increase or decrease depending on the duration and magnitude of the changes, leading either to increased investment or decreased revenues.

 

Acts of terrorism could have a material adverse effect on our financial condition, results of operations and cash flows.

 

Our assets and the assets of our customers and others may be targets of terrorist activities that could disrupt our business or cause significant harm to our operations, such as full or partial disruption to the ability to produce, process, transport or distribute natural gas, oil, or NGLs. Acts of terrorism as well as events occurring in response to or in connection with acts of terrorism could cause environmental repercussions that could result in a significant decrease in revenues or significant reconstruction or remediation costs.

We have identified two material weaknesses in our internal controls over financial reporting. Our failure to achieve and maintain effective internal controls could have a material adverse effect on our business in the future, on the price of our common stock and our access to the capital markets.

 

Although we are not currently subject to the requirements of Section 404 of the Sarbanes-Oxley Act of 2002 (“Sarbanes-Oxley”), during the preparation of our financial statements for each of the three years in the period ended December 31, 2010 and for the three months ended March 31, 2011, two material weaknesses (as defined under Public Company Accounting Oversight Board Standard No. 5) in our internal controls were identified: one relating to the timing of the recognition of certain compression deficiency obligations under compression service agreements, and one reflecting the aggregation of two significant deficiencies relating to aspects of depreciation, depletion and amortization of property, plant and equipment. As a result of these material weaknesses, adjustments to the estimated carrying value of property, plant and equipment aggregating approximately $20 million on a pre-tax basis have been reflected in our financial statements as of December 31, 2010 and adjustments to gathering, processing and transportation expense aggregating approximately $14 million on a pre-tax basis have been reflected in our income statements for the years ended December 31, 2008, 2009 and 2010. We have taken steps to remediate the internal controls related to the material weaknesses, although we cannot provide assurance that these steps will prove to be effective. See Note 2 of Notes to Combined Financial Statements.

 

We cannot be certain that future significant deficiencies or material weaknesses will not develop or be identified. As of December 31, 2012, we will be required to assess the effectiveness of our internal control over financial reporting under Sarbanes-Oxley, and we will be required to have our independent registered public accounting firm audit the operating effectiveness of our internal control over financial reporting. If we or our independent registered public accounting firm were to conclude that our internal control over financial reporting was not effective, investors could lose confidence in our reported financial information, the price of our common stock could decline and access to the capital markets or other sources of financing could be limited.

 

Risks Related to Our Relationship with Williams

 

We may not realize the potential benefits from our separation from Williams.

 

We may not realize the benefits that we anticipate from our separation from Williams. These benefits include the following:

 

 

We may not achieve the anticipated benefits from our separation for a variety of reasons. For example, the process of separating our business from Williams and operating as an independent public company may distract our management from focusing on our business and strategic priorities. In addition, although we will have direct access to the debt and equity capital markets following the separation, we may not be able to issue debt or equity on terms acceptable to us or at all. The availability of shares of our common stock for use as consideration for acquisitions also will not ensure that we will be able to successfully pursue acquisitions or that the acquisitions will be successful. Moreover, even with equity compensation tied to our business we may not be able to attract and retain employees as desired. We also may not fully realize the anticipated benefits from our separation if any of the matters identified as risks in this “Risk Factors” section were to occur. If we do not realize the anticipated benefits from our separation for any reason, our business may be materially adversely affected.

Our historical and pro forma combined financial information may not be representative of the results we would have achieved as a stand-alone public company and may not be a reliable indicator of our future results.

 

The historical and pro forma combined financial information that we have included in this prospectus has been derived from Williams’ accounting records and may not necessarily reflect what our financial position, results of operations or cash flows would have been had we been an independent, stand-alone entity during the periods presented or those that we will achieve in the future. Williams did not account for us, and we were not operated, as a separate, stand-alone company for the historical periods presented. The costs and expenses reflected in our historical financial information include an allocation for certain corporate functions historically provided by Williams, including executive oversight, cash management and treasury administration, financing and accounting, tax, internal audit, investor relations, payroll and human resources administration, information technology, legal, regulatory and government affairs, insurance and claims administration, records management, real estate and facilities management, sourcing and procurement, mail, print and other office services, and other services, that may be different from the comparable expenses that we would have incurred had we operated as a stand-alone company. These allocations were based on what we and Williams considered to be reasonable reflections of the historical utilization levels of these services required in support of our business. We have not adjusted our historical or pro forma combined financial information to reflect changes that will occur in our cost structure and operations as a result of our transition to becoming a stand-alone public company, including changes in our employee base, potential increased costs associated with reduced economies of scale and increased costs associated with the SEC reporting and the NYSE requirements. Therefore, our historical and pro forma combined financial information may not necessarily be indicative of what our financial position, results of operations or cash flows will be in the future. For additional information, see “Selected Historical Combined Financial Data” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” and our financial statements and related notes included elsewhere in this prospectus.

