United States
Securities and Exchange Commission

Washington, D.C. 20549

Form 10-K

þ		Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the Fiscal Year Ended December 31, 2009

o		Transition Report Under Section 13 or 15(d) of the Securities Exchange Act of 1934

Endeavour International Corporation

(Exact name of registrant as specified in its charter)

Nevada		88-0448389
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

1001 Fannin Street, Suite 1600, Houston, Texas		77002
(Address of principal executive offices)		(Zip code)

(713) 307-8700
(Registrant’s telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class of Stock		Name of Each Exchange on Which Registered
Common Stock - $0.001 par value per share		NYSE-Amex

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer as defined in Rule 405 of the Securities Act. o Yes þ No

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. o Yes þ No

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. þ Yes o No

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 2 months (or for such shorter period that the registrant was required to submit and post such files). o Yes o No

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ

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. (Check one):

Large accelerated filer o		Accelerated filer þ		Non-accelerated filer o		Smaller reporting company o
				(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). o Yes þ No

The aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant was $154.0 million computed by reference to the closing sale price of the registrant’s common stock on the NYSE-Amex on June 30, 2009, the last business day of the registrant’s most recently completed second fiscal quarter. Shares of common stock held by executive officers and directors of the registrant are not included in the computation. However, the registrant has made no determination that such individuals are “affiliates” within the meaning of Rule 405 of the Securities Act of 1933.

As of March 12, 2010, 160,247,205 shares of the registrant’s common stock were outstanding.

Documents Incorporated By Reference:

Portions of the registrant’s definitive proxy statement relating to the 2010 Annual Meeting of Stockholders, which will be filed within 120 days of December 31, 2009, are incorporated by reference into Part III of this Form 10-K.

 

 

Table of Contents

Part I			1
Item 1. Business			1
Item 1A. Risk Factors			15
Item 1B. Unresolved Staff Comments			33
Item 2. Properties			33
Item 3. Legal Proceedings			36
Part II			36
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities			36
Item 6. Selected Financial Data			37
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations			39
Item 7A. Quantitative and Qualitative Disclosures About Market Risk			60
Item 8. Financial Statements and Supplementary Data			62
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure			123
Item 9A. Controls and Procedures			123
Item 9B. Other Information			126
Part III
Item 10. Directors, Executive Officers and Corporate Governance of the Registrant			126
Item 11. Executive Compensation			126
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters			126
Item 13. Certain Relationships and Related Transactions, and Director Independence			126
Item 14. Principal Accounting Fees and Service			127
Part IV			127
Item 15. Exhibits and Financial Statement Schedules			127
Signatures			128
EX-3.6.C
EX-10.7
EX-10.13.C
EX-10.15.B
EX-10.26.B
EX-12.1
EX-12.2
EX-21.1
EX-23.1
EX-23.2
EX-31.1
EX-31.2
EX-32.1
EX-32.2
EX-99.1

Quantities of natural gas are expressed in this Annual Report on Form 10-K in terms of thousand cubic feet (Mcf) and million cubic feet (MMcf). Oil is quantified in terms of barrels (Bbls) and thousands of barrels (Mbbls). Natural gas is compared to oil in terms of barrels of oil equivalent (BOE), thousand barrels of oil equivalent (MBOE) or million barrels of oil equivalent (MMBOE). One barrel of oil is the energy equivalent of six Mcf of natural gas. With respect to information relating to our working interest in wells or acreage, “net” oil and gas wells or acreage is determined by multiplying gross wells or acreage by our working interest therein. References to number of potential well locations are gross, unless otherwise indicated.

References to “GAAP” refer to U.S. generally accepted accounting principles.

Endeavour International Corporation

Part I

Item 1. Business

Endeavour International Corporation is an independent oil and gas company engaged in the exploration, development and acquisition of energy reserves in the U.S. and U.K. Unless the context otherwise requires, references to “Endeavour”, “we”, “us” or “our” mean Endeavour International Corporation and our consolidated subsidiaries.

General

Since commencing operations in 2004, we have built a strong asset base and achieved steady reserve growth through acquisitions and exploration and development activities. Historically, we have focused our operations in the North Sea, but have recently expanded our focus to target unconventional U.S. onshore resource shale plays with shorter production-cycle times and compelling risk/return profiles. As a result, we have established a strong foundation of producing assets and undeveloped acreage in both established and emerging U.S. onshore resource plays, including approximately 66,000 gross (27,000 net) acres within the Haynesville and Marcellus Shale regions, complemented by our four development assets in the UK North Sea.

Our strategic shift to expand our focus to include U.S. onshore asset development has been achieved through measured and specific steps taken in 2009. In May 2009, we sold our assets and operations in the Norwegian sector of the North Sea for $150 million. Proceeds from this sale enabled us to enter into a joint venture relationship with an established U.S. gas shale operator, providing us with acreage positions and production in the Haynesville and Marcellus gas shales. We also entered into additional joint venture agreements with other selected operators, providing exposure to emerging shale plays in Alabama and Montana.

The primary focus of our U.S. unconventional gas shale development efforts will target reserve and production growth in the Haynesville and Marcellus Shales. We have approximately 7,250 net acres with over 200 potential drilling locations in the Northern Louisiana and East Texas Haynesville Shale, with acreage located in Red River, DeSoto, Bienville and Caddo Parishes in Louisiana and Harrison and Gregg Counties in Texas. Our Marcellus gas shale acreage is comprised of 19,750 net acres and over 300 potential drilling locations, with acreage between two of the most active parts of the play. We also have exploratory plans in emerging shale plays in Alabama and Montana, with 63,000 and 75,000 net acres, respectively. Early well results will determine the pace and scope of subsequent development initiatives in each of these plays.

In addition to our recent expansion into the onshore U.S. shale plays, we intend to continue to actively manage our North Sea assets in a manner that maximizes value and enables us to allocate resources to effectively pursue our strategic objectives. Our North Sea activities and assets remain a key source of value that can be further developed to increase our overall reserves and production. Our major development projects – Bacchus, Columbus, Cygnus and Rochelle – have the potential to significantly expand our total proved reserves and production levels.

Endeavour International Corporation

Further exploration and development efforts will continue on our current and nearby properties, as appropriate, to best achieve maximum risk-adjusted value for our North Sea assets.

With the recent volatility in commodity prices and concerns over the financial markets, we will continue to pursue our strategy of exploiting a balanced portfolio of exploration and development assets through a disciplined approach. We are attempting to balance the capital intensive, long lead-time nature of our North Sea assets with our recent entry into the onshore U.S. shale plays. We believe the resource-rich shale plays provide us with less expensive, shorter lead time opportunities in some of the most active hydrocarbon producing areas in the U.S. We intend to develop our existing assets in the North Sea, which we expect to enter production beginning in 2011, while simultaneously pursuing the development of our leasehold positions in the Haynesville and Marcellus Shales.

Strategic Alternatives for North Sea Assets

On March 15, 2010, we announced that our board of directors has approved a review of strategic alternatives for its North Sea assets. In an effort to unlock the value of our underlying North Sea assets, we will study a full range of options, including:

	•		Continuing to execute current operations plan;
	•		Entering into a joint venture to accelerate activities in the North Sea; and
	•		Selling specific assets or the North Sea entire business.

We will announce the results of the effort once a course of action is chosen. At the end of this review process, we may elect to make no changes.

Our Areas of Operation

North Sea

The exploitation of North Sea oil reserves has been ongoing for a number of decades and the resulting increase in international oil prices made the large investments needed for extraction attractive. Although production costs are relatively high, the quality of the oil, the political stability of the region, and the proximity of important markets in Western Europe has made the North Sea an important oil producing region.

Our development assets in the Bacchus, Columbus, Cygnus and Rochelle fields comprise the primary component of our UK North Sea portfolio. We currently have development plans under way in each of these primary fields. When these projects are fully producing, they have the potential to exceed our current production levels from all other fields. We also hold interests in producing and non-producing properties in the UK sector of the North Sea. Our producing properties include the Alba, Bittern, Enoch and Goldeneye fields and recently suspended production from certain of our fields. We anticipate re-developing these suspended fields, if commercially advisable and practicable, once additional production commences from the nearby Rochelle field. We believe our assets in the North Sea possess significant value that can continue to be harvested or monetized in a manner that maximizes shareholder value.

Endeavour International Corporation

Primary Development Fields

Rochelle

We hold a 55.6% working interest in and operate our Rochelle field assets. Our interests in the Rochelle field account for 6.3 MMBOE of our proved reserves at December 31, 2009. The environmental impact study for the subsea development and pipeline corridor has been completed with no sensitivities identified.

Moreover, recent seismic studies in the area near our Rochelle field in the North Sea indicate that the natural gas formation may be larger than we had previously understood. We believe this larger Rochelle area can be developed using the current infrastructure. We are planning to drill a well to test the westward expansion of the Rochelle play in 2010. The Rochelle development is scheduled to achieve first production in 2011. This first production is dependent on approval of the Field Development Plan from the Department of Energy and Climate Change (“DECC”), which is further dependent on receiving acceptable commercial terms from the infrastructure holders for the off-take solution.

Cygnus

We hold a 12.5% working interest in our Cygnus field assets, which are operated by Gaz de France. Our interests in the Cygnus field account for 5.7 MMBOE of our proved reserves at December 31, 2009. These proved reserves are associated with the eastern portion of the field. Appraisal drilling to test two additional fault blocks in the western portion of the field has begun, with drilling underway of a well in the fourth fault block. A field development plan has been filed, with production from the eastern portion of the field expected to begin in 2011.

Columbus

We hold a 25% working interest in our Columbus field assets, which are operated by Serica Energy plc. Our interests in the Columbus field account for 1.8 MMBOE of our proved reserves at December 31, 2009. The host platform has been identified and commercial agreements are under negotiation with first production expected in 2012.

Bacchus

We hold a 10% working interest in our Bacchus field assets, which are operated by Apache Corporation. The development of the Bacchus field is expected to be sanctioned in 2010 by the DECC with first production expected to commence in 2011. The discovery well was drilled in 2005, followed by a down-dip sidetrack appraisal well that tested the upper part of the reservoir. A three-well subsea development tie-back to the Forties field is planned.

Endeavour International Corporation

Producing Fields

We have four producing fields in the U.K. – Alba, Bittern, Enoch and Goldeneye. Combined these fields held 2.5 MMBOE of proved reserves at December 31, 2009. The Goldeneye field represents nearly all of our current gas production in the U.K.

Our Ivanhoe, Rob Roy, Hamish (collectively, “IVRRH”), Renee and Rubie fields all produced to a single floating production facility that has experienced significant increases in operating costs in recent periods. As a result, production was suspended in the first quarter of 2009 and will remain suspended until the development activities at Rochelle are operational, which we currently anticipate to be during 2011. After the start of Rochelle production, we expect to re-develop these fields if commercially advisable and practicable.

United States

We have made significant recent acquisitions to bolster our holdings in unconventional U.S. onshore resource shale plays. As of March 16, 2010, our U.S. acreage consisted of approximately 165,000 net acres. We believe that our U.S. acreage provides us with development projects with shorter timeframes compared to our North Sea assets, and a strong return/risk profile. We anticipate that development of our U.S. acreage will be less expensive than our North Sea assets and reduce our overall finding and development costs. In addition, our U.S. acreage covers a broad spectrum of resource plays, from established and explored areas, such as the Haynesville and Marcellus Shales, to “frontier” areas, in Alabama and Montana.

Haynesville Shale

The Haynesville Shale has become one of the most active natural gas plays in the U.S. This area is defined by a Jurassic shale formation located approximately 1,000 to 1,500 feet below the base of the Cotton Valley formation at depths ranging from approximately 10,500 feet to 13,000 feet. The formation is 125 to 250 feet thick and is composed of organic-rich, black shale. It is located across numerous parishes in Northwest Louisiana, primarily in Caddo, Bossier, Red River, DeSoto, Webster and Bienville parishes and also in East Texas. Numerous shallower secondary objectives exist in the Haynesville Shale play area, including the overlying Jurassic Cotton Valley Sandstone and Bossier Shale intervals.

To facilitate our entrance into the Haynesville Shale, we have entered into a joint venture relationship with Cohort Energy, a subsidiary of J-W Operating Company (“J-W Operaing”). J-W Operating, a privately-held company, is a proven operator that has drilled over 130 horizontal wells in the Barnett, Haynesville, Marcellus and other shale formations since 2004. In separate transactions, we have acquired interests in both producing wells and acreage that is prospective for the Haynesville Shale. We have not acquired any meaningful Haynesville Shale interests outside of our relationship with Cohort Energy. Both the Haynesville and the Marcellus Shale project wells (described below) will be operated by J-W Operating, which has substantial experience in the Haynesville and Marcellus Shales.

Endeavour International Corporation

In October 2009, we purchased 50% of Cohort’s working interest in 24 wells located in five fields and certain proved undeveloped locations associated with Cohort’s proved developed assets in North Louisiana and East Texas for $15 million in cash. These 24 wells, some of which produce from the Cotton Valley trend and some of which produce from the Haynesville Shale, are associated with net proved reserves of approximately 1.6 MMBOE.

In addition to these wells, through our joint venture with Cohort Energy, we hold interests in approximately 17,700 gross (7,250 net) acres with Haynesville Shale potential. In connection with this acreage, we have identified over 200 potential drilling locations. Of this acreage, approximately 13,500 gross (5,800 net) acres are located in the Haynesville Shale core area in Louisiana with over 150 potential drilling locations.

Our most recent Haynesville well in Red River Parish, Louisiana, the Indigo Minerals 3#1-H, initially flowed approximately 21 MMcf/d and has produced over 2 Bcf (gross) gas in its first 6 months of production. Currently, we are drilling the Bachelor 3#1-H as a direct offset to the Indigo Minerals well. We are also drilling the Longview North 1H in Gregg County, Texas as a horizontal Cotton Valley Sandstone test.

Marcellus Shale

The Marcellus Shale is a Middle Devonian-aged shale that underlies much of Pennsylvania, New York, Ohio, West Virginia and adjacent states. The Marcellus Shale is an organic-rich shale gas target which we believe is analogous to the Mississippian Barnett Shale in Texas. Within the past few years, advances in two technologies, fracture stimulation and horizontal drilling, have produced promising results in the Marcellus Shale. These developments have resulted in significantly increased leasing and drilling activity in the area. As with our Haynesville Shale acreage, we have acquired all of our interests in the Marcellus Shale through a 50/50 joint venture relationship with Cohort Energy/J-W Operating who will operate the project. We acquired interests in approximately 48,300 gross (19,750 net) acres prospective for the Marcellus Shale in several project areas, including portions of Cameron, Elk, Potter, McKean, Jefferson and Clarion counties, Pennsylvania. In connection with this acreage, we have over 300 potential drilling locations. Currently, we are planning to complete the Pardee C-9H horizontal well in Cameron County followed by vertical pilot tests in other selected project areas.

Alabama Gas Shales

Through our joint venture with Hillwood Energy Alabama LP, an affiliate of Hillwood International Energy, we hold a 50% non-operating interest in approximately 160,000 gross (63,000 net) acres with exposure to emerging gas shale plays in western Alabama. Hillwood has an extensive and successful background as a participant and an operator in the Barnett shale play. Our position allows us to target multiple gas shale intervals. If successful, we believe this acreage could yield in excess of 400 potential drilling locations. We intend to participate in the drilling of vertical pilot wells during the first half of 2010, which may be followed by horizontal re-entries. We will monitor the results of these wells before formulating an appropriate development plan.