 

Following this offering, we will continue to depend on Williams to provide us with certain services for our business; the services that Williams will provide to us following the separation may not be sufficient to meet our needs, and we may have difficulty finding replacement services or be required to pay increased costs to replace these services after our agreements with Williams expire.

 

Certain administrative services required by us for the operation of our business are currently provided by Williams and its subsidiaries, including services related to cash management and treasury administration, finance and accounting, tax, internal audit, investor relations, payroll and human resources administration, information technology, legal, regulatory and government affairs, insurance and claims administration, records management, real estate and facilities management, sourcing and procurement, mail, print and other office services. Prior to the completion of this offering, we will enter into agreements with Williams related to the separation of our business operations from Williams, including an administrative services agreement and a transition services agreement. The services provided under the administrative services agreement will commence on the date this offering is completed and terminate upon the earlier of (i) the date immediately prior to the date Williams distributes all of our shares of common stock that it owns to its stockholders (which we refer to as the distribution date) or (ii) sixty days’ notice by Williams if it determines that the provision of such services involves certain conflicts of interest between Williams and us or would cause Williams to violate applicable law. The services provided under the transition services agreement will commence on the distribution date and terminate upon the earlier of (i) one year after the distribution date or (ii) sixty days’ notice by either party. In addition, Williams may immediately terminate any of the services it provides to us under the transition services agreement if it determines that the provision of such services involves certain conflicts of interest between Williams and us or would cause Williams to violate applicable law. We believe it is necessary for Williams to provide services for us under the administrative services agreement and the transition services agreement to facilitate the efficient operation of our business as we transition to becoming a stand alone public company. We will, as a result, initially depend on Williams for services following this offering. While these services are being provided to us by Williams, our operational flexibility to modify or implement changes with respect to such services or the amounts we pay for them will be limited. After the

expiration or termination of these agreements, we may not be able to replace these services or enter into appropriate third-party agreements on terms and conditions, including cost, comparable to those that we will receive from Williams under our agreements with Williams. Although we intend to replace portions of the services currently provided by Williams, we may encounter difficulties replacing certain services or be unable to negotiate pricing or other terms as favorable as those we currently have in effect. See “Arrangements Between Williams and Our Company—Administrative Services and Transition Services Agreements.”

 

Your investment in our common stock may be adversely affected if Williams does not spin-off the common stock owned by Williams.

 

Williams has advised us that, following the completion of this offering, it intends to spin-off all of the shares of our common stock that it owns to its stockholders. Williams has indicated that it intends to complete the spin-off no later than the first quarter of 2012. Williams may decide not to complete this offering or the spin-off if, at any time, Williams’ board of directors determines, in its sole discretion, that this offering or the spin-off is not in the best interests of Williams or its stockholders. Unless and until such a spin-off occurs, we will face the risks discussed in this prospectus relating to our continuing relationship with Williams, including its control of us and potential conflicts of interest between Williams and us. In addition, if a spin-off does not occur, the liquidity of the market for our common stock may be constrained for as long as Williams, or a successor controlling shareholder, continues to hold a significant position in our common stock. A lack of liquidity in the market for our common stock may adversely affect our share price.

 

Our share price may decline because of Williams’ ability to sell shares of our common stock.

 

Sales of substantial amounts of our common stock after this offering, or the possibility of those sales, could adversely affect the market price of our common stock and impede our ability to raise capital through the issuance of equity securities. See “Shares Eligible for Future Sale” for a discussion of possible future sales of our common stock.

 

After the completion of this offering, Williams will own     % of our outstanding common stock, or     % if the underwriters exercise their option to purchase additional common shares in full. Williams has advised us that it intends to complete the distribution of all of our common stock owned by Williams to its stockholders no later than the first quarter of 2012. Common stock so distributed will be freely tradable by such Williams stockholders who are not deemed to be our affiliates or are otherwise subject to lock-up agreements.

 

Williams has no contractual obligation to retain its shares of our common stock, except for a limited period described under “Underwriting” during which it will not sell any of its shares of our common stock without the consent of Barclays Capital Inc. until 180 days after the date of this prospectus, subject to extension in certain circumstances. Subject to applicable U.S. federal and state securities laws, after the expiration of this 180-day waiting period (or before, with consent of the underwriters to this offering), Williams may sell any and all of the shares of our common stock that it beneficially owns or distribute any or all of these shares of our common stock to its stockholders. This 180-day waiting period does not apply to the distribution by Williams of its remaining ownership interest in us to its common stockholders. The registration rights agreement described elsewhere in this prospectus grants Williams the right to require us to register the shares of our common stock it holds in specified circumstances. In addition, after the expiration of this 180-day waiting period, we could issue and sell additional shares of our common stock. Any sale by Williams or us of our common stock in the public market, or the perception that sales could occur (for example, as a result of the distribution), could adversely affect prevailing market prices for the shares of our common stock.

 

As long as we are controlled by Williams, your ability to influence the outcome of matters requiring stockholder approval will be limited.

 

After the completion of this offering, Williams will own     % of our outstanding common stock, or     % if the underwriters exercise their option to purchase additional common shares in full. As long as Williams has voting control of our company, Williams will have the ability to take many stockholder actions,

including the election or removal of directors, irrespective of the vote of, and without prior notice to, any other stockholder. As a result, Williams will have the ability to influence or control all matters affecting us, including:

 

 

Williams’ interests may not be the same as, or may conflict with, the interests of our other stockholders. As a result, actions that Williams takes with respect to us, as our controlling stockholder, may not be favorable to us. In addition, this voting control may discourage transactions involving a change of control of our company, including transactions in which you, as a holder of our common stock, might otherwise receive a premium for your shares over the then-current market price. Furthermore, Williams is not prohibited from selling a controlling interest in our company to a third party without your approval or without providing for a purchase of your shares. At any time following the completion of this offering and the expiration or waiver of the applicable lock-up period described under “Underwriting,” Williams has the right to spin-off shares of our common stock that it owns to its stockholders. In addition, after the expiration or waiver of the applicable lock-up period described under “Underwriting,” Williams has the right to sell a controlling interest in us to a third party, without your approval and without providing for a purchase of your shares. There is no assurance that Williams will effect the spin-off, and if Williams elects not to effect the spin-off, it could remain our stockholder for an extended or indefinite period of time. In addition, Williams may decide not to complete the spin-off if, at any time, Williams’ board of directors determines, in its sole discretion, that the spin-off is not in the best interests of Williams or its stockholders. As a result, the spin-off may not occur by 2012 or at all. See “Shares Eligible For Future Sale.”

 

We may have potential business conflicts of interest with Williams regarding our past and ongoing relationships, and because of Williams’ controlling ownership in us, the resolution of these conflicts may not be favorable to us.

 

Conflicts of interest may arise between Williams and us in a number of areas relating to our past and ongoing relationships, including:

 

 

We may not be able to resolve any potential conflicts, and, even if we do so, the resolution may be less favorable to us than if we were dealing with an unaffiliated party.

 

Finally, in connection with this offering, we will enter into several agreements with Williams. These agreements will be made in the context of a parent-subsidiary relationship and will be entered into in the overall context of our separation from Williams. The terms of these agreements may be more or less favorable to us than if they had been negotiated with unaffiliated third parties. While we are controlled by Williams,

Williams may seek to cause us to amend these agreements on terms that may be less favorable to us than the original terms of the agreement.

 

During the terms of the administrative services agreement and the transition services agreement, and for one year thereafter, neither we nor Williams will be permitted to solicit each other’s employees for employment without the other’s consent.

 

Pursuant to the terms of our amended and restated certificate of incorporation, Williams is not required to offer corporate opportunities to us, and certain of our directors and officers are permitted to offer certain corporate opportunities to Williams before us.

 

Our amended and restated certificate of incorporation provides that, until both (1) Williams and its subsidiaries no longer beneficially own 50% or more of the voting power of all then outstanding shares of our capital stock generally entitled to vote in the election of our directors and (2) no person who is a director or officer of Williams or of a subsidiary of Williams is also a director or officer of ours:

 

 

At the completion of this offering, our board of directors will include persons who are also directors and/or officers of Williams. In addition, after the completion of the spin-off of our stock to Williams’ stockholders, we expect that our board of directors will continue to include persons who are also directors and/or officers of Williams. As a result, Williams may gain the benefit of corporate opportunities that are presented to these directors.

 

Our agreements with Williams require us to assume the past, present, and future liabilities related to our business and may be less favorable to us than if they had been negotiated with unaffiliated third parties.