Endeavour International Corporation

Central Montana Oil-prone Shales

Through our joint venture with a private company, we own a 25% non-operating interest in approximately 300,000 gross (75,000 net) acres in central Montana. In this region, historical conventional oil production from Cretaceous through Mississippian reservoirs has totaled over 130 MMBoe. Our acreage contains approximately 900 potential drilling locations and has exposure to both the Mississippian Heath and Devonian Bakken oil-prone source shales. We currently plan to participate in the drilling of pilot wells during 2010. As with our Alabama acreage, we intend to monitor the results of these wells before determining further appraisal or development plans.

Reserves

Our proved oil and gas reserves at December 31, 2009, 2008 and 2007 included the following:

		Oil				Gas				Oil Equivalents
		(MBbls)				(MMcf)				(MBOE)
2009:
United Kingdom			3,348				78,316				16,401
United States			18				10,784				1,815
			3,366				89,100				18,216
2008:
United Kingdom			2,131				27,130				6,653
United States			18				690				133
Discontinued operations — Norway			1,406				4,977				2,236
			3,555				32,797				9,022
2007:
United Kingdom			3,284				11,812				5,252
Discontinued operations — Norway			2,056				8,434				3,461
			5,340				20,246				8,713

Endeavour International Corporation

Our proved developed and undeveloped oil and gas reserves at December 31, 2009, 2008 and 2007 included the following:

		Proved				Proved
		Developed				Undeveloped				Total Proved
		Reserves				Reserves				Reserves
		(MBOE)				(MBOE)				(MBOE)
2009:
United Kingdom			2,103				14,298				16,401
United States			792				1,023				1,815
			2,895				15,321				18,216
2008:
United Kingdom			2,595				4,058				6,653
United States			46				87				133
Discontinued Operations — Norway			2,122				114				2,236
			4,763				4,259				9,022
2007:
United Kingdom			3,947				1,305				5,252
Discontinued Operations — Norway			2,752				709				3,461
			6,699				2,014				8,713

Preparation of Oil and Gas Reserve Information

We have established internal controls over reserve estimation processes and procedures to support the accurate and timely preparation and disclosure of reserve estimations in accordance with SEC and GAAP requirements. These controls include oversight of the reserves estimation reporting processes by our technical staff, annual external audits of all of our proved reserves by independent reserve engineers and secured access to reservoir databases and systems. Proved reserve estimates are prepared by our technical staff and reviewed and approved by our executive team, including our Executive Vice President of Exploration. Reserves are reviewed internally with senior management quarterly and presented to our Board of Directors in summary form on an annual basis.

For 2009, our oil and gas reserve estimates were prepared by our internal reservoir engineers and audited by independent reserve engineers, Netherland, Sewell & Associates, Inc. (“NSAI”). For 2008 and 2007, our proved oil and gas reserves were estimated by NSAI.

Each year, our internal technical staff use reliable technologies to evaluate all technical data available on each field including production data, wells logs, pressure data, petrophysical analysis, fluid properties, seismic data, seismic interpretations and well control along with offset well data. We estimate the quantity of oil and gas reserves and provide our estimates, analysis and data to our independent reserve engineers.

Endeavour International Corporation

For 2008 and 2007, we provided our analysis and data to NSAI for their independent estimates using the Securities and Exchange Commission, or SEC, definitions of proved reserves. The independent engineers then performed their own analysis of the same raw data including analysis of all production data, pressure data, well logs, petrophysical analysis, fluid analysis, seismic data and mapping based on that seismic data to determine their own reserves in place and ultimately estimated the quantity of proved oil and gas reserves attributable to a specific property.

Qualification of Reserves Preparers and Auditors

We employ oil and gas technical professionals, including geophysicists, petrophysicists, geologists, petroleum engineers, and production and reservoir engineers, who have an average of 10 to 35 years of experience in their technical fields. In addition, we engage experienced and qualified consultants to perform various comprehensive seismic acquisitions, processing, reprocessing, interpretation, and other related services.

NSAI provides worldwide petroleum property analysis services for energy clients, financial organizations and government agencies. NSAI was founded in 1961 and performs consulting petroleum engineering services under Texas Board of Professional Engineers Registration No. F-002699. The technical persons responsible for conducting this audit for NSAI meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. NSAI opined that the overall proved reserves for the reviewed properties as estimated by us are, in the aggregate, reasonable, prepared in accordance with generally accepted petroleum engineering and evaluation principles and conform to the SEC’s definition of proved reserves as set forth in Rule 210.4-10(a) of Regulation S-X. NSAI has informed us that the tests and procedures used during its reserves audit conform to the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. Paragraph 2.2(f) of the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information defines a reserves audit as the process of reviewing certain of the pertinent facts interpreted and assumptions made that have resulted in an estimate of reserves prepared by others and the rendering of an opinion about (1) the appropriateness of the methodologies employed, (2) the adequacy and quality of the data relied upon, (3) the depth and thoroughness of the reserves estimation process, (4) the classification of reserves appropriate to the relevant definitions used, and (5) the reasonableness of the estimated reserve quantities. A reserve audit is not the same as a financial audit and is less rigorous in nature than an independent reserve report where the independent reserve engineer determines the reserves on his or her own.

2010 Planned Capital Expenditures

We anticipate spending approximately $90 million during 2010 to fund oil and gas activities in the U.S. and U.K. The majority of this amount is controllable by Endeavour. Our primary focus during 2010 in the U.S. will be in the Haynesville area as we believe this acreage contains near-term production potential. The ongoing U.S. program and expenditures will be tailored based on early drilling results. During 2010, we also expect to begin the evaluation program of our other

Endeavour International Corporation

U.S. assets in the Marcellus area and the two frontier plays in Alabama and Montana. Four U.K. wells have been or will be drilled in 2010; two Cygnus appraisal wells in the western portion of the field; the Deacon well that began in 2009 and finished in 2010, and the exploration well west of the Rochelle development. While this drilling is occurring, we expect to continue to further our development programs at our four existing development projects, including ongoing engineering assessments for future production and commercial off-take solutions. We intend to fund these development activities through cash on hand, and cash flow generated from operations, as well as expansion of our credit facilities as needed.

The timing, completion and process of our 2010 capital program is subject to a number of factors, including availability of capital, drilling results, drilling and production costs, availability of drilling services and equipment, partner approvals and technical work. Based on these and other factors, we may increase or decrease our planned capital program or prioritize certain projects over others.

Company History

Endeavour International Corporation (a Nevada corporation formed in 2000) is an independent oil and gas company engaged in the acquisition, exploration and development of energy reserves.

In November 2004, we purchased a 76.66% majority interest in OER oil AS (“OER”), a privately held Norwegian exploration and production company. In January 2005, we purchased the remaining 23.34% interest in OER from the minority interest holders.

In May 2006, we announced our largest acquisition to date – the purchase of producing properties in the U.K. (the “Talisman Acquisition”). On October 31, 2006, we completed this acquisition of all the outstanding shares of Talisman Expro Limited for $366 million, after purchase price adjustments and expenses. As a result of the Talisman Acquisition, we acquired interests in eight fields in the United Kingdom sector of the North Sea and over seven million BOE of proved reserves as of the closing date.

In the second quarter of 2006, we purchased an eight percent interest in the Enoch Field in the North Sea for approximately $11.7 million. The field is one of the first discoveries to be developed along the median line between the United Kingdom and Norway after the ratification of the U.K./Norway Framework Treaty concerning cross-boundary petroleum cooperation.

While working to complete and integrate these acquisitions, we also moved forward in our drilling program. During 2004 and 2005, we gained approval in the U.K. and Norway to act as an operator or licensee in both countries and began participating in the license round process. We continue to participate in the licensing rounds in the U.K. and Norway. We have also pursued various farm-in and license transfer opportunities to build acreage and exploration potential and spread the risk of exploration drilling among multiple prospects. Most notably, we have four significant development projects ongoing in the U.K. – Bacchus, Columbus, Cygnus and Rochelle. In 2008, we initiated operations in the U.S. and announced our first production there in January 2009.

Endeavour International Corporation

On May 14, 2009, we completed the divestiture of our Norwegian subsidiary, Endeavour Energy Norge AS, to VerbundnetzGas AG, a German utility company, for cash consideration of $150 million. We used the proceeds from this divestiture primarily to pay down our outstanding debt and streamline our capital structure, acquire new properties in the U.S. and support our ongoing drilling program. This divestiture allows us to focus our efforts on our acquired positions in our U.S. resource plays, as wells as develop our significant North Sea assets.

In the fourth quarter of 2009, we purchased producing properties and exploration acreage in the U.S. We purchased additional exploration acreage in the U.S. in January 2010. This accumulation of acreage in the U.S. reflects our expansion into resource plays in the U.S.

Geographical Data

We operate in one industry segment, that being oil and gas exploration and production, in two geographical areas. See Note 21 to our consolidated financial statements in “Item 8, Financial Statements and Supplementary Data” for geographic operating segment information, including results of operations and segment assets.

Competition

We encounter intense competition from other oil and gas companies in all areas of our operations, including the acquisition of producing properties and undeveloped acreage. Our competitors include major integrated oil and gas companies, numerous independent oil and gas companies and individuals. Many of our competitors are large, well-established companies with substantially larger operating staffs and greater capital resources and have been engaged in the oil and gas business for a much longer time than our company.

Petroleum and natural gas producers also compete with other suppliers of energy and fuel to industrial, commercial and individual customers. Competitive conditions may be substantially affected by various forms of energy legislation and/or regulation considered from time to time by the governments and/or agencies thereof and other factors out of our control including, international political conditions, overall levels of supply and demand for oil and gas, and the markets for synthetic fuels and alternative energy sources.

Significant Customers

Our sales in the U.K. are to a limited number of customers, each of which accounts for more than 10% of revenue: Chevron North Sea Ltd; Shell U.K. Limited, and Esso Exploration and Production. Our sales in the U.S. are sold through our arrangements with the operators of the fields, with substantially all of the sales being to Cohort Energy.

Employees

As of March 16, 2010, we have 43 full-time employees. We believe that we maintain good relationships with our employees, none of whom are covered by a collective bargaining agreement.

Endeavour International Corporation

Environmental Matters and Regulation

Endeavour was established on a commitment to find and develop energy resources in a manner that protects the health and safety of people and preserves the quality of the environment. Adhering to high performance standards in the areas of health, safety and the environment (“HSE”) is an integral part of our operations in our efforts to end each day “injury and incident free.”

North Sea

Our operations in the U.K. portions of the North Sea are subject to numerous U.K. and European Union laws and regulations relating to environmental matters, health and safety. Environmental matters are addressed before oil and gas production activities commence and during the exploration and production activities. Before a U.K. licensing round begins, the DECC will consult with various public bodies that have responsibility for the environment. Applicants for production licenses are required to submit a summary of its management systems and how those systems will be applied to the proposed work program. Additionally, the Offshore Petroleum Production and Pipelines (Assessment of Environmental Effects) Regulations 1999 require the Secretary of State to exercise his licensing powers under the U.K. Petroleum Act in such a way to ensure that an environmental assessment is undertaken and considered before consent is given to certain projects.

United States

With our entry into the U.S. onshore shale plays, our U.S. operations are subject to stringent federal, state and local laws and regulations relating to environmental protection, as well as controlling the manner in which various substances, including wastes generated in connection with oil and gas industry operations, are released into the environment. Compliance with these laws and regulations require the acquisition of permits authorizing air emissions and wastewater discharge from operations and can affect the location or size of wells and facilities, limit or prohibit the extent to which exploration and development may be allowed, and require proper closure of wells and restoration of properties that are being abandoned. Failure to comply with these laws and regulations may result in the assessment of administrative, civil or criminal penalties, imposition of remedial obligations, incurrence of capital costs to comply with governmental standards, and even injunctions that limit or prohibit exploration and production operations or the disposal of substances generated in connection with oil and gas industry operation.

We currently lease a number of properties that for many years have been used for the exploration and production of oil and gas. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons or wastes may have been disposed of or released on or under the properties operated or leased by us or on or under other locations where such hydrocarbons or wastes have been taken for recycling or disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or wastes was not under our control. These properties and the hydrocarbons and

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wastes disposed thereon may be subject to laws and regulations imposing joint and several, strict liability, without regard to fault or the legality of the original conduct, that could require us to remove or remediate previously disposed wastes or environmental contamination, or to perform remedial plugging or pit closure to prevent future contamination.

In June 2009, the U.S. House of Representatives passed a bill — the “American Clean Energy and Security Act of 2009,” also known as the “Waxman-Markey cap-and-trade legislation” (“ACESA”) — to control and reduce the emission of “greenhouse gases” (“GHGs”), such as carbon dioxide and methane, that may be contributing to warming of the Earth’s atmosphere and other climatic changes. The U.S. Senate is currently considering similar legislation that seeks to reduce emission of GHGs in the U.S. through the granting of emission allowances which would gradually be decreased over time. Moreover, more than one-third of the states, either individually or through multi-state initiatives, already have begun implementing legal measures to reduce emissions of GHGs. Also, on December 15, 2009, the U.S. Environmental Protection Agency (“EPA”) published its findings that emissions of carbon dioxide, methane and other GHGs present an endangerment to human health and the environment. These findings by the EPA allow the agency to proceed with the adoption and implementation of regulations that would restrict emissions of GHGs under existing provisions of the federal Clean Air Act. EPA has also proposed regulations that would require a reduction in emissions of GHGs from motor vehicles, and this regulatory action, if finalized, could also lead to the imposition of GHG emission limitations in Clean Air Act permits for certain stationary sources. In addition, on September 22, 2009, the EPA issued a final rule requiring the reporting of GHG emissions from specified large GHG emission sources in the U.S. beginning in 2011 for emissions occurring in 2010. Although our facilities were not subject to the EPA’s GHG reporting rule adopted in September 2009, EPA has indicated that it is evaluating whether the rule should be applied to oil and gas production activities, perhaps on a field-wide basis. While it is not possible at this time to fully predict how legislation or new regulations that may be adopted in the U.S. to address GHG emissions would impact our business, any such future laws and regulations could result in increased compliance costs or additional operating restrictions, and could have an adverse effect on demand for the oil and natural gas that we produce.

The U.S. Congress is currently considering legislation to amend the federal Safe Drinking Water Act (“SDWA”), to subject hydraulic fracturing operations to regulation under the SDWA and to require the disclosure of chemicals used by the oil and gas industry in the hydraulic fracturing process. Hydraulic fracturing involves the injection of water, sand and chemicals under pressure into rock formations to stimulate oil and gas production. Sponsors of bills currently pending before the U.S. Senate and House of Representatives have asserted that chemicals used in the fracturing process could adversely affect drinking water supplies. Proposed legislation would require, among other things, the reporting and public disclosure of chemicals used in the fracturing process, which could make it easier for third parties opposing the hydraulic fracturing process to initiate legal proceedings against producers. In addition, these bills, if adopted, could establish an additional level of regulation and permitting of hydraulic fracturing operations at the federal level, which could lead to operational delays, increased operating costs and additional regulatory burdens that could make it more difficult for us to perform hydraulic fracturing, which is an important component of well development. Any impairment of our ability to perform hydraulic fracturing could have an adverse effect on our ability to produce oil and gas from new wells.

Endeavour International Corporation

We have made, and will continue to make, expenditures in our effort to comply with environmental laws and regulations. We believe that we are in substantial compliance with applicable environmental laws and regulations in effect and that continued compliance with existing requirements will not have a material adverse impact on us. However, we also believe that it is reasonably likely that the trend in environmental legislation and regulation will continue toward stricter standards and, thus, we cannot give any assurance that we will not be adversely affected in the future.