 

We negotiated all of our agreements with Williams as a wholly-owned subsidiary of Williams and will enter into these agreements prior to the completion of this offering. If these agreements had been negotiated with unaffiliated third parties, they might have been more favorable to us. Pursuant to the separation and distribution agreement, we have assumed all past, present and future liabilities (other than tax liabilities which will be governed by the tax sharing agreement as described herein; see “Arrangements Between Williams and Our Company—Tax Sharing Agreement”) related to our business, and we will agree to indemnify Williams for these liabilities, among other matters. Such liabilities include unknown liabilities that could be significant. The allocation of assets and liabilities between Williams and us may not reflect the allocation that would have been reached between two unaffiliated parties. See “Arrangements Between Williams and Our Company” for a description of these obligations and the allocation of liabilities between Williams and us.

Our agreements with Williams may limit our ability to obtain additional financing or make acquisitions.

 

We may engage, or desire to engage, in future financings or acquisitions. However, because our agreements with Williams are designed to preserve the tax-free status of the spin-off and any related restructuring transaction, we will agree to certain restrictions in those agreements that may severely limit our ability to effect future financings or acquisitions. For example, for the spin-off of our stock to Williams’ stockholders to be tax-free to Williams and its stockholders, among other things, Williams must own at least 80% of the voting power of all then outstanding shares of our capital stock entitled to vote generally in the election of directors (and at least 80% of the then outstanding shares of any class of non-voting stock) at the time of the spin-off. In addition, after the spin-off, our stock may not undergo a 50% or greater change of ownership (measured by vote or value) in transactions considered related to the spin-off. Therefore, the tax sharing agreement and the separation and distribution agreement restrict our ability to issue or sell additional common stock or other securities (including securities convertible into our common stock) prior to the spin-off to the extent that such issuances or sales would reduce Williams’ ownership below certain threshold levels, and for a period after the spin-off to the extent that such issuances would cause us to undergo significant ownership changes.

 

In addition, we will agree in the separation and distribution agreement that we will not (without Williams’ prior written consent) take any of the following actions prior to the spin-off:

 

 

The separation and distribution agreement will also provide that for so long as Williams owns 50% or more of the voting power of all then outstanding shares of our capital stock entitled to vote generally in the election of directors, we will not (without the prior written consent of Williams) take any actions that could reasonably result in Williams being in breach or in default under any contract or agreement. Also, for so long as Williams is required to consolidate our results of operations and financial position, we may not incur any additional indebtedness (other than under our Credit Facility and the issuance of the Notes) without the prior written consent of Williams.

 

Our tax sharing agreement with Williams may limit our ability to take certain actions and may require us to indemnify Williams for significant tax liabilities.

 

Under the tax sharing agreement, we will agree to take reasonable action or reasonably refrain from taking action to ensure that the spin-off of our stock to Williams’ stockholders and any related restructuring transaction qualify for tax-free status under section 355 and section 368(a)(1)(D) of the Internal Revenue Code of 1986, as amended (the “Code”) (unless Williams receives a private letter ruling from the Internal Revenue Service (“IRS”) or the IRS issues other guidance that can be relied on conclusively to the effect that a contemplated matter or transaction would not jeopardize such tax-free status of the spin-off and related restructuring transaction). We will also make various other covenants in the tax sharing agreement intended to ensure the tax-free status of the spin-off and any related restructuring transaction. These covenants restrict our ability to sell assets outside the ordinary course of business, to issue or sell additional common stock or other securities (including securities convertible into our common stock), or to enter into certain other corporate transactions. For example, prior to the spin-off, we may not enter into any transactions that would reduce Williams’ ownership to less than 80% of the voting power of all then outstanding shares of our capital stock entitled to vote generally in the election of directors or 80% of the then outstanding shares of any class of non-voting stock. Similarly, after the spin-off, we may not enter into any transaction that would cause us to undergo either a 50% or greater change in the ownership of our voting stock or a 50% or greater change in the ownership (measured by value) of all classes of our stock (in either case, taking into account shares issued in this offering) in transactions considered related to the spin-off. See “Arrangements Between Williams and Our Company—Tax Sharing Agreement” for a discussion of these restrictions.

Further, under the tax sharing agreement, we are required to indemnify Williams against certain tax-related liabilities incurred by Williams (including any of its subsidiaries) relating to the spin-off of our stock to Williams’ stockholders or relating to any related restructuring transaction undertaken by Williams, to the extent caused by our breach of any representations or covenants made in the tax sharing agreement or the separation and distribution agreement, or made in connection with the private letter ruling or tax opinion. These liabilities include the substantial tax-related liability (calculated without regard to any net operating loss or other tax attribute of Williams) that would result if the spin-off of our stock to Williams’ stockholders failed to qualify as a tax-free transaction.

 

We will not have complete control over our tax decisions and could be liable for income taxes owed by Williams.

 

For so long as Williams continues to own at least 80% of the total voting power and value of our common stock, we and our U.S. subsidiaries will be included in Williams’ consolidated group for U.S. federal income tax purposes. In addition, we or one or more of our U.S. subsidiaries may be included in the combined, consolidated or unitary tax returns of Williams or one or more of its subsidiaries for U.S. state or local income tax purposes. Under the tax sharing agreement, for each period in which we or any of our subsidiaries are consolidated or combined with Williams for purposes of any tax return, Williams will prepare a pro forma tax return for us as if we filed our own consolidated, combined or unitary return, except that such pro forma tax return will generally include current income, deductions, credits and losses from us (with certain exceptions), will not include any carryovers or carrybacks of losses or credits and will be calculated without regard to the federal Alternative Minimum Tax. We will reimburse Williams for any taxes shown on the pro forma tax returns, and Williams will reimburse us for any current losses or credits we recognize based on the pro forma tax returns. In addition, by virtue of Williams’ controlling ownership and the tax sharing agreement, Williams will effectively control all of our U.S. tax decisions in connection with any consolidated, combined or unitary income tax returns in which we (or any of our subsidiaries) are included. The tax sharing agreement provides that Williams will have sole authority to respond to and conduct all tax proceedings (including tax audits) relating to us, to prepare and file all consolidated, combined or unitary income tax returns on our behalf (including the making of any tax elections), and to determine the reimbursement amounts in connection with any pro forma tax returns. This arrangement may result in conflicts of interest between Williams and us. For example, under the tax sharing agreement, Williams will be able to choose to contest, compromise or settle any adjustment or deficiency proposed by the relevant taxing authority in a manner that may be beneficial to Williams and detrimental to us. See “Arrangements Between Williams and Our Company—Tax Sharing Agreement.”

 

Moreover, notwithstanding the tax sharing agreement, U.S. federal law provides that each member of a consolidated group is liable for the group’s entire tax obligation. Thus, to the extent Williams or other members of Williams’ consolidated group fail to make any U.S. federal income tax payments required by law, we could be liable for the shortfall. Similar principles may apply for foreign, state or local income tax purposes where we file combined, consolidated or unitary returns with Williams or its subsidiaries for federal, foreign, state or local income tax purposes.

 

 

The spin-off will be conditioned upon, among other things, Williams’ receipt of a private letter ruling from the IRS and an opinion of its outside tax advisor reasonably acceptable to the Williams board of directors, to the effect that the distribution by Williams of the shares of our common stock held by Williams after the offering, and any related restructuring transaction undertaken by Williams, will qualify for U.S. federal income tax purposes as a tax-free transaction under section 355 and section 368(a)(1)(D) of the Code. Williams has received the private letter ruling from the IRS and the opinion from its outside tax advisor to such effect. The ruling and the opinion rely on certain facts, assumptions, representations and undertakings from Williams and us regarding

the past and future conduct of the companies’ respective businesses and other matters. If any of these facts, assumptions, representations, or undertakings are, or become, incorrect or not otherwise satisfied, Williams and its stockholders may not be able to rely on the private letter ruling and opinion of its tax advisor and could be subject to significant tax liabilities. In addition, notwithstanding the opinion of Williams’ tax advisor, the IRS could conclude upon audit that the spin-off is taxable if it determines that any of these facts, assumptions, representations, or undertakings are, or have become, not correct or have been violated or if it disagrees with the conclusions in the opinion, or for other reasons, including as a result of certain significant changes in the stock ownership of Williams or us after the spin-off. If the spin-off is determined to be taxable for U.S. federal income tax purposes for any reason, Williams and/or its stockholders could incur significant income tax liabilities, and we could incur significant liabilities. For a description of the sharing of such liabilities between Williams and us, see “Arrangements Between Williams and Our Company—Tax Sharing Agreement.”

 

 

Third parties may seek to hold us responsible for retained liabilities of Williams. Under our agreements with Williams, Williams will agree to indemnify us for claims and losses relating to these retained liabilities. However, if those liabilities are significant and we are ultimately held liable for them, we cannot assure you that we will be able to recover the full amount of our losses from Williams.