We have established internal guidelines to be followed in order to comply with environmental laws and regulations in the U.S. We employ a safety department whose responsibilities include providing assurance that our operations are carried out in accordance with applicable environmental guidelines and safety precautions. Although we maintain pollution insurance to cover a portion of the costs of cleanup operations, public liability and physical damage, there is no assurance that such insurance will be adequate to cover all such costs or that such insurance will continue to be available in the future. To date, we believe that compliance with existing requirements of such governmental bodies has not had a material effect on our operations.

Other Regulation of the Oil and Gas Industry

The oil and gas industry is extensively regulated by numerous federal, state and local authorities. Legislation affecting the oil and gas industry is under constant review for amendment or expansion, frequently increasing the regulatory burden. Also, numerous departments and agencies, both federal and state, are authorized by statute to issue rules and regulations binding on the oil and gas industry and its individual members, some of which carry substantial penalties for failure to comply. Although the regulatory burden on the oil and gas industry increases our cost of doing business and, consequently, affects our profitability, these burdens generally do not affect us any differently or to any greater or lesser extent than they affect other companies in the industry with similar types, quantities and locations of production.

Legislation continues to be introduced in Congress and development of regulations continues in the Department of Homeland Security and other agencies concerning the security of industrial facilities, including oil and gas facilities. Our operations may be subject to such laws and regulations. Presently, it is not possible to accurately estimate the costs we could incur to comply with any such facility security laws or regulations, but such expenditures could be substantial.

Production Regulation

Our operations are subject to various types of regulation at federal, state and local levels. These types of regulation include requiring permits for the drilling of wells, drilling bonds and reports concerning operations. Most states, and some counties and municipalities, in which we operate, also regulate one or more of the following:

	•		the location of wells;
	•		the method of drilling and casing wells;
	•		the surface use and restoration of properties upon which wells are drilled;

Endeavour International Corporation

	•		the plugging and abandoning of wells; and
	•		notice to surface owners and other third parties.

The various states regulate the drilling for, and the production of, oil and natural gas, including imposing severance taxes and requirements for obtaining drilling permits. States also regulate the method of developing new fields, the spacing and operation of wells and the prevention of waste of oil and natural gas resources. States may regulate rates of production and may establish maximum daily production allowable from oil and gas wells based on market demand or resource conservation, or both. States do not regulate wellhead prices or engage in other similar direct economic regulation, but there can be no assurance that they will not do so in the future. The effect of these regulations may be to limit the amounts of oil and natural gas that may be produced from our wells, and to limit the number of wells or locations we can drill.

Regulation

The exploration, production and sale of oil and gas are extensively regulated by governmental bodies. Applicable legislation is under constant review for amendment or expansion. Oil and gas mineral rights may be held by individuals, corporations or governments having jurisdiction over the area in which such mineral rights are located. As a general rule, parties holding such mineral rights grant licenses or leases to third parties to facilitate the exploration and development of these mineral rights. The terms of the leases and licenses are generally established to require timely development. Notwithstanding the ownership of mineral rights, the government of the jurisdiction in which mineral rights are located generally retains authority over the manner of development of those rights.

Title to Properties

We believe that our title to the various interests set forth above is satisfactory and consistent with generally accepted industry standards, subject to exceptions that would not materially detract from the value of the interests or materially interfere with their use in our operations. Individual properties may be subject to burdens such as royalty, overriding royalty and other outstanding interests customary in the industry. In addition, interests may be subject to obligations or duties under applicable laws or burdens such as production payments, net profits interest, liens incident to operating agreements and for current taxes, development obligations under crude oil and natural gas leases or capital commitments under production sharing contracts or exploration licenses.

Offices

Our principal executive offices are located at 1001 Fannin Street, Suite 1600, Houston, Texas 77002, and our telephone number is (713) 307-8700. Many of our executive officers are also located in our offices at 114 St. Martin’s Lane, London WC2N 4BE England. We also have offices in Aberdeen, United Kingdom and Denver, Colorado.

Endeavour International Corporation

Available Information

We file annual and quarterly financial reports, as well as interim updates of a material nature to investors, with the SEC. The public may read and copy any materials that we file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. Also, the SEC maintains a website that contains reports, proxy and information statements and other information regarding issuers, including Endeavour, that file electronically with the SEC. The public can obtain any document we file at the SEC web page; http://www.sec.gov.

Our website is available at http://www.endeavourcorp.com. We make available, free of charge, on our website, the annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports, as soon as reasonably practicable after providing such reports to the SEC. Also, our Governance Guidelines, the charters of the Audit Committee, the Compensation Committee and the Governance and Nominating Committee, and the Code of Conduct and Code of Ethics for Senior Officers are available on our website and in print to any stockholder who provides a written request to the Corporate Secretary at 1001 Fannin Street, Suite 1600, Houston, Texas 77002. Our Code of Conduct applies to all directors, officers and employees, including the chief executive officer and senior financial officer.

Information contained on or connected to our website is not incorporated by reference into this Form 10-K and should not be considered part of this report or any other filing that we make with the SEC.

Financial Information about Segment and Geographical Areas

Our revenues and long-lived assets by geographic area is included in Note 21 to our consolidated financial statements in Item 8 and incorporated herein by reference.

Average Sales Prices and Production Costs by Geographical Area

Information on average sales prices and production costs by geographic area is included in Item 7 and incorporated herein by reference.

Item 1A. Risk Factors

Cautionary Statement Concerning Forward-Looking Statements

Certain matters discussed in this Annual Report on Form 10-K are “forward-looking statements” intended to qualify for the safe harbors from liability established by the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, as amended, or the Securities Act, and Section 21E of the Securities Exchange Act of 1934, as amended, or the Exchange Act. These forward-looking statements include statements that express a belief,

Endeavour International Corporation

expectation, or intention, as well as those that are not statements of historical fact, and may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. Our forward-looking statements are generally accompanied by words such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “plan,” “goal” or other words that convey the uncertainty of future events or outcomes. We caution you not to rely on them unduly. In particular, this Annual Report on Form 10-K contains forward-looking statements pertaining to the following:

	•		our future financial position;
	•		our business strategy;
	•		budgets;
	•		projected costs, savings and plans;
	•		objectives of management for future operations;
	•		legal strategies; and
	•		legal proceedings.

We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks, contingencies and uncertainties, which may not be exhaustive, relate to, among other matters, the following:

	•		discovery, estimation, development and replacement of oil and gas reserves;
	•		decreases in proved reserves due to technical or economic factors;
	•		drilling of wells and other planned exploitation activities;
	•		timing and amount of future production of oil and gas;
	•		the volatility of oil and gas prices;
	•		availability and terms of capital;
	•		operating costs such as lease operating expenses, administrative costs and other expenses;
	•		our future operating or financial results;
	•		amount, nature and timing of capital expenditures, including future development costs;
	•		cash flow and anticipated liquidity;
	•		availability of drilling and production equipment;
	•		uncertainties related to drilling and production operations in a new region;
	•		business strategy and the availability of acquisition opportunities; and
	•		factors not known to us at this time.

Any of these factors, or a combination of these factors, could materially affect our future financial condition or results of operations and the ultimate accuracy of the forward-looking statements. The forward-looking statements are not guarantees of our future performance, and our actual results and future developments may differ materially from those projected in the forward-looking statements. In addition, any or all of our forward-looking statements in this Annual Report on Form 10-K may turn out to be incorrect. They can be affected by inaccurate assumptions we might make or by known or unknown risks and uncertainties, including those mentioned in “Item 1A. Risk Factors” and elsewhere in this Annual Report on Form 10-K.

Endeavour International Corporation

Except as required by law, we undertake no obligation to update publicly or release any revisions to these forward-looking statements to reflect events or circumstances after the date of this Annual Report on Form 10-K. These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

Risks related to our business

We operate internationally and are subject to political, economic and other uncertainties.

We currently have operations in the U.S., U.K. and the Netherlands. We may expand our operations to other countries or regions. International operations are subject to political, economic and other uncertainties, including:

	•		the risk of war, acts of terrorism, revolution, border disputes, expropriation, renegotiation or modification of existing contracts, and import, export and transportation regulations and tariffs;
	•		taxation policies, including royalty and tax increases and retroactive tax claims;
	•		exchange controls, currency fluctuations and other uncertainties arising out of foreign government sovereignty over our international operations;
	•		laws and policies of the U.S. affecting foreign trade, taxation and investment; and
	•		the possibility of being subject to the exclusive jurisdiction of foreign courts in connection with legal disputes and the possible inability to subject foreign persons to the jurisdiction of courts in the U.S.

The exploration, production and sale of oil and gas are extensively regulated by governmental bodies. Applicable legislation is under constant review for amendment or expansion. These efforts frequently result in an increase in the regulatory burden on companies in our industry and consequently an increase in the cost of doing business and decrease in profitability. Numerous governmental departments and agencies are authorized to, and have, issued rules and regulations imposing additional burdens on the oil and gas industry that often are costly to comply with and carry substantial penalties for failure to comply. Production operations are affected by changing tax and other laws relating to the petroleum industry, by constantly changing administrative regulations and possible interruptions or termination by government authorities.

Oil and gas mineral rights may be held by individuals, corporations or governments having jurisdiction over the area in which such mineral rights are located. As a general rule, parties holding such mineral rights grant licenses or leases to third parties to facilitate the exploration and development of these mineral rights. The terms of the leases and licenses are generally established to require timely development. Notwithstanding the ownership of mineral rights, the government of the jurisdiction in which mineral rights are located generally retains authority over the manner of development of those rights.

Endeavour International Corporation

Future economic conditions in the U.S. and key international markets may materially adversely impact our operating results, which could hinder or prevent us from meeting our future capital needs.

The U.S. and other world economies are slowly recovering from a recession which began in 2008 and extended into 2009. Growth has resumed, but is modest. There are likely to be significant long-term effects resulting from the recession and credit market crisis, including a future global economic growth rate that is slower than what was experienced in recent years. In addition, more volatility may occur before a sustainable, yet lower, growth rate is achieved. Global economic growth drives demand for energy from all sources, including fossil fuels. A lower future economic growth rate will result in decreased demand growth for our crude oil and natural gas production as well as lower commodity prices, which will reduce our cash flows from operations and our profitability and may adversely affect our ability to obtain funding for our projects.

In addition, we may be unable to obtain adequate funding under our current senior bank facility because (i) our lending counterparties may be unwilling or unable to meet their funding obligations or (ii) our borrowing base under our current senior bank facility is redetermined at least twice per year and was reduced twice in 2009 as a result of lower oil or gas prices, declines in reserves, sales of assets and lending requirements or regulations.

Due to these factors, we cannot be certain that funding will be available if needed, and to the extent required, on acceptable terms or at all. If funding is not available as needed, or is available only on unfavorable terms, we may be unable to meet our obligations as they come due, or we may be unable to implement our capital program, enhance our existing business, complete acquisitions or otherwise take advantage of business opportunities or respond to competitive pressures, any of which could have a material adverse effect on our production, revenues and results of operations.

Oil and gas prices are volatile, and a decline in oil and gas prices would reduce our revenues, profitability and cash flow and impede our growth.

Our revenues, profitability and cash flow depend substantially upon the prices and demand for oil and gas. The markets for these commodities are volatile, and even relatively modest drops in prices can significantly affect our financial results and impede our growth. Oil and gas prices increased to, and then declined significantly from, historical highs in 2008 and may fluctuate and decline significantly in the near future. Prices for oil and gas fluctuate in response to relatively minor changes in the supply and demand for oil and gas, market uncertainty and a variety of additional factors beyond our control, such as:

	•		global supply of oil and gas;
	•		level of consumer product demand;
	•		technological advances affecting oil and gas consumption;
	•		global economic conditions;
	•		price and availability of alternative fuels;

Endeavour International Corporation

	•		actions of the Organization of Petroleum Exporting Countries and other state-controlled oil companies relating to oil price and production controls;
	•		governmental regulations and taxation;
	•		political conditions in or affecting other oil-producing and gas-producing countries;
	•		weather conditions;
	•		the proximity, capacity, cost and availability of pipeline and other transportation facilities; and
	•		the impact of energy conservation efforts.

Lower oil and gas prices may not only decrease our revenues on a per unit basis, but significant or extended price declines may also reduce the amount of oil and gas that we can produce economically. A reduction in production could result in a shortfall in expected cash flows and require us to reduce capital spending or borrow funds to cover any such shortfall. Any of these factors could negatively impact our ability to replace our production and our future rate of growth.

In addition, we may, from time to time, enter into long-term contracts based upon our reasoned expectations for commodity price levels. If commodity prices subsequently decrease significantly for a sustained period, we may be unable to perform our obligations or otherwise breach the contract and be liable for damages.

Competition for oil and gas properties and prospects is intense and some of our competitors have larger financial, technical and personnel resources that give them an advantage in evaluating, obtaining and developing properties and prospects.

We operate in a highly competitive environment for reviewing prospects, acquiring properties, marketing oil and gas and securing trained personnel. Many of our competitors are major or independent oil and gas companies that have longer operating histories in our areas of operation and employ superior financial resources which allow them to obtain substantially greater technical and personnel resources and which better enable them to acquire and develop the prospects that they have identified. We also actively compete with other companies when acquiring new licenses or oil and gas properties. Our relatively small size could adversely affect our ability to obtain new prospects and opportunities. Specifically, competitors with greater resources than our own have certain advantages that are particularly important in reviewing prospects and purchasing properties. Competitors may be able to evaluate, bid for and purchase a greater number of properties and prospects than our financial or personnel resources permit. Competitors may also be able to pay more for producing oil and gas properties and exploratory prospects than we are able or willing to pay. If we are unable to compete successfully in these areas in the future, our future revenues and growth may be diminished or restricted.

These competitors may also be better able to withstand sustained periods of unsuccessful drilling or downturns in the economy, including decreases in the price of commodities as experienced in 2008 and 2009. Larger competitors may also be able to absorb the burden of any changes in laws and regulations more easily than we can, which would also adversely affect our competitive position. In addition, most of our competitors have been operating for a much longer time and have demonstrated the ability to operate through industry cycles.

Endeavour International Corporation

We are dependent on our executive officers and need to attract and retain additional qualified personnel.

Our future success depends in large part on the service of our executive officers. The loss of these executives could have a material adverse effect on our business. Although we have employment agreements with certain of our executive officers, there can be no assurance that we will have the ability to retain their services. Further, we do not maintain key-person life insurance on any executive officers.

Our future success also depends upon our ability to attract, assimilate and retain highly qualified technical and other management personnel who are essential for the identification and development of our prospects. There can be no assurance that we will be able to attract, integrate and retain key personnel, and our failure to do so would have a material adverse effect on our business.

Our use of derivative transactions may limit future revenues from price increases and involves the risk that our counterparties may be unable to satisfy their obligations to us.

To manage our exposure to price or interest rate risk with our production, we routinely enter into commodity derivative contracts. The goal of these derivative contracts is to limit volatility and increase the predictability of cash flow. Although the use of derivative contracts limits the downside risk of price declines, their use also may limit future revenues from price increases. In addition, derivative contracts may expose us to the risk of financial loss in certain circumstances, including instances in which our production is less than expected or a sudden, unexpected event materially impacts oil or gas prices.

Derivative contracts also involve the risk that counterparties, which generally are financial institutions, may be unable to satisfy their obligations to us. If any of our counterparties were to default on its obligations to us under the derivative contracts or seek bankruptcy protection it could have a material adverse effect on our ability to fund our planned activities and could result in a larger percentage of our future production being subject to commodity price changes. In addition, in the current economic environment and tight financial markets, the risk of a counterparty default is heightened and it is possible that fewer counterparties will participate in future derivative transactions, which could result in greater concentration of our exposure to any one counterparty or a larger percentage of our future production being subject to commodity price changes.

Risks related to executing our strategy and operations

To maintain and grow our production and cash flow, we must continue to develop and produce existing reserves and discover or acquire new oil and gas reserves to develop and produce.