 

 

Williams is obligated to indemnify us for losses that a party may seek to impose upon us or our affiliates for liabilities relating to the business of Williams that are incurred through a breach of the separation and distribution agreement or any ancillary agreement by Williams or its affiliates other than us, or losses that are attributable to Williams in connection with this offering or are not expressly assumed by us under our agreements with Williams. Immediately following this offering, any claims made against us that are properly attributable to Williams in accordance with these arrangements would require us to exercise our rights under our agreements with Williams to obtain payment from Williams. We are exposed to the risk that, in these circumstances, Williams cannot, or will not, make the required payment.

 

 

Ownership of shares of common stock of Williams, options to acquire shares of common stock of Williams and other equity-based securities of Williams by certain of our directors and officers after this offering, and the presence of directors or officers of Williams on our board of directors could create, or appear to create, potential conflicts of interest when those directors and officers are faced with decisions that could have different implications for Williams than they do for us. Certain of our directors will hold director and/or officer positions with Williams or beneficially own significant amounts of common stock of Williams. See “Management.”

 

In addition, because our board of directors does not intend to form a compensation committee or nominating and governance committee in connection with the completion of this offering, the Williams compensation committee will make recommendations to our board of directors regarding compensation for our directors and officers, which could also create, or appear to create, similar potential conflicts of interest. See “Management” for a description of the extent of the relationship between our directors and officers and directors and officers of Williams.

 

After the completion of this offering and prior to the spin-off of our stock to Williams’ stockholders, Williams will own more than 50% of the voting power of all then outstanding shares of our capital stock entitled to vote generally in the election of directors, and we will be a “controlled company” under the NYSE corporate governance standards. As a controlled company, we intend to rely on certain exemptions from the NYSE standards that will enable us not to comply with certain NYSE corporate governance requirements, including the requirements that:

 

 

We intend to rely on some or all of these exemptions, and, as a result, prior to the spin-off, you will not have the same protection afforded to stockholders of companies that are subject to all of the NYSE corporate governance requirements.

 

Risks Related to this Offering

 

 

Prior to this offering, there has been no public market for shares of our common stock. We cannot predict the extent to which investor interest in our company will lead to the development of a trading market on the NYSE or otherwise, or how liquid that market might become. If an active market does not develop, you may have difficulty selling any shares of our common stock that you purchase in this initial public offering. The initial public offering price for the shares of our common stock has been determined by negotiations between us and the representatives of the underwriters, and may not be indicative of prices that will prevail in the open market following this offering.

 

 

The market price of our stock may be influenced by many factors, some of which are beyond our control, including those described above in “—Risks Related to Our Business” and the following:

 

 

 

As a result of these factors, investors in our common stock may not be able to resell their shares at or above the initial offering price or may not be able to resell them at all. These broad market and industry factors may materially reduce the market price of our common stock, regardless of our operating performance. In addition, price volatility may be greater if the public float and trading volume of our common stock is low.

 

 

The market price of our common stock could decline significantly as a result of sales of a large number of shares of our common stock in the market after this offering, including shares which might be offered for sale by Williams. The perception that these sales might occur could depress the market price. These sales, or the possibility that these sales may occur, also might make it more difficult for us to sell equity securities in the future at a time and at a price that we deem appropriate.

 

Upon completion of this offering, we will have           shares of common stock outstanding,           of which will have been sold in this offering (           shares if the underwriters exercise their option to purchase additional common shares in full) and           of which will be owned by Williams (           shares if the underwriters exercise their option to purchase additional common shares in full). The shares of common stock offered in this offering will be freely tradable without restriction under the Securities Act of 1933, as amended (the “Securities Act”), except for any shares of common stock that may be held or acquired by our directors, executive officers and other affiliates, as that term is defined in the Securities Act, which will be restricted securities under the Securities Act. Restricted securities may not be sold in the public market unless the sale is registered under the Securities Act or an exemption from registration is available. We will grant registration rights to Williams with respect to the common stock it owns. Any shares registered pursuant to the registration rights agreement with Williams described in “Arrangements Between Williams and Our Company” will be freely tradable in the public market.

 

In connection with this offering, we, our directors and executive officers, Williams and its directors and executive officers have each agreed to enter into a lock-up agreement and thereby be subject to a lock-up period, meaning that they and their permitted transferees will not be permitted to sell any of the shares of our common stock for 180 days after the date of this prospectus, subject to certain extensions without the prior consent of the underwriters. Although we have been advised that there is no present intention to do so, the underwriters may, in their sole discretion and without notice, release all or any portion of the shares of our common stock from the restrictions in any of the lock-up agreements described above. See “Underwriting.”

 

Also, in the future, we may issue our securities in connection with investments or acquisitions. The amount of shares of our common stock issued in connection with an investment or acquisition could constitute a material portion of our then outstanding shares of our common stock.

 

 

If the underwriters exercise their option to purchase additional common shares, all of our net proceeds from the issuance of such shares will be distributed to Williams in connection with our restructuring transactions. Accordingly, we will receive no benefit from the issuance of any shares of our common stock subject to the underwriters’ option to purchase additional common shares.

 

We have historically operated our business as a segment of a public company. As a stand-alone public company, we may incur additional legal, accounting, compliance and other expenses that we have not incurred historically. After this offering, we will become obligated to file with the SEC annual and quarterly information and other reports that are specified in Section 13 and other sections of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). We will also be required to ensure that we have the ability to prepare financial statements that are fully compliant with all SEC reporting requirements on a timely basis. In addition, we will also become subject to other reporting and corporate governance requirements, including certain requirements of the NYSE, and certain provisions of Sarbanes-Oxley and the regulations promulgated thereunder, which will impose significant compliance obligations upon us.

 

Sarbanes-Oxley, as well as new rules subsequently implemented by the SEC and the NYSE, have imposed increased regulation and disclosure and required enhanced corporate governance practices of public companies. We are committed to maintaining high standards of corporate governance and public disclosure, and our efforts to comply with evolving laws, regulations and standards in this regard are likely to result in increased marketing, selling and administrative expenses and a diversion of management’s time and attention from revenue-generating activities to compliance activities. These changes will require a significant commitment of additional resources. We may not be successful in implementing these requirements and implementing them could materially adversely affect our business, results of operations and financial condition. In addition, if we fail to implement the requirements with respect to our internal accounting and audit functions, our ability to report our operating results on a timely and accurate basis could be impaired. If we do not implement such requirements in a timely manner or with adequate compliance, we might be subject to sanctions or investigation by regulatory authorities, such as the SEC or the NYSE. Any such action could harm our reputation and the confidence of investors and clients in our company and could materially adversely affect our business and cause our share price to fall.

 

 

As a public company, we will be required to document and test our internal control procedures in order to satisfy the requirements of Section 404 of Sarbanes-Oxley, which will require annual management assessments of the effectiveness of our internal control over financial reporting and a report by our independent registered public accounting firm that addresses the effectiveness of internal control over financial reporting. During the course of our testing, we may identify deficiencies which we may not be able to remediate in time to meet our deadline for compliance with Section 404. Testing and maintaining internal control can divert our management’s attention from other matters that are important to the operation of our business. We also expect the new regulations to increase our legal and financial compliance costs, make it more difficult to attract and retain qualified officers and members of our board of directors, particularly to serve on our audit committee, and make some activities more difficult, time consuming and costly. We may not be able to conclude on an ongoing basis that we have effective internal control over financial reporting in accordance with Section 404 or our independent registered public accounting firm may not be able or willing to issue an unqualified report on the effectiveness of our internal control over financial reporting. If we conclude that our internal control over financial reporting is not effective, we cannot be certain as to the timing of completion of our evaluation, testing and remediation actions or their effect on our operations because there is presently no precedent available by which to measure compliance adequacy. If either we are unable to conclude that we have effective internal control over financial reporting or our independent auditors are unable to provide us with an unqualified report as required by Section 404, then investors could lose confidence in our reported financial information, which could have a negative effect on the trading price of our common stock.

 

 

The trading market for our common stock will be influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of our

company or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our stock price or trading volume to decline. Moreover, if one or more of the analysts who cover our company downgrades our stock or if our operating results do not meet their expectations, our stock price could decline.

 

 

We do not anticipate paying any dividends on our common stock in the foreseeable future. Any declaration and payment of future dividends to holders of our common stock may be limited by the provisions of the Delaware General Corporation Law. The future payment of dividends will be at the sole discretion of our board of directors and will depend on many factors, including our earnings, capital requirements, financial condition and other considerations that our board of directors deems relevant. As a result, to receive any income or realize a return on your investment, you will need to sell your shares of common stock. You may not be able to sell your shares of common stock at or above the price you paid for them.