Our future oil and gas production is highly dependent upon our level of success in finding or acquiring additional reserves. Producing oil and gas reserves are generally characterized by

Endeavour International Corporation

declining production rates that vary depending on reservoir characteristics and other factors. Our reserves will decline unless we acquire properties with proved reserves or conduct successful development and exploration drilling activities. We accomplish this through successful drilling programs and the acquisition of properties. However, we may be unable to find, develop or acquire additional reserves or production at an acceptable cost or at all. Acquisition opportunities in the oil and gas industry are very competitive, which can increase the cost of, or cause us to refrain from, completing acquisitions.

If we are unable to find, develop or acquire additional reserves to replace our current and future production, our production rates will decline even if we drill the undeveloped locations that were included in our estimated proved reserves. Our future oil and gas reserves and production, and therefore our cash flow and income, are dependent on our success in economically finding or acquiring new reserves and efficiently developing our existing reserves.

We may be unable to make attractive acquisitions, and any acquisition we complete is subject to substantial risks that could impact our business.

As part of our growth strategy, we intend to pursue strategic acquisitions of new properties or businesses that expand our current asset base and potentially offer unexploited reserve potential. Our growth strategy following the full development of our existing properties could be impeded if we are unable to acquire additional interests in oil and gas prospects on a profitable basis. Acquisition opportunities in the oil and gas industry are very competitive, which can increase the cost of, or cause us to refrain from, completing acquisitions. The success of any acquisition will depend on a number of factors and involves potential risks, including among other things:

	•		the inability to estimate accurately the costs to develop the interests in oil and gas prospects, the recoverable volumes of reserves, rates of future production and future net cash flows attainable from the reserves;
	•		the assumption of unknown liabilities, losses or costs for which we are not indemnified or for which the indemnity we receive is inadequate;
	•		the validity of assumptions about costs, including synergies;
	•		the impact on our liquidity or financial leverage of using available cash or debt to finance acquisitions;
	•		the diversion of management’s attention from other business concerns; and
	•		an inability to hire, train or retain qualified personnel to manage and operate our growing business and assets.

All of these factors affect whether an acquisition will ultimately generate cash flows sufficient to provide a suitable return on investment. Even though we perform a review of the properties we seek to acquire that we believe is consistent with industry practices, such reviews are often limited in scope. As a result, among other risks, our initial estimates of reserves may be subject to revision following an acquisition, which may materially and adversely impact the desired benefits of the acquisition.

Endeavour International Corporation

Our expectations for future drilling activities will be realized over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing.

We have identified drilling locations and prospects for future drilling opportunities, including development, exploratory and other drilling and enhanced recovery activities. These drilling locations and prospects represent a significant part of our future drilling plans. Our ability to drill and develop these locations depends on a number of factors, including the availability of capital, seasonal conditions, third-party operators, regulatory approvals, negotiation of agreements with third parties, commodity prices, costs and drilling results. Because of these uncertainties, we cannot give any assurance as to the timing of these activities or that they will ultimately result in the realization of proved reserves or meet our expectations for success. As such, our actual drilling and enhanced recovery activities may materially differ from our current expectations, which could have a significant adverse effect on our financial condition and results of operations.

Our drilling projects are based in part on seismic data, which cannot ensure the commercial success of the project.

Our decisions to purchase, explore, develop and exploit prospects or properties depend in part on data obtained through geophysical and geological analyses, production data and engineering studies, the results of which are often uncertain. Even when used and properly interpreted, seismic data and visualization techniques only assist geoscientists and geologists in identifying subsurface structures and hydrocarbon indicators. Seismic data do not enable an interpreter to conclusively determine whether hydrocarbons are present or producible economically. In addition, the use of seismic and other advanced technologies may require greater predrilling expenditures than other drilling strategies. Because of these factors, we could incur losses as a result of exploratory drilling expenditures. Poor results from drilling activities could have a material adverse effect on our future cash flows, ability to replace reserves and results of operations.

Reserve estimates depend on many assumptions that may turn out to be inaccurate and any material inaccuracies in the reserve estimates or underlying assumptions of our assets will materially affect the quantities and present value of those reserves.

Estimating oil and gas reserves is complex and inherently imprecise. It requires interpretation of the available technical data and making many assumptions about future conditions, including price and other economic factors. In preparing such estimates, projection of production rates, timing of development expenditures and available geological, geophysical, production and engineering data are analyzed. The extent, quality and reliability of these data can vary. This process also requires economic assumptions about matters such as oil and gas prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. If our interpretations or assumptions used in arriving at our reserve estimates prove to be inaccurate, the amount of oil and gas that will ultimately be recovered may differ materially from the estimated quantities and net present value of reserves owned by us.

Endeavour International Corporation

A significant portion of our total estimated net proved reserves at December 31, 2009 were undeveloped, and those reserves may not ultimately be developed.

At December 31, 2009, approximately 84 percent of our total estimated net proved reserves were undeveloped. Recovery of undeveloped reserves requires significant capital expenditures and successful drilling. Our reserve data assumes that we can and will make these expenditures and conduct these operations successfully. These assumptions, however, may not prove correct. If we choose not to spend the capital to develop these reserves or if we are not otherwise able to successfully develop these reserves we may be required to write-off these reserves. Any such write-offs of our reserves could reduce our ability to borrow money and could reduce the value of our securities.

Our offshore operations involve special risks that could increase our cost of operations and adversely affect our ability to produce oil and gas.

Offshore operations are subject to a variety of operating risks specific to the marine environment, such as capsizing, collisions and damage or loss from hurricanes or other adverse weather conditions. These conditions can cause substantial damage to facilities and interrupt production. As a result, we could incur substantial liabilities that could reduce or eliminate the funds available for exploration, development or leasehold acquisitions, or result in loss of equipment and properties. Offshore drilling in the North Sea generally requires more time and more advanced drilling technologies, involving a higher risk of technological failure and usually higher drilling costs. Moreover, offshore projects often lack proximity to the physical and oilfield service infrastructure, necessitating significant capital investment in subsea flow line infrastructure. Subsea tieback production systems require substantial time and the use of advanced and very sophisticated installation equipment supported by remotely operated vehicles. These operations may encounter mechanical difficulties and equipment failures that could result in significant cost overruns. As a result, a significant amount of time and capital must be invested before we can market the associated oil or gas, increasing both the financial and operational risk involved with these operations. Because of the lack and high cost of infrastructure, some offshore reserve discoveries may never be produced economically.

We have recently commenced exploration, production and development operations in the United States, and as a result, our ability to successfully achieve our goals is subject to greater risk and uncertainty.

In 2008, we began to pursue exploration, production and development activities in the U.S. Moreover, we did not have a significant U.S. presence in our assets and operations until late 2009. Because we have limited production history in this geographic region and do not have extensive experience in unconventional resource plays, we are less able to use past operational results to help predict future results. Our lack of operational experience in the U.S. may result in our not being able to fully execute our expected drilling programs in this region, and the return on investment from our United States operations may not be as attractive as expected. We cannot assure you that our efforts in the U.S. will be successful, or if successful will achieve the resource potential levels that we currently anticipate or achieve the anticipated economic returns based on our current financial models.

Endeavour International Corporation

We will not be the operator of all of the interests we own or acquire, and therefore we may not be in a position to control the timing of development efforts, the associated costs, or the rate of production of the reserves in respect of such interests.

A significant number of our interests, including all of our producing fields, are currently operated by third parties. As a result, we may have limited ability to exercise influence over the operations of these interests or their associated costs. Dependence on the operator and other working interest owners for these projects, and limited ability to influence operations and associated costs could prevent the realization of expected returns on capital in drilling or acquisition activities. The success and timing of development and exploitation activities on properties operated by others depend upon a number of factors that will be largely outside our control, including:

•		the operator’s expertise and financial resources;
•		the timing and amount of their capital expenditures;
•		the rate of production of the reserves;
•		approval of other participants to drill wells and implement other work programs;
•		the availability of suitable drilling rigs, drilling equipment, support vessels, production and transportation infrastructure and qualified operating personnel; and
•		selection of technology.

Our inability to control the development efforts, costs and timing on the interests where we are not the operator could have a material adverse effect on our financial conditions, results of operations and business prospects.

Actual production could differ significantly from forecasts.

From time to time we provide forecasts of expected quantities of future oil and gas production. These forecasts are based on a number of estimates, including expectations of production decline rates from existing wells and the outcome of future drilling activity. Should these estimates prove inaccurate, actual production could be adversely impacted. Downturns in commodity prices could make certain drilling activities or production uneconomical, which would also adversely impact production. In addition, we may adjust estimates of proved reserves to reflect production history, results of exploration and development, prevailing oil and gas prices and other factors, many of which are beyond our control.

Our insurance may not protect us against business and operating risks, including an operator of a prospect in which we participate failing to maintain or obtain adequate insurance.

Oil and gas operations are subject to particular hazards incident to the drilling and production of oil and gas, such as blowouts, cratering, explosions, uncontrollable flows of oil, gas or well fluids, fires and pollution and other environmental risks. These hazards can cause personal injury and loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage and suspension of operations. We maintain insurance for some, but not

Endeavour International Corporation

all, of the potential risks and liabilities associated with our business. If a significant accident or other event resulting in damage to our operations, including severe weather, terrorist acts, war, civil disturbances, pollution or environmental damage, occurs and is not fully covered by insurance, it could adversely affect our financial condition and results of operations. We do not currently operate all of our oil and gas properties. In the projects in which we own non-operating interests, the operator may maintain insurance of various types to cover our operations with policy limits and retention liability customary in the industry. The occurrence of a significant adverse event that is not fully covered by insurance could result in the loss of our total investment in a particular prospect and additional liability for us, which could have a material adverse effect on our financial condition and results of operations and prospects.

The cost of decommissioning is uncertain.

We expect to incur obligations to abandon and decommission certain structures associated with our producing properties. To date, the industry has little experience of removing oil and gas structures from the North Sea. Few of the structures in the North Sea have been removed. Certain groups have been established to study issues relating to decommissioning and abandonment and how the costs will be borne. Because experience is limited, we cannot precisely predict the costs of any future decommissions for which we might become obligated. If actual decommission or abandonment costs exceed our estimates or reserves to satisfy such obligations, our financial condition, results of operations and prospects could be materially adversely affected.

Risks related to environmental and other regulations

We are subject to environmental regulations that can have a significant impact on our operations.

Our operations are subject to a variety of national, state, local and international laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. Failure to comply with these laws and regulations can result in the imposition of substantial fines and penalties as well as potential orders suspending or terminating our rights to operate. Some environmental laws to which we are subject to provide for strict liability for pollution damages, rendering a person liable without regard to negligence or fault on the part of such person. In addition, we may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances such as oil and gas related products. Aquatic environments in which we operate are often particularly sensitive to environmental impacts, which may expose us to greater potential liability than that associated with exploration, development and production at many onshore locations.

Changes in environmental laws and regulations occur frequently, and any changes that result in more stringent or costly requirements for oil and gas exploration and production activities could require us, as well as others in our industry, to make significant expenditures to attain and maintain compliance which could have a corresponding material adverse effect on our competitive position, financial condition or results of operations. We cannot provide assurance that we will be able to comply with future laws and regulations to the same extent that we

Endeavour International Corporation

believe we have in the past. Similarly, we cannot always precisely predict the potential impact of environmental laws and regulations which may be adopted in the future, including whether any such laws or regulations would restrict our operations in any area.

Current and future environmental regulations, including restrictions on greenhouse gases due to concerns about climate change, could reduce the demand for our products. Our business, financial condition and results of operations could be materially and adversely affected if this were to occur.

Under certain environmental laws and regulations, we could be subject to liability arising out of the conduct of operations or conditions caused by others, or for activities that were in compliance with all applicable laws at the time they were performed. Such liabilities can be significant, and if imposed could have a material adverse effect on our financial condition or results of operations.

Governmental regulations to which we are subject could expose us to significant fines and/or penalties and our cost of compliance with such regulations could be substantial.

Oil and gas exploration, development and production are subject to various types of regulation by local, state and national agencies. Regulations and laws affecting the oil and gas industry are comprehensive and under constant review for amendment and expansion. These regulations and laws carry substantial penalties for failure to comply. The regulatory burden on the oil and gas industry increases our cost of doing business and, consequently, adversely affects our profitability. In addition, competitive conditions may be substantially affected by various forms of energy legislation and/or regulation considered from time to time by the governments and/or agencies thereof.

Federal legislation and state legislative regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays as well as adversely affect our support services.

The U.S. Congress is currently considering two companions bills for the “Fracturing Responsibility and Awareness of Chemicals Act,” or “FRAC Act.” The bills would repeal an exemption in the federal Safe Drinking Water Act (“SWDA”) for the underground injection of hydraulic fracturing fluids near drinking water sources. Hydraulic fracturing is an important and commonly used process for the completion of natural gas, and to a lesser extent, oil wells in shale formations, and involves the pressurized injection of water, sand and chemicals into rock formations to stimulate natural gas production. Sponsors of the FRAC Act have asserted that chemicals used in the fracturing process could adversely affect drinking water supplies. If enacted, the FRAC Act could result in additional regulatory burdens such as permitting, construction, financial assurance, monitoring, recordkeeping, and plugging and abandonment requirements. The FRAC Act also proposes requiring the disclosure of chemical constituents used in the fracturing process to state or federal regulatory authorities, who would then make such information publicly available. The availability of this information could make it easier for third parties opposing the hydraulic fracturing process to initiate legal proceedings based on allegations that specific chemicals used in the fracturing process could adversely affect

Endeavour International Corporation

groundwater. In addition, various state and local governments are considering increased regulatory oversight of hydraulic fracturing through additional permit requirements, operational restrictions, and temporary or permanent bans on hydraulic fracturing in certain environmentally sensitive areas such as watersheds. The adoption of the FRAC Act or any other federal or state laws or regulations imposing reporting obligations on, or otherwise limiting, the hydraulic fracturing process could make it more difficult to complete natural gas wells in shale formations, increase our costs of compliance and doing business.

Climate change legislation or regulations restricting emissions of “greenhouse gases” could result in increased operating costs and reduced demand for the crude oil and natural gas that we produce.

On December 15, 2009, the U.S. Environmental Protection Agency (“EPA”) published its findings that emissions of carbon dioxide, methane and other “greenhouse gases” present an endangerment to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the earth’s atmosphere and other climatic changes. These findings allow the EPA to adopt and implement regulations that would restrict emissions of greenhouse gases under existing provisions of the federal Clean Air Act. Accordingly, the EPA has proposed regulations that would require a reduction in emissions of greenhouse gases from motor vehicles and could trigger permit review for greenhouse gas emissions from certain stationary sources. In addition, on October 30, 2009, the EPA published a final rule requiring the reporting of greenhouse gas emissions from specified large greenhouse gas emission sources in the U.S. beginning in 2011 for emissions occurring in 2010. Also, on June 26, 2009, the U.S. House of Representatives passed the “American Clean Energy and Security Act of 2009,” or “ACESA,” which would establish an economy-wide cap-and-trade program to reduce U.S. emissions of greenhouse gases, including carbon dioxide and methane. ACESA would require a 17% reduction in greenhouse gas emissions from 2005 levels by 2020 and just over an 80% reduction of such emissions by 2050. Under this legislation, the EPA would issue a capped and steadily declining number of tradable emissions allowances authorizing emissions of greenhouse gases into the atmosphere. These reductions would be expected to cause the cost of allowances to escalate significantly over time. The net effect of ACESA will be to impose increasing costs on the combustion of carbon-based fuels such as oil, refined petroleum products, and natural gas. The U.S. Senate has begun work on its own legislation for restricting domestic greenhouse gas emissions and the Obama Administration has indicated its support for legislation to reduce greenhouse gas emissions through an emission allowance system. At the state level, more than one-third of the states, either individually or through multi-state regional initiatives, already have begun implementing legal measures to reduce emissions of greenhouse gases. The adoption and implementation of any regulations imposing reporting obligations on, or limiting emissions of greenhouse gases from, our equipment and operations could require us to incur costs to reduce emissions of greenhouse gases associated with our operations or could adversely affect demand for the crude oil and natural gas that we produce. Finally, it should be noted that some scientists have concluded that increasing concentrations of greenhouse gases in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events; if any such effects were to occur, they could have an adverse effect on our assets and operations.

Endeavour International Corporation

The adoption of derivatives legislation by the U.S. Congress could have an adverse impact on our ability to hedge risks associated with our business.

The U.S. Congress is currently considering legislation to impose restrictions on certain transactions involving derivatives, which could affect the use of derivatives in hedging transactions. ACESA contains provisions that would prohibit private energy commodity derivative and hedging transactions. ACESA would expand the power of the Commodity Futures Trading Commission, or CFTC, to regulate derivative transactions related to energy commodities, including oil and natural gas, and to mandate clearance of such derivative contracts through registered derivative clearing organizations. Under ACESA, the CFTC’s expanded authority over energy derivatives would terminate upon the adoption of general legislation covering derivative regulatory reform. The CFTC is considering whether to set limits on trading and positions in commodities with finite supply, particularly energy commodities, such as crude oil, natural gas and other energy products. The CFTC also is evaluating whether position limits should be applied consistently across all markets and participants. Separately, the House of Representatives adopted financial regulatory reform legislation on December 11, 2009, that among other things would impose comprehensive regulation on the over-the-counter (OTC) derivatives marketplace. This legislation would subject swap dealers and “major swap participants” to substantial supervision and regulation, including capital standards, margin requirements, business conduct standards, recordkeeping and reporting requirements. It also would require central clearing for transactions entered into between swap dealers or major swap participants, and would provide the CFTC with authority to impose position limits in the OTC derivatives markets. A major swap participant generally would be someone other than a dealer who maintains a “substantial” net position in outstanding swaps, excluding swaps used for commercial hedging or for reducing or mitigating commercial risk, or whose positions create substantial net counterparty exposure that could have serious adverse effects on the financial stability of the U.S. banking system or financial markets. Although it is not possible at this time to predict whether or when Congress may act on derivatives legislation or how any climate change bill approved by the Senate would be reconciled with ACESA, any laws or regulations that may be adopted that subject us to additional capital or margin requirements relating to, or to additional restrictions on, our trading and commodity positions could have an adverse effect on our ability to hedge risks associated with our business or on the cost of our hedging activity.

Certain federal income tax deductions currently available with respect to oil and natural gas exploration and development may be eliminated as a result of future legislation.

President Obama’s Proposed Fiscal Year 2010 Budget includes proposed legislation that would, if enacted into law, make significant changes to U.S. tax laws, including the elimination of certain key U.S. federal income tax incentives currently available to oil and gas exploration and production companies. These 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 deductions for intangible drilling costs, (iii) the elimination of the deduction for certain domestic production activities, and (iv) an extension of the amortization period for certain geological and geophysical expenditures. It is unclear whether any such changes will be enacted or how soon any such changes could become effective. The passage of any legislation as a result of these

Endeavour International Corporation

proposals or any other similar changes in U.S. federal income tax laws could eliminate or otherwise limit certain tax deductions that are currently available with respect to oil and natural gas exploration and development, and any such change could negatively impact our financial condition and results of operations.

Risks related to access to capital and financing

Our development and exploration operations, including our recent North Sea discoveries, require substantial capital, and we may be unable to obtain needed capital or financing on satisfactory terms, which could lead to a loss of properties and a decline in our oil and gas reserves.

The oil and gas industry is capital intensive. We make and expect to continue to make substantial capital expenditures in our business and operations for the exploration, development, production and acquisition of oil and gas reserves, including expenditures relating to the development of our discoveries in the North Sea and our acreage position in the Haynesville Shale and other U.S. plays. We intend to finance our future capital expenditures primarily with cash flow from operations and borrowings under our senior bank facility. Our cash flow from operations and access to capital is subject to a number of variables, including:

	•		our proved reserves;
	•		the level of natural gas and crude oil we are able to produce from existing wells;
	•		the prices at which natural gas and crude oil are sold; and
	•		our ability to acquire, locate and produce new reserves.

If our revenues decrease as a result of lower oil and gas prices, operating difficulties, declines in reserves or for any other reason, we may have limited ability to obtain the capital necessary to sustain our operations at current levels or to further develop and exploit our current properties, or for exploratory activity. In order to fund our capital expenditures, we may need to seek additional financing. Our credit agreements contain covenants restricting our ability to incur additional indebtedness without the consent of the lenders. Our lenders may withhold this consent in their sole discretion. In addition, if our borrowing base is redetermined resulting in a lower borrowing base under our senior bank facility, we may be unable to obtain financing otherwise available under our senior bank facility.

Furthermore, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. In particular, the cost of raising money in the debt and equity capital markets has increased substantially while the availability of funds from those markets generally has diminished significantly. Also, as a result of concerns about the stability of financial markets generally and the solvency of counterparties specifically, the cost of obtaining money from the credit markets generally has increased as many lenders and institutional investors have increased interest rates, enacted tighter lending standards, refused to refinance existing debt at maturity on terms that are similar to existing debt, and reduced, or in some cases ceased, to provide funding to borrowers. 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

Endeavour International Corporation

a possible loss of properties and a decline in our natural gas, crude oil and natural gas liquids reserves.

Our debt level could negatively impact our financial condition, results of operations and business prospects.

As of December 31, 2009, we had $231.2 million in outstanding indebtedness. Our level of indebtedness could have important consequences on our operations, including

	•		placing restrictions on certain operating activities;
	•		making it more difficult for us to satisfy our obligations under our indentures or the terms of our other debt instruments and increasing the risk that we may default on our debt obligations;
	•		requiring us to dedicate a substantial portion of our cash flow from operating activities to required payments on debt, thereby reducing the availability of cash flow for working capital, capital expenditures and other general business activities;
	•		limiting our ability to obtain additional financing in the future for working capital, capital expenditures, acquisitions and other general business activities;
	•		decreasing our ability to withstand a downturn in our business or the economy generally; and
	•		placing us at a competitive disadvantage against other less leveraged competitors.

We may not have sufficient funds to repay our outstanding debt. If we are unable to repay our debt out of cash on hand, we could attempt to refinance such debt, sell assets or repay such debt with the proceeds from an equity offering. In addition, we cannot assure you that we will be able to generate sufficient cash flow from operating activities to pay the interest on our debt or that future borrowings, equity financings or proceeds from the sale of assets will be available to repay or refinance such debt. Factors that will affect our ability to raise cash through an offering of our capital stock, a refinancing of our debt or a sale of assets include financial market conditions, our market value, our reserve levels and our operating performance at the time of such offering or other financing. We cannot assure you that any such offering, refinancing or sale of assets can be successfully completed. The inability to repay or refinance our debt, could have a material adverse effect on our operations and negatively impact our capital program.

A change of control may adversely affect our liquidity and require refinancing of certain debt instruments.

At December 31, 2009, we had $231.2 million outstanding under our debt agreements. Upon specified change of control events, each lender under our debt agreements may cancel the facility and declare outstanding loans, plus accrued and unpaid interest, outstanding letters of credit and other outstanding fees, if any, due and payable. We cannot assure you we would have sufficient financial resources to purchase the notes for cash or repay the lenders under our Debt Agreements upon the occurrence of a change of control. If a change of control occurs, we may be required to refinance our indebtedness. There can be no assurance that we would be able to refinance our indebtedness or, if a refinancing were to occur, that the refinancing would be on terms favorable to us.

Endeavour International Corporation

If we are unable to fulfill commitments under any of our oil and gas interests, we will lose our interest, and our entire investment, in such interest.

Our ability to retain oil and gas interests will depend on our ability to fulfill the commitments made with respect to each interest. We cannot assure you that we or the other participants in the projects will have the financial ability to fund these potential commitments. If we are unable to fulfill commitments under any of our interests, we will lose our interest, and our entire investment, in such interest.

Risks relating to our common stock

The trading price of our common stock may be volatile.

Smaller capitalized companies like ours often experience substantial fluctuations in the trading price of their securities. The trading price of our common stock has fluctuated significantly and in the future may be subject to similar fluctuations. The trading price may be affected by a number of factors, including those set forth elsewhere herein, as well as our operating results, financial condition, announcements or drilling activities, general conditions in the oil and gas exploration and development industry, and other events or factors, some of which may be unrelated to our performance or prospects or to conditions in the industry as a whole.

If we, our existing stockholders or holders of our securities that are convertible into shares of our common stock sell additional shares of our common stock, the market price of our common stock could significantly decline.

The market price of our common stock could decline as a result of sales of a large number of shares of common stock in the public market or the perception that such sales could occur. These sales, or the possibility that these sales may occur, 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.

As of March 12, 2010, we had approximately 160.2 million shares of common stock outstanding. Of those shares, approximately 5.0 million shares are restricted shares subject to vesting periods of up to three years. The remainder of these shares is freely tradable.

In addition, approximately 2.8 million shares are issuable upon the exercise of presently outstanding stock options under our employee incentive plans and 0.9 million shares are issuable upon the exercise of presently outstanding options and warrants outside our employee incentive plans. Also 16.2 million shares are issuable upon the conversion of our convertible senior notes due 2012 and 48.8 million shares are issuable upon conversion of our Series C Preferred Stock, based upon the conversion price of $1.25, and 21.5 million shares are issuable upon conversion of our 11.5% convertible bonds, based on a conversion price of $2.36.

Endeavour International Corporation

Provisions in our articles of incorporation, bylaws and the Nevada Revised Statutes may discourage a change of control.

Certain provisions of our amended and restated articles of incorporation and amended and restated bylaws and the Nevada Revised Statutes (“NRS”) could delay or make more difficult a change of control transaction or other business combination that may be beneficial to stockholders. These provisions include, but are not limited to, the ability of our board of directors to issue a series of preferred stock, classification of our board of directors into three classes and limiting the ability of our stockholders to call a special meeting.

We are subject to the “Combinations With Interested Stockholders Statute” and the “Control Share Acquisition Statute” of the NRS. The Combinations Statute provides that specified persons who, together with affiliates and associates, own, or within three years did own, 10% or more of the outstanding voting stock of a corporation cannot engage in specified business combinations with the corporation for a period of three years after the date on which the person became an interested stockholder, unless the combination or the transaction by which the person first became an interested stockholder is approved by the corporation’s board of directors before the person first became an interested stockholder.

The Control Share Acquisition Statute provides that persons who acquire a “controlling interest” as defined by the statute, in a company may only be given full voting rights in their shares if such rights are conferred by the stockholders of the company at an annual or special meeting. However, any stockholder that does not vote in favor of granting such voting rights is entitled to demand that the company pay fair value for their shares if the acquiring person has acquired at least a majority of all of the voting power of the company. As such, persons acquiring a controlling interest may not be able to vote their shares.

Risks related to potential impairments

Lower oil and gas prices and other factors resulted in a ceiling test write-down and may in the future result in additional ceiling test write-downs or other impairments.

We capitalize the costs to acquire, find and develop our oil and gas properties under the full cost accounting method. The net capitalized costs of our oil and gas properties may not exceed the present value of estimated future net cash flows from proved reserves, using period-end oil and gas prices and a 10% discount factor, plus the lower of cost or fair market value for unproved properties. If net capitalized costs of our oil and gas properties exceed this limit, we must charge the amount of the excess to earnings. This is called a “ceiling test write-down.” Although a ceiling test write-down does not impact cash flow from operating activities, it does reduce net income and our shareholders’ equity. Once recorded, a ceiling test write-down is not reversible at a later date even if oil and gas prices increase.

We review the net capitalized costs of our properties quarterly, based on prices in effect (excluding the effect of our hedging contracts that are not designated for hedge accounting) as of the end of each quarter or as of the time of reporting our results. The net capitalized costs of oil and gas properties are computed on a country-by-country basis. Therefore, while our properties

Endeavour International Corporation

in one country may be subject to a write-down, our properties in other countries could be unaffected. We also assess investments in unproved properties periodically to determine whether impairment has occurred.

The risk that we will be required to further write down the carrying value of our oil and gas properties increases when oil and gas prices are low or volatile. In addition, write-downs may occur if we experience substantial downward adjustments to our estimated proved reserves or our unproved property values, or if estimated future development costs increase. We may experience further ceiling test write-downs or other impairments in the future. In addition, any future ceiling test cushion would be subject to fluctuation as a result of acquisition or divestiture activity.

Our financial results could be adversely affected by goodwill impairments.

As a result of mergers, acquisitions and dispositions, at December 31, 2009 we had $211.9 million of goodwill on our balance sheet. Goodwill is not amortized, but instead must be tested at least annually for impairment by applying a fair-value-based test. Goodwill is deemed impaired to the extent that its carrying amount exceeds the fair value of the reporting unit. Although our latest tests indicate that no goodwill impairment is currently required, future deterioration in market conditions could lead to goodwill impairments that could have a substantial negative effect on our profitability.

Item 1B. Unresolved Staff Comments

None.

Item 2. Properties

Drilling Statistics

A well is considered productive for purposes of the following table if it justifies the installation of permanent equipment for the production of oil or gas. The information contained in the table should not be considered indicative of future performance, nor should it be assumed that there is necessarily any correlation between the number of productive wells drilled, quantities of reserves found or economic value. The following table shows the results of the oil and gas wells in which we participated, drilled and tested during 2009, 2008 and 2007:

Endeavour International Corporation

		Productive Wells								Dry Holes								In Progress Wells
		Gross				Net				Gross				Net				Gross				Net
Exploration
2009:
United Kingdom			3.00				0.82				2.00				0.52				1.00				0.10
United States			3.00				1.32				1.00				0.22				3.00				1.04
2008:
United Kingdom			—				—				—				—				2.00				0.68
United States			1.00				0.20				—				—				1.00				0.10
Discontinued Operations — Norway			5.00				0.14				—				—				—				—
2007:
United Kingdom			2.00				0.50				3.00				0.75				—				—
Discontinued Operations — Norway			2.00				0.05				1.00				0.04				—				—
Development
2009:
United Kingdom			2.00				0.05				—				—				1.00				0.02
2008:
United Kingdom			—				—				—				—				1.00				0.02
Discontinued Operations — Norway			3.00				0.08				—				—				—				—
2007:
United Kingdom			1.00				0.02				—				—				—				—
Discontinued Operations — Norway			3.00				0.13				1.00				0.04				—				—

We do not own any drilling rigs, and all of our drilling activities are conducted by independent drilling contractors.

Endeavour International Corporation

Productive Well Summary

At December 31, 2009, our productive wells included the following:

		Oil								Gas
		Gross				Net				Gross				Net
United Kingdom			32.00				0.79				2.00				0.14
United States			2.00				1.12				25.00				7.16
Total			34.00				1.91				27.00				7.30

Acreage

The following table sets forth certain information regarding our developed and undeveloped acreage as of December 31, 2009, in the areas indicated.

		Developed								Undeveloped
		Gross				Net				Gross				Net
United Kingdom			31,790				8,108				325,610				86,566
United States			39,360				11,690				427,518				102,342
Ireland			—				—				172,797				34,559
Total			71,150				19,798				925,925				223,467

As of December 31, 2009, we had approximately 34,559, 28,473 and no net acres that are scheduled to expire by December 31, 2010, 2011 and 2012, respectively, if we take no action to continue the term of the underlying license through operational or administrative actions. We currently have plans to continue the terms of various licenses through operational or administrative actions and do not expect a significant portion of our net acreage position to expire before such actions occur.