 

 

Section 203 of the Delaware General Corporation Law and provisions in our amended and restated certificate of incorporation and amended and restated bylaws could make it more difficult for a third party to acquire us without the consent of our board of directors. See “Description of Capital Stock—Anti-Takeover Effects of Certificate of Incorporation and Bylaws Provisions.” These provisions include the following:

 

 

Although we believe these provisions protect our stockholders from coercive or otherwise unfair takeover tactics and thereby provide an opportunity to receive a higher bid by requiring potential acquirers to negotiate with our board of directors, these provisions apply even if the offer may be considered beneficial by some stockholders. Further, these provisions may discourage potential acquisition proposals and may delay, deter or prevent a change of control of our company, including through unsolicited transactions that some or all of our stockholders might consider to be desirable. As a result, efforts by our stockholders to change our direction or our management may be unsuccessful.

 

Certain matters contained in this prospectus include forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions and other matters.

 

All statements, other than statements of historical facts, included in this prospectus that address activities, events or developments that we expect, believe or anticipate will exist or may occur in the future, are forward-looking statements. In some cases, forward-looking statements can be identified by various forms of words such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:

 

 

Forward-looking statements are based on numerous assumptions, uncertainties and risks that could cause future events or results to be materially different from those stated or implied in this prospectus. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by the forward-looking statements include, among others, the following:

 

 

 

All forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements set forth above. 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. Forward-looking statements speak only as of the date they are made. We disclaim any obligation to and do not intend to update the above list or to announce publicly the result of any revisions to any of the forward-looking statements to reflect future events or developments, except to the extent required by applicable laws. If we update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect to those or other forward-looking statements.

 

In addition to causing our actual results to differ, the factors listed above and referred to below may cause our intentions to change from those statements of intention set forth in this prospectus. Such changes in our intentions may also cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.

 

Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements. These factors are described in “Risk Factors.”

 

We estimate that our net proceeds from the sale of shares of common stock in this offering, after deducting estimated underwriting discounts and commissions and estimated offering expenses, will be approximately $      million ($      million if the underwriters exercise their option to purchase additional common shares in full), assuming the shares are offered at $      per share of common stock, which is the midpoint of the estimated offering price range set forth on the cover page of this prospectus. We expect to distribute all the net proceeds from this offering to Williams. Any shares of common stock issued pursuant to the underwriters’ option to purchase additional common shares will not increase the total number of shares of common stock outstanding after this offering, but rather the number of shares of common stock owned by Williams will be reduced share for share by the number of shares of common stock issued pursuant to such option, thus reducing Williams’ ownership interest in us. We will distribute the net proceeds from the sale of shares of common stock pursuant to this option to Williams as part of our restructuring transactions. Williams is deemed to be an underwriter with respect to any shares of common stock issued pursuant to this option. See “Underwriting.”

 

We have issued $1.5 billion aggregate principal amount of Notes in a private offering exempt from registration under the Securities Act. As part of our restructuring transactions, all of the net proceeds of the sale of the Notes in excess of $500 million have been distributed to Williams.

 

At current commodity prices and drilling costs, as much as 50 percent of the net proceeds we retain from the Notes offering is expected to be utilized for capital projects, principally for drilling activities and, to a lesser extent, the construction of gathering lines, compression facilities and other ancillary infrastructure supporting our drilling program, with the remainder utilized to provide additional liquidity to fund similar activities and for general corporate purposes. Our ability to access the capital markets could be constrained in the future depending on various factors, including our credit rating, and we believe it is prudent to maintain sufficient liquidity to fund our drilling plan under reduced commodity prices. Williams has informed us that it expects to use the net proceeds distributed to it from this offering and the offering of the Notes to repay a portion of its indebtedness.

 

The following table sets forth the anticipated sources and uses of funds we expect to receive from the sale of shares of common stock in this offering and the issuance of the Notes, assuming the underwriters do not exercise their option to purchase additional common shares.

 

 

 

 

 

We do not anticipate paying any dividends on our common stock in the foreseeable future. We currently intend to retain our future earnings to support the growth and development of our business. The payment of future cash dividends, if any, will be at the discretion of our board of directors and will depend upon, among other things, our financial condition, results of operations, capital requirements and development expenditures, future business prospects and any restrictions imposed by future debt instruments.

 

The following table sets forth our cash and cash equivalents and capitalization as of September 30, 2011 on an actual basis and pro forma basis to give effect to:

 

 

 

 

You should read this table in conjunction with “Use of Proceeds,” “Selected Historical Combined Financial Data,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our historical and unaudited pro forma combined financial statements and related notes included elsewhere in this prospectus.