Sales Volumes and Prices

Information regarding our annual average sales volumes, sales prices and average production costs is contained in Item 7 of this Form 10-K. Additional detail of production costs is contained in Note 24 to our consolidated financial statements under Item 8 of this Form 10-K.

Reserves

Our estimates of proved reserves, proved developed reserves and proved undeveloped reserves at December 31, 2009, 2008 and 2007 and changes in proved reserves during the last three years

Endeavour International Corporation

are contained in Note 24 Note to our consolidated financial statements under Item 8 of this Form 10-K.

Item 3. Legal Proceedings

We are a party to various lawsuits, claims, and proceedings from time to time in the ordinary course of business. These proceedings are subject to uncertainties inherent in any litigation, and the outcome of these matters is inherently difficult to predict with any certainty. We believe that the amount of any potential loss associated with these proceedings would not be material to our consolidated financial position; however, in the event of an unfavorable outcome, the potential loss could have an adverse effect on our results of operations and cash flow in the reporting periods in which any such actions are resolved.

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our common stock currently trades on the NYSE-Amex, formerly the American Stock Exchange, under the symbol “END” and on the London Stock Exchange under the symbol “ENDV.” The following table sets forth the range of high and low prices per share of our common stock for each of the calendar quarters identified below as reported by the NYSE-Amex. These quotations represent inter-dealer prices, without retail mark-up, markdown or commission, and may not represent actual transactions.

		2009								2008
		High				Low				High				Low
First Quarter		$	1.03			$	0.46			$	1.46			$	1.13
Second Quarter			2.21				0.83				2.56				1.20
Third Quarter			1.50				1.02				2.30				1.01
Fourth Quarter			1.30				0.82				1.45				0.33

Holders

As of March 12, 2010, the number of holders of record of our common stock was 222. We believe that there are a number of additional beneficial owners of our common stock who hold such shares in street name.

Endeavour International Corporation

Dividends

We have not paid any cash dividends on our common stock to date, and have no intention of declaring or paying any cash dividends on our common stock in the foreseeable future. Our Series B Preferred Stock is subject to a cumulative 8% dividend. Unless the full amount of the foregoing dividends accrued for the Series B Preferred Stock is paid in full, we cannot declare or pay any dividend on our common stock. In addition, our senior bank facility contains restrictions on the payment of dividends to the holders of our common stock. The declaration and payment of dividends is subject to the discretion of our Board of Directors and to certain limitations imposed under Nevada corporate laws. The timing, amount and form of dividends, if any, will depend on, among other things, our results of operations, financial condition, cash requirements and other factors deemed relevant by our Board of Directors.

In 2006, we issued the Series C Preferred Stock. Dividends on the Series C Preferred Stock are:

	•		cumulative;
	•		compounded quarterly based on the original issue price;
	•		payable in cash or common stock; and
	•		payable to the preferred stock investors prior to payment of any other dividend on any other shares of our capital stock.

In November 2009, we amended the terms of the Series C Preferred Stock in connection with a partial redemption. In connection with this transaction, the Series C Preferred Stock dividend rates were changed from 8.5% or 8.92% when payable in cash or common stock, respectively, to 4.5% or 4.92%, respectively. The Series C Preferred Stock continues to participate in any dividends paid on our common stock. We paid the Series C Preferred Stock dividends in common stock until the fourth quarter of 2007. Thereafter, we have paid the Series C Preferred Stock dividends in cash.

Item 6. Selected Financial Data

The following table sets forth some of our historical consolidated financial data. We completed the divestiture of our Norwegian subsidiary on May 14, 2009. The results of operations and financial position of this subsidiary are classified as discontinued operations for all periods presented.

The following data should be read in conjunction with “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the Consolidated Financial Statements and Notes thereto included in “Item 8. Financial Statements and Supplementary Data.” The selected consolidated financial data provided below are not necessarily indicative of our future results of operations or financial performance.

Endeavour International Corporation

Summary Financial Data(1)
		Year Ended December 31,
(Amounts in thousands, except per share data)		2009				2008				2007				2006				2005
Summary Income Statement Data:
Revenues		$	62,293			$	170,781			$	135,876			$	24,881			$	—
Operating Profit (Loss)			(50,398	)			18,236				23,778				(11,516	)			(43,281	)
Net Income (Loss) to Common Shareholders			(62,206	)			45,681				(60,315	)			(8,829	)			(31,531	)
Net Income (Loss) Per
Common Share — Basic:
Continuing Operations		$	(0.84	)		$	0.12			$	(0.50	)		$	(0.08	)		$	(0.50	)
Discontinued Operations			0.36				0.24				0.01				(0.02	)			0.08
Total		$	(0.48	)		$	0.36			$	(0.49	)		$	(0.10	)		$	(0.42	)
Net Income (Loss) Per Common Share — Diluted:
Continuing Operations		$	(0.84	)		$	0.15			$	(0.50	)		$	(0.08	)		$	(0.50	)
Discontinued Operations			0.36				0.17				0.01				(0.02	)			0.08
Total		$	(0.48	)		$	0.32			$	(0.49	)		$	(0.10	)		$	(0.42	)
Summary Balance Sheet Data:
Working Capital		$	24,885			$	22,902			$	37,198			$	47,431			$	49,638
Total Assets			538,879				737,470				747,623				774,470				186,966
Debt			223,385				227,855				266,250				306,250				81,250
Convertible Preferred Stock			59,058				125,000				125,000				125,000				—
Equity			60,133				117,971				70,149				116,828				40,344

	•		acquisition of producing properties and exploration acreage in the U.S. in 2009;
	•		acquisition of Talisman Expro Limited in November 2006;
	•		acquisition of working interests in the Enoch and Bacchus prospects in 2006;
	•		disposition of Thailand assets in 2005;
	•		acquisition of Norwegian assets in November 2004 and January 2005;
	•		disposition of non-core assets in 2004;
	•		acquisition of NSNV, Inc. in 2004; and
	•		unrealized gains (losses) on derivatives of $(55.6) million, $76.7 million, $(89.1) million and $34.5 million in 2009, 2008, 2007 and 2006, respectively.

Information regarding each of these transactions is included in the notes to the Consolidated Financial Statements included elsewhere in this report.

Endeavour International Corporation

Item 7.		Management’s Discussion and Analysis of Financial Condition and Results of Operations

This Management’s Discussion and Analysis of Financial Condition and Results of Operations and other parts of this Annual Report on Form 10-K contain forward-looking statements that involve risks and uncertainties. All forward-looking statements included in this Annual Report on Form 10-K are based on information available to us on the date hereof, and we assume no obligation to update any such forward-looking statements. Our actual results could differ materially from those anticipated in these forward-looking statements as a result of a number of factors, including those set forth in the section captioned “Risk Factors” in Item 1A and elsewhere in this Annual Report on Form 10-K. The following should be read in conjunction with the audited financial statements and the notes thereto included in “Item 8. Financial Statements and Supplementary Data.” The following discussion also includes non-GAAP financial measures, which may not be comparable to similarly titled measures presented by other companies. Accordingly, we strongly encourage investors to review our financial statements in their entirety and not rely on any single financial measure.

Overview

We are an international oil and gas exploration and production company focused on the acquisition, exploration and development of energy reserves. Historically, we have focused our operations in the North Sea, but have recently expanded our focus to target unconventional U.S. onshore resource shale plays with shorter production-cycle times and compelling risk/return profiles.

On May 14, 2009, we completed the sale of our Norwegian subsidiary, Endeavour Energy Norge AS, to Verbundnetz Gas AG for cash consideration of $150 million (the “Norway Sale”). We recognized a gain upon closing the Norway Sale of $47.0 million, after the allocation of $68 million of goodwill to the assets sold. Proceeds from this sale enabled us to enter into a joint venture relationship with an established U.S. shale operator, providing us with acreage positions and production in the Haynesville and Marcellus Shales. We also entered into additional joint venture agreements with other selected operators, providing exposure to emerging shale plays in Alabama and Montana.

Our North Sea activities and assets represented the majority of our activity in 2007 and 2008,. Our major development projects – Bacchus, Columbus, Cygnus and Rochelle – have continued to move toward development with appraisal wells drilled at Cygnus and Rochelle in early 2009. Further appraisal drilling is planned for 2010 at Cygnus.

Our realized price per BOE, before derivatives, decreased from $71.70 per BOE in 2008 to $64.15 per BOE in 2009 largely as a result of lower gas prices in the U.K. Our realized price per BOE, before derivatives, increased 25% from 2007 to 2008 largely as a result of oil prices climbing to record levels in the summer of 2008 and gas prices in our markets improving. This substantial increase in prices in the first half of 2008 helped revenue grow from $135.9 million in

Endeavour International Corporation

2007 to $170.8 million in 2008. At December 31, 2009, we held $27.3 million in cash and another $2.9 million in restricted cash.

Even with the substantial growth in revenues, net income can be significantly affected by various non-cash items, such as unrealized gains and losses on our commodity derivatives, currency impact of long-term liabilities and deferred taxes. Cash flow provided by (used in) operations was $55.7 million in 2009 versus $133.2 million in 2008 and $128.5 million in 2007. Discretionary cash flow was $71.4 million in 2009 compared to $120.8 million in 2008 and $113.0 million in 2007.

Net loss to common stockholders was $62.2 million for 2009, representing $(0.48) per diluted share and reflecting significant unrealized losses on the mark-to-market of commodity derivatives and a non-cash preferred stock dividend upon the valuation of the redemption and modification of a portion of our preferred stock. Net income to common stockholders was $45.7 million for 2008, or $0.32 per diluted share. Net loss to common stockholders for 2007 was $60.3 million, or $0.49 per share, reflecting the significant unrealized loss on the mark-to-market of commodity derivatives.

Net income as adjusted for 2009 would have been $41.1 million without the effect of impairments, derivative transactions and currency impacts of deferred taxes. Net income as adjusted for 2008 would have been $16.5 million, as compared to net loss as adjusted of $0.3 million in 2007.

Given the significant impact that non-cash items may have on our net income, we use various measures in addition to net income, including non-financial performance indicators and non-GAAP measures as key metrics to manage our business. These key metrics demonstrate the company’s ability to maintain or grow production levels and reserves, internally fund capital expenditures and service debt as well as provide comparisons to other oil and gas exploration and production companies. These measures include, among others, debt and cash balances, production levels, oil and gas reserves, drilling results, discretionary cash flow, adjusted earnings before interest, taxes, depreciation, depletion and amortization (“Adjusted EBITDA”) and adjusted net income.

For definitions of Adjusted EBITDA and Discretionary Cash Flow, and a reconciliation of Adjusted EBITDA to net income as adjusted, please see “Reconciliation of Non-GAAP Accounting Measures.”

Results of Operations

Our revenues have increased significantly since 2006 primarily due to the following:

	•		Our Enoch field began first production in mid 2007 and each of 2009 and 2008 reflect a full year’s contribution of this asset.
	•		U.S. production reflects the results of our successful drilling of the Garwood well at the end of 2008 and the purchase of producing assets in October 2009.

Endeavour International Corporation

	•		In the first quarter of 2009, we suspended production at the IVRRH, Renee and Rubie fields due to high operating costs.
	•		Natural production declines at certain of our fields have not been offset by infield drilling resulting in production decreases at certain fields, particularly in 2009 at our largest gas field – Goldeneye.
	•		There was an increase in gas production from our discontinued operations at the end of 2007 with the completion of a gas project at Njord in the fourth quarter of 2007.

The following table shows our annual average sales volumes, sales prices and average production costs.

Endeavour International Corporation

		Year Ended December 31,
		2009				2008				2007
Sales volume (1)
Oil and condensate sales (Mbbls):
United Kingdom			690				1,032				1,274
United States			4				—				—
Continuing operations			694				1,032				1,274
Discontinued operations — Norway			310				726				519
Total			1,004				1,758				1,793
Gas sales (MMcf):
United Kingdom			3,743				6,532				8,556
United States			320				—				—
Continuing operations			4,063				6,532				8,556
Discontinued operations — Norway			686				2,322				328
Total			4,749				8,854				8,884
Oil equivalent sales (MBOE)
United Kingdom			1,314				2,121				2,700
United States			58				—				—
Continuing operations			1,372				2,121				2,700
Discontinued operations — Norway			425				1,113				574
Total			1,797				3,234				3,274
Total BOE per day			4,923				8,835				8,969
Physical production volume (BOE per day):
United Kingdom			3,669				5,804				7,660
United States			162				—				—
Continuing operations			3,831				5,804				7,660
Discontinued operations — Norway			1,156				3,033				1,608
Total			4,987				8,837				9,268
Realized Prices (2)
Oil and condensate price ($  per Bbl):
Before commodity derivatives		$	52.15			$	90.53			$	67.11
Effect of commodity derivatives			22.51				(14.50	)			(2.13	)
Realized prices including commodity derivatives		$	74.66			$	76.03			$	64.98
Gas price ($  per Mcf):
Before commodity derivatives		$	5.77			$	11.44			$	6.27
Effect of commodity derivatives			2.69				(0.35	)			1.79
Realized prices including commodity derivatives		$	8.46			$	11.09			$	8.06
Equivalent oil price ($  per BOE):
Before commodity derivatives		$	44.44			$	80.54			$	53.78
Effect of commodity derivatives			19.71				(8.84	)			3.68
Realized prices including commodity derivatives		$	64.15			$	71.70			$	57.46
Operating Costs ($  per BOE)		$	12.97			$	14.40			$	12.56

Endeavour International Corporation

	(1)		We record oil revenues on the sales method, i.e. when delivery has occurred. Actual production may differ based on the timing of tanker liftings. We use the entitlements method to account for sales of gas production.
	(2)		The average sales prices reflect both our continuing and discontinued operations and include realized gains and losses for derivative contracts we utilize to manage price risk related to our future cash flows.
	(3)		Operating costs reflect both our continuing and discontinued operations and are costs incurred to operate and maintain our wells and related equipment and include cost of labor, well service and repair, location maintenance, power and fuel, transportation, cost of product and production related general and administrative costs.

Our revenues and cash flows from operating activities are very sensitive to changes in the prices we receive for the oil and natural gas we produce. Our production is sold at prevailing market prices which may be volatile and subject to numerous factors which are outside of our control. Further, the current tightly balanced supply and demand market allows a small variation in supply or demand to significantly impact the market prices for these commodities.

The markets in which we sell our oil and natural gas also materially impact our revenues and cash flows. Oil trades on a worldwide market and consequently, price movements for all types and grades of crude oil generally trend in the same direction and within a relatively narrow price range. However, natural gas prices vary among geographic areas as the prices received are largely impacted by local supply and demand conditions as the global transportation infrastructure for natural gas is still developing. As such, the oil we produce and sell is typically in line with global prices, whereas our natural gas is to a large extent impacted by regional supply and demand issues and to a lesser extent by global fuel prices, including oil and coal. Specifically, we sell a majority of our gas into the U.K. market, which is very sensitive to and impacted by tighter European gas supplies and gas deliveries from Russia. Therefore, the price for natural gas in the U.K. market is typically higher than the price for natural gas in other geographic regions and markets, including the U.S.

We utilize various oil and gas derivative instruments to achieve a more predictable cash flow by reducing our exposure to price fluctuations. Hedge accounting has not been elected for these instruments resulting in the application of mark-to-market accounting — effectively pulling forward into current periods the non-cash gains and losses from commodity price fluctuations relating to all future delivery periods. The derivative instruments cover a portion of our production through 2011. The significant volatility in commodity prices and the multi-year nature of the derivative instruments leads to large fluctuations in the fair market value of the derivative instruments at the end of each year. This non-cash change in the fair market value are recorded in unrealized gains (losses) on derivatives in the income statement. The realized prices above show the effect of the cash settlements for our derivative instruments each year. We expect to continue to have fluctuations in net earnings for the change in the fair market value each period as commodity prices fluctuate based on all remaining unsettled contracts. See Note 18 to the consolidated financial statements for additional information on these derivatives.

Endeavour International Corporation

Operating Expenses

For 2009, operating expenses decreased to $17.8 million as compared to $32.3 million for 2008. Operating costs per BOE decreased to $12.97 per BOE for 2009 from $14.40 per BOE for 2008. In general, the changes in operating costs reflect the increase in fuel costs in 2008 at a non-operated facility which gathered the production from the IVRRH, Renee and Rubie and then the absence of those costs when we suspended production from those fields in 2009.

DD&A and Impairment of Oil and Gas Properties

Decreased depreciation, depletion and amortization (“DD&A”) expense from 2008 to 2009 reflects the impact of a decrease in production and the lower DD&A rates as a result of impairments in oil and gas properties in 2008 and earlier 2009. Decreased DD&A expense from 2007 to 2008 reflects the impact of a decrease in production from 2007 to 2008 partially offset by an increase in the DD&A rate.

In 2009, we recorded $43.9 million in impairment of oil and gas properties, pre-tax, through the application of the full cost ceiling test. At December 31, 2009, the prices used to determine the estimates of future cash inflows were $60.40 per Bbl for oil and $4.96 per Mcf for gas.

In 2008, we recorded $37.0 million in impairment of oil and gas properties, pre-tax, through the application of the full cost ceiling test at year-end. The prices used to determine the impairment were $36.55 per barrel for oil and $8.70 per Mcf for gas. While our commodity derivatives had a fair value of $31.0 million at December 31, 2008, these derivatives were not included in the calculation of the full cost ceiling test as the derivatives are not accounted for as cash flow hedges.

General and Administrative (“G&A”) Expenses

Our have only slightly increased since 2007 as we have been able to absorb a significant amount of our expanded operations without a corresponding increase in the number of employees. The increase in G&A expenses to $17.0 million for 2009 is a result of an increase in employee compensation and consulting fees associated with the additional staff to pursue our expanding development projects in the U.K. Much of this increase in staff costs was offset by recoveries from our partner on the development project we operate, Rochelle. Non-cash stock-based compensation decreased as a result of the final vesting of grants given in prior years, current year forfeitures and declining fair values on each year’s grants. Components of G&A expenses for these periods are as follows:

Endeavour International Corporation

		Year Ended December 31,
		2009				2008				2007
Compensation		$	14,659			$	11,203			$	10,181
Consulting, legal and accounting fees			5,118				4,679				5,045
Occupancy costs			982				1,130				994
Other expenses			1,364				4,004				2,352
Total gross cash G&A expenses			22,123				21,016				18,572
Non-cash stock-based compensation			2,612				2,928				4,487
Gross G&A expenses			24,735				23,944				23,059
Less: capitalized G & A expenses			(7,769	)			(8,012	)			(7,206	)
Net G&A expenses		$	16,966			$	15,932			$	15,853

Interest Expense and Other

The decrease in interest expense from $23.0 million in 2008 to $16.6 million in 2009 reflects the partial repayment of outstanding balances under our senior bank facility with a portion of the proceeds from the sale of our Norwegian operations. Interest expense increased to $23.0 million in 2008 primarily as a result of $4.3 million in expenses, including $2.1 million in cash, related to the early repayment of the second lien term loan.

Income Taxes

The following summarizes the components of tax expense (benefit):

Endeavour International Corporation

														Total				Discontinued
														Continuing				Operations –
(Amounts in thousands)		U.K.				U.S.				Other				Operations				Norway				Total
Year Ended December 31, 2009:
Net income (loss) before taxes		$	(52,041	)		$	(31,167	)		$	(11,479	)		$	(94,687	)		$	51,963			$	(42,724	)
Current tax (benefit) expense			(5,739	)			40				(26	)			(5,725	)			(603	)			(6,328	)
Deferred tax (benefit) expense			(20,260	)			(20	)			(35	)			(20,315	)			4,791				(15,524	)
Foreign currency losses on deferred tax liabilities			18,882				—				—				18,882				1,241				20,123
Total tax (benefit) expense			(7,117	)			20				(61	)			(7,158	)			5,429				(1,729	)
Net income (loss) after taxes		$	(44,924	)		$	(31,187	)		$	(11,418	)		$	(87,529	)		$	46,534			$	(40,995	)
Year Ended December 31, 2008:
Net income (loss) before taxes		$	66,129			$	(11,969	)		$	(4,185	)		$	49,975			$	63,244			$	113,219
Current tax expense			11,158				—				10				11,168				27,879				39,047
Deferred tax expense			22,673				—				303				22,976				15,415				38,391
Foreign currency gains on deferred tax liabilities			(10,028	)			—				—				(10,028	)			(10,681	)			(20,709	)
Total tax expense			23,803				—				313				24,116				32,613				56,729
Net income (loss) after taxes		$	42,326			$	(11,969	)		$	(4,498	)		$	25,859			$	30,631			$	56,490
Year Ended December 31, 2007:
Net income (loss) before taxes		$	(68,704	)		$	(10,233	)		$	6,584			$	(72,353	)		$	14,095			$	(58,258	)
Current tax (benefit) expense			2,898				(3	)			289				3,184				562				3,746
Deferred tax (benefit) expense			(27,430	)			—				711				(26,719	)			8,951				(17,768	)
Foreign currency losses on deferred tax liabilities			1,327				—				—				1,327				3,514				4,841
Total tax (benefit) expense			(23,205	)			(3	)			1,000				(22,208	)			13,027				(9,181	)
Net income (loss) after taxes		$	(45,499	)		$	(10,230	)		$	5,584			$	(50,145	)		$	1,068			$	(49,077	)

Our income tax expense during the periods indicated relates primarily to our operations in the U.K. and our discontinued operations in Norway. Income taxes decreased in 2009 to a benefit of $7.2 million reflecting the decrease in revenues and the weakening of the U.S. dollar versus the U.K. pound. Income tax expense in 2008 represents the significant increase in revenues as a result of higher realized prices, the strengthening of the U.S. dollar versus the U.K. pound and the shift in anticipated capital expenditures from late 2008 to early 2009. During 2007, we incurred taxes in all of the jurisdictions in which we do business, except for the U.S.

At December 31, 2009, we had net operating loss carryforwards of $77.6 million in the U.S.

In 2009, 2008 and 2007, we have not recorded any income tax benefits in the U.S. as there was no assurance that we could generate any U.S. taxable earnings, resulting in a full valuation allowance of deferred tax assets generated.

Endeavour International Corporation

Capital Program

We spent $88.6 million, $88.5 million and $87.9 million on our oil and gas capital program, excluding acquisitions, in 2009, 2008 and 2007, respectively. We spent $16.5 million in 2009 and $15 million to $20 million in both 2008 and 2007 on development activities at our producing properties. The remaining costs were spent on exploration and appraisal activities, including $11.4 million and $5.5 million in 2009 and 2008, respectively, related to our new operations in the U.S. Expenditures for 2009 also included $32.2 million for our acquisitions, primarily located in the U.S.

2009 Capital Resources

		Year Ended December 31,
(Amounts in thousands)		2009				2008
Cash		$	27,287			$	31,421
Restricted Cash, related to rig commitments		$	2,879			$	20,739
Debt, including current maturities		$	(223,385	)		$	(227,855	)
Debt, net of Cash		$	(193,219	)		$	(175,695	)

		Year Ended December 31,
		2009				2008
Net cash provided by operating activities		$	55,711			$	133,180
Net cash provided by (used in) investing activities		$	31,120			$	(64,851	)
Net cash used in financing activities		$	(97,700	)		$	(46,613	)

Our primary sources of financial resources and liquidity are internally generated cash flows from operations and access to the credit and capital markets, to the extent available. During 2009, we principally relied on cash flow from operations and proceeds from our sale of Norwegian assets to fund our capital needs and repay a portion of outstanding debt and preferred stock. Going forward, we believe the combination of our available cash on hand, cash flow from operations and our ability to control capital expenditures will allow us to manage our business effectively while enabling us to further our strategic objectives.

Operating, Investing and Financing Activities include the net cash flows from our discontinued operations. For the years ended December 31, 2009, 2008, and 2007, our discontinued operations had net cash flows provided by (used in) operating activities of approximately $9.0 million, $38.8 million and $26.3 million, respectively. These net cash flows were substantially offset by net cash used by investing activities of approximately $9.0 million, $34.7 million and $25.5 million during 2009, 2008, and 2007, respectively.

Cash flow from operations decreased to $55.7 million for 2009 from $133.2 million for 2008 primarily due to lower realized commodity prices and lower sales volumes, particularly the reduction in gas sales as a result of production declines at Goldeneye.

Endeavour International Corporation

In addition to cash flows from operations, we have utilized issuances of debt and equity securities to enhance our liquidity and support the execution of our strategic objectives. Significant issuances and repayments of debt and equity, as well as the uses of the net proceeds, in 2009, 2008, and 2007 were as follows:

	•		repaid the outstanding balance of the second lien term loan in the first quarter of 2008;
	•		issued $40 million of the 11.5% convertible bonds in the first quarter of 2008;
	•		repaid $63.0 million of net debt in 2009; and
	•		repaid $75 million of the Series C Convertible Preferred Stock in the fourth quarter of 2009 with $25 million in cash and a $50 million note payable.

On November 17, 2009, we redeemed 60% of the outstanding shares of Series C Preferred Stock, for face value of $75 million, and amended the terms of the remaining shares of Series C Preferred Stock. The redemption price consisted of a $25 million cash payment and the issuance of $50 million Subordinated Notes.

The redemption and modification of the Series C Preferred Stock required the modified Series C Preferred Stock to be recorded at fair market value at the redemption date. As there was not a market observable price for the Series C Preferred Stock, we utilized a valuation approach to estimate the price that would be paid to transfer the Series C Preferred Stock in an orderly transaction between market participants. The fair value of the modified Series C Preferred Stock was greater than the carrying value by $11.5 million. This excess of fair value over carrying value was recorded as a non-cash charge to preferred stock dividends and increased the carrying value of the Series C Preferred Stock. As holders convert the Series C Preferred Stock, the $11.5 million non-cash charge will be transferred to equity on a ratio of shares converted to shares of Series C Preferred Stock outstanding.

In the November 2009 amendment, we amended terms of the Series C Preferred Stock to reduce the annual dividend rate to 4.5% (from 8.5%), adjust the conversion price to $1.25 per share (from $2.50) and remove certain anti-dilution provisions.

See Note 9 to the Consolidated Financial Statements for additional discussion of our debt.

Our future revenues and cash flows from operating activities will continue to be sensitive to changes in prices received for our products. Our production is sold at prevailing market prices which fluctuate in response to many factors that are outside of our control. Given the current tightly balanced supply-demand market, small variations in either supply or demand, or both, can have dramatic effects on prices we receive for our oil and natural gas production. While the market price received for oil and natural gas varies among geographic areas, oil trades in a worldwide market, whereas natural gas, which is still developing a global transportation system, is more subject to local supply and demand conditions. Consequently, price movements for all types and grades of crude oil generally move in the same direction.

Natural gas prices in the North Sea have been influenced by fuel prices around the world, including crude oil and coal. These prices are also impacted by European gas supplies,

Endeavour International Corporation

particularly deliveries from Russian gas supplies. In addition, regional supply and demand issues affect gas prices. The majority of our natural gas is sold in the U.K. market. Market prices for both oil and natural gas were at high levels throughout much of 2007 and 2008. North Sea gas prices declined in the first quarter of 2007 but recovered in the second half of the year and remained strong during 2008 and 2009.

Our cash flows will be significantly impacted by the amount of hydrocarbons we produce, the price we obtain for our produced commodities and taxes paid on operations. Oil prices continue to be impacted by supply and demand on a worldwide basis, while natural gas prices are more impacted by regional economic and weather patterns. Although oil and gas prices have remained volatile, the full impact on our cash flows will be partially mitigated by our balance of gas to oil production and our commodity derivative positions. As of December 31, 2009, our outstanding commodity derivatives covered 30% to 45% of expected 2010 production.

Recent Financing Arrangements

In February 2010, we issued 23.5 million shares of common stock in a private placement for aggregate net proceeds of $20.5 million. We also entered $25 million junior lending facility, with a maturity date of February 5, 2011, and interest at LIBOR plus 8%. Upon entering the new junior lending facility, we borrowed $15 million against the facility. The net proceeds from the private placement and the borrowing under the junior facility will be used to partially fund our 2010 capital budget.

Non-GAAP Measures

Net income can be significantly affected by various non-cash items, such as unrealized gains and losses on our commodity derivatives, currency impact of long-term liabilities and deferred taxes. Given the significant impact that non-cash items may have on our net income, we use various measures in addition to net income, including non-financial performance indicators and non-GAAP measures as key metrics to manage our business. These key metrics demonstrate the company’s ability to maintain or grow production levels and reserves, internally fund capital expenditures and service debt as well as provide comparisons to other oil and gas exploration and production companies. These measures include, among others, debt and cash balances, production levels, oil and gas reserves, drilling results, discretionary cash flow, adjusted earnings before interest, taxes, depreciation, depletion and amortization (“Adjusted EBITDA”) and adjusted net income.

Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow are internal, supplemental measures of our performance that are not required by, or presented in accordance with, GAAP. We use these non-GAAP measures as internal measures of performance and to aid in our budgeting and forecasting processes. We view these non-GAAP measures, and we believe that others in the oil and gas industry view these, or similar, non-GAAP measures, as commonly used analytic indicators to compare performance among companies. We further believe that these non-GAAP measures are frequently used by securities analysts, investors, and other interested parties in the evaluation of issuers, many of which present these measures when reporting their results. We believe these non-GAAP measures provide useful information to both

Endeavour International Corporation

management and investors to gain an overall understanding of our current financial performance and provide investors with financial measures that most closely align to our internal measurement processes. Since the application of mark-to-market accounting has the effect of pulling forward into current periods non-cash gains and losses related to commodity derivatives relating to future delivery periods, analysis of results of operations from one period to another can be difficult. We believe that excluding these unrealized non-cash gains and losses related to commodity derivatives and currency exchange changes provides a more meaningful representation of our economic performance in the reporting period and is therefore useful to us, investors, analysts and others in facilitating the analysis of our results of operations from one period to another. These measures should not be considered as measures of financial performance under GAAP, and the items excluded from these measures are significant components in understanding and assessing financial performance.

These non-GAAP measures should not be considered in isolation or as an alternative to net income, operating income or any other performance measures derived in accordance with GAAP or as alternatives to cash flows generated by operating, investing or financing activities as a measure of our liquidity. Because Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow are not measurements determined in accordance with GAAP and thus susceptible to varying calculations, Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow as presented may not be comparable to other similarly titled measures of other companies.

Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow have limitations as an analytical tool, and you should not consider these measures in isolation, or as a substitute for analysis of our financial statement data presented in the consolidated financial statements as reported under GAAP. For example, Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow may not reflect:

	•		our cash expenditures, or future requirements, for capital expenditures or contractual commitments;
	•		changes in, or cash requirements for, our working capital needs;
	•		unrealized gains (losses) on derivatives;
	•		non-cash foreign currency gains (losses);
	•		our interest expense, or the cash requirements necessary to service interest and principal payments on our debts;
	•		our preferred stock dividend requirements; and
	•		depreciation, depletion and amortization.

Because of these limitations, Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow should not be considered as measures of cash available to us to invest in the growth of our business. We compensate for these limitations by relying primarily on our GAAP results and by using Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow only supplementally.

Endeavour International Corporation

As required under Regulation G of the Securities Exchange Act of 1934, provided below are reconciliations of net income (loss) to the following non-GAAP financial measures: Net Income (Loss) as Adjusted, Adjusted EBITDA and Discretionary Cash Flow.

		Year Ended December 31,
		2009				2008				2007
Net income (loss)		$	(40,995	)		$	56,490			$	(49,077	)
Depreciation, depletion and amortization			38,701				81,734				76,850
Impairment of oil and gas properties			43,929				36,970				—
Deferred tax expense (benefit)			4,599				17,682				(12,925	)
Gain on asset sales			(47,308	)			—				—
Unrealized (gain) loss on derivatives			55,598				(76,666	)			89,132
Other			16,835				4,597				8,994
Discretionary Cash Flow (1)		$	71,359			$	120,807			$	112,974
Net income (loss)		$	(40,995	)		$	56,490			$	(49,077	)
Impairment of oil and gas properties (net of tax) (2)			28,263				18,485				—
Unrealized (gain) loss on derivatives (net of tax) (3)			33,702				(37,743	)			44,566
Currency impact on deferred taxes			20,123				(20,709	)			4,842
Net Income as Adjusted		$	41,093			$	16,523			$	331
Net income (loss)		$	(40,995	)		$	56,490			$	(49,077	)
Unrealized (gain) loss on derivatives			55,598				(76,666	)			89,132
Net interest expense			16,420				21,301				16,430
Depreciation, depletion and amortization			38,701				81,734				76,850
Impairment of oil and gas properties			43,929				36,970				—
Income tax expense (benefit)			(1,729	)			56,729				(9,180	)
Gain on asset sales			(47,308	)			—				—
Adjusted EBITDA		$	64,616			$	176,558			$	124,155

Endeavour International Corporation

Outlook
2010 Planned Capital Expenditures

We anticipate spending approximately $90 million during 2010 to fund oil and gas activities in the U.S. and U.K. The majority of this amount is controllable by Endeavour. Our primary focus during 2010 in the U.S. will be in the Haynesville area as we believe this acreage contains near-term production potential. The ongoing U.S. program and expenditures will be tailored based on early drilling results. During 2010, we also expect to begin the evaluation program of our other U.S. assets in the Marcellus area and the two frontier plays in Alabama and Montana. Four U.K. wells have been or will be drilled in 2010; two Cygnus appraisal wells in the western portion of the field; the Deacon well that began in 2009 and finished in 2010, and the exploration well west of the Rochelle development. While this drilling is occurring, we expect to continue further our development programs at our four existing development projects, including ongoing engineering assessments for future production and commercial off-take solutions. We intend to fund these development activities through cash on hand, and cash flow generated from operations, as well as expansion of our credit facilities as needed.

The timing, completion and process of our 2010 capital program is subject to a number of factors, including availability of capital, drilling results, drilling and production costs, availability of drilling services and equipment, partner approvals and technical work. Based on these and other factors, we may increase or decrease our planned capital program or prioritize certain projects over others.

Estimated Average Production (A)
Daily Production (BOE per day)			4,500			to					6,000
Differentials (B)
Oil ($/Bbl)		$	(5.00	)		to				$	(6.00	)
Gas ($Mcf)		$	(0.50	)		to				$	(0.60	)
Gas Percentage of Total			55	%		to					60	%
Lease Operating Expense ($  per barrel)		$	8.00			to				$	10.00

Liquidity and Financial Resources

Our primary sources of financial resources and liquidity are internally generated cash flows from operations and access to the credit and capital markets, to the extent available. We believe the

Endeavour International Corporation

combination of our available cash on hand, cash flow from operations and our ability to control capital expenditures will allow us to manage our business effectively while enabling us to further our strategic objectives.

Our cash flows will be significantly impacted by the amount of hydrocarbons we produce, the price we obtain for our produced commodities and taxes paid on operations. Oil prices continue to be impacted by supply and demand on a worldwide basis, while natural gas prices are more impacted by regional economic and weather patterns. Although oil and gas prices have remained volatile, the full impact on our cash flows will be partially mitigated by our balance of gas to oil production and our commodity derivative positions. As of December 31, 2009, our outstanding commodity derivatives covered 30% to 45% of expected 2010 production.

Our income tax expense relates primarily to our operations in the UK (statutory income tax rate of 50%). We are currently not able to record income tax benefits on our U.S. loss as there is no assurance that we can generate any U.S. taxable earnings. As operations expand in the U.S., we will be able to record income tax benefits in the U.S., however we do not anticipate paying current federal income taxes in the U.S. for quite some time.

In February 2010, we issued 23.5 million shares of common stock for an aggregate net proceeds of $20.5 million. We also entered into a $25 million junior lending facility, with a maturity date of February 5, 2011, and interest at LIBOR plus 8%. Upon entering the new junior lending facility, we borrowed $15 million against the facility. The net proceeds from these transactions will be used to partially fund our 2010 capital budget.

At December 31, 2009, we had $49.9 million outstanding under our senior bank facility. The senior bank facility has a current borrowing base capacity of $50 million, which is secured by our oil and gas assets. In February 2010, the maturity date of the senior bank facility was changed to January 31, 2011. We also have $50.1 million of Subordinated Notes that amortize over four years commencing in March 2011.

With the Junior Facility and Senior Bank Facility, we will have $65 million in debt due in the first quarter of 2011, based on outstanding balances at February 28, 2010. During 2010, we plan to utilize our existing U.K. oil and gas assets, as well as our growing U.S. reserve base, as a basis for refinancing and expansion of our credit facilities. We are currently in discussions with several parties concerning this process. We strive to synchronize our capital expenditures with our cash flow. However, we believe our existing U.K. reserves, including probable reserves, are of significant value and together with our U.S. assets can be used as support for increased financial resources when necessary to fund our on-going activities or refinance indebtedness. We continually monitor the capital markets to evaluate the most appropriate actions to fund our activities.

On March 15, 2010, we announced that our board of directors has approved a review of strategic alternatives for its North Sea assets. In an effort to unlock the value of our underlying North Sea assets, we will study a full range of options, including:

•

Continuing to execute current operations plan;

Endeavour International Corporation

•

Entering into a joint venture to accelerate activities in the North Sea; and

•

Selling specific assets or the North Sea entire business.

We will announce the results of the effort once a course of action is chosen. At the end of this review process, we may elect to make no changes.

Disclosures about Contractual Obligations and Commercial Commitments

The following table sets forth our obligations and commitments to make future payments under its lease agreements and other long-term obligations as of December 31, 2009:

		Payments due by Period
						Less
						than 1				1-3				3-5				After 5
(Amounts in thousands)		Total				Year				Years				Years				Years
Long-term debt
Principal		$	231,152			$	—			$	161,192			$	69,960			$	—
Interest (1)			56,962				11,323				13,728				31,911				—
Asset retirement obligations			47,362				3,249				51				—				44,062
Operating leases for office leases and equipment			1,073				638				393				42				—
Rig commitments (2)			17,055				17,055				—				—				—
Total Contractual Obligations		$	353,604			$	32,265			$	175,364			$	101,913			$	44,062

Off-Balance Sheet Arrangements

At December 31, 2010, we did not have any off-balance sheet arrangements.

Endeavour International Corporation

Rig Commitments

Our rig commitments represent one commitment for 46 days of a rig in the U.K. We are currently considering the timing of rig deliverability and completion of the commitment.

Critical Accounting Policies and Estimates

The accompanying financial statements have been prepared on the accrual basis of accounting in accordance with accounting principles generally accepted in the United States of America and have been presented on a going concern basis, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business. These accounting principles require management to use estimates, judgments and assumptions that affect the reported amounts of assets and liabilities as of the date of the financial statements, and revenues and expenses during the reporting period. Management reviews its estimates, including those related to the determination of proved reserves, estimates of future dismantlement costs, income taxes and litigation. Actual results could differ from those estimates.

Management believes it is reasonably possible that the following material estimates affecting the financial statements could change in the coming year: (1) estimates of proved oil and gas reserves, (2) estimates as to the expected future cash flow from proved oil and gas properties, (3) estimates of future dismantlement and restoration costs, (4) estimates of fair values used in purchase accounting and (5) estimates of the fair value of derivative instruments. In addition, alternatives may exist among various accounting methods. In such cases, the choice of accounting method may also have a significant impact on reported amounts.

Our critical accounting policies are as follows:

Full Cost Accounting

Under the full cost method, all acquisition, exploration and development costs, including certain directly related employee costs and a portion of interest expense, incurred for the purpose of finding oil and gas are capitalized and accumulated in pools on a country-by-country basis. Capitalized costs include the cost of drilling and equipping productive wells, including the estimated costs of dismantling and abandoning these assets, dry hole costs, lease acquisition costs, seismic and other geological and geophysical costs, delay rentals and costs related to such activities. Employee costs associated with production and other operating activities and general corporate activities are expensed in the period incurred.

Capitalized costs are limited on a country-by-country basis (the ceiling test). The ceiling test limitation is calculated as the sum of the present value of future net cash flows related to estimated production of proved reserves, using the average, first-day-of-the-month price during the 12-month period before the end of the year for 2009 and the year-end price for 2008 and 2007, including the effect of derivative instruments that qualify as cash flow hedges, discounted at 10%, plus the lower of cost or estimated fair value of unproved properties, all net of expected

Endeavour International Corporation

income tax effects. Under the ceiling test, if the capitalized cost of the full cost pool, net of deferred taxes, exceeds the ceiling limitation, the excess is charged as an impairment expense.

We utilize a single cost center for each country where we have operations for amortization purposes. Any conveyances of properties are treated as adjustments to the cost of oil and gas properties with no gain or loss recognized unless the operations are suspended in the entire cost center or the conveyance is significant in nature.

Unproved property costs include the costs associated with unevaluated properties and properties under development and are not included in the full cost amortization base (where proved reserves exist) until the project is evaluated. These costs include unproved leasehold acreage, seismic data, wells and production facilities in progress and wells pending determination, together with interest costs capitalized for these projects. Seismic data costs are associated with specific unevaluated properties where the seismic data is acquired for the purpose of evaluating acreage or trends covered by a leasehold interest owned by us. Significant unproved properties are assessed periodically for possible impairment or reduction in value. If a reduction in value has occurred, these property costs are considered impaired and are transferred to the related full cost pool. Geological and geophysical costs included in unproved properties are transferred to the full cost amortization base along with the associated leasehold costs on a specific project basis. Costs associated with wells in progress and wells pending determination are transferred to the amortization base once a determination is made whether or not proved reserves can be assigned to the property. Costs of dry holes are transferred to the amortization base immediately upon determination that the well is unsuccessful. Unproved properties whose acquisition costs are not individually significant are aggregated, the portion of such costs estimated to be ultimately nonproductive, based on experience, are amortized to the full cost pool over an average holding period.

In countries where the existence of proved reserves has not yet been determined, unevaluated property costs remain capitalized in unproved property cost centers until proved reserves have been established, exploration activities cease or impairment and reduction in value occurs. If exploration activities result in the establishment of a proved reserve base, amounts in the unproved property cost center are reclassified as proved properties and become subject to amortization and the application of the ceiling test. When it is determined that the value of unproved property costs have been permanently diminished (in part or in whole) based on the impairment evaluation and future exploration plans, the unproved property cost centers related to the area of interest are impaired, and accumulated costs charged against earnings.

We capitalize interest on expenditures for significant exploration and development projects while activities are in progress to bring the assets to their intended use. Capitalized interest is calculated by multiplying our weighted-average interest rate on debt by the amount of qualifying costs and is limited to gross interest expense. As costs are transferred to the full cost pool, the associated capitalized interest is also transferred to the full cost pool.

Endeavour International Corporation

Business Combinations

Assets and liabilities acquired through a business combination are recorded at estimated fair value. We use all available information to make these fair value determinations, including information commonly considered by our engineers in valuing individual oil and gas properties and sales prices for similar assets. Estimated deferred taxes are based on available information concerning the tax basis of the acquired company’s assets and liabilities and carryforwards at the merger date.

Any excess of the acquisition cost of the acquired business over the fair value amounts assigned to assets and liabilities is recorded as goodwill. Any excess of the amounts assigned to assets and liabilities over the acquisition of the acquired business is recorded as a gain on acquisition on the income statement. The amount of goodwill recorded in any particular business combination can vary significantly depending upon the fair values attributed to assets acquired and liabilities assumed relative to the total acquisition cost.

Goodwill and Intangible Assets

Goodwill represents the excess of the purchase price over the estimated fair value of the assets acquired and liabilities assumed in an acquisition. Intangible assets represent the purchase price allocation to the assembled workforce as a result of the acquisition of NSNV, Inc. We assess the carrying amount of goodwill and other indefinite-lived intangible assets by testing the asset for impairment annually at year-end, or more frequently if events or changes in circumstances indicate that the asset might be impaired. The impairment test requires allocating goodwill and all other assets and liabilities to reporting units. The fair value of each reporting unit is determined and compared to the book value of the reporting unit. An impairment loss is recognized to the extent that the carrying amount exceeds the asset’s fair value.

At December 31, 2009, we had $211.9 million of goodwill recorded related to past business combinations. This goodwill is not amortized, but is required to be assessed for impairment annually, or more often as facts and circumstances warrant. The first step of that process is to compare the fair value of the reporting unit to which goodwill has been assigned to the carrying amount of the associated net assets and goodwill. The reporting units used to evaluate and measure goodwill for impairment are determined from the manner in which the business is managed. We have determined we have a single reporting unit. Goodwill is tested annually at year end. Although we cannot predict when or if goodwill will be impaired, impairment charges may occur if we are unable to replace the value of our depleting asset base or if other adverse events (for example, lower sustained oil and gas prices) reduce the fair value of the reporting unit.

We completed our 2009 annual goodwill impairment test with no impairment indicated as the estimated fair value of our reporting unit was substantially greater than its book value. We considered our market capitalization based on average stock prices for 20 days before December 31, 2009.

Endeavour International Corporation

A lower fair value estimate in the future could result in impairment. Examples of factors that could cause a lower fair value estimate could be sustained declines in prices, increases in costs, and changes in discount rate assumptions due to market conditions.

Dismantlement, Restoration and Environmental Costs

We recognize liabilities for asset retirement obligations associated with tangible long-lived assets, such as producing well sites, offshore production platforms, and natural gas processing plants, with a corresponding increase in the related long-lived asset. The asset retirement cost is depreciated along with the property and equipment in the full cost pool. The asset retirement obligation is recorded at fair value and accretion expense, recognized over the life of the property, increases the liability to its expected settlement value. If the fair value of the estimated asset retirement obligation changes, an adjustment is recorded for both the asset retirement obligation and the asset retirement cost.

Revenue Recognition

We use the entitlements method to account for sales of gas production. We may receive more or less than our entitled share of production. Under the entitlements method, if we receive more than our entitled share of production, the imbalance is treated as a liability at the market price at the time the imbalance occurred. If we receive less than our entitled share, the imbalance is recorded as an asset at the lower of the current market price or the market price at the time the imbalance occurred. Oil revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred, title has transferred and collectability of the revenue is probable.

Derivative Instruments and Hedging Activities

From time to time, we may utilize derivative financial instruments to hedge cash flows from operations or to hedge the fair value of financial instruments. We may use derivative financial instruments with respect to a portion of our oil and gas production or a portion of our variable rate debt to achieve a more predictable cash flow by reducing our exposure to price fluctuations. These transactions are likely to be swaps, collars or options and to be entered into with major financial institutions or commodities trading institutions. Derivative financial instruments are intended to reduce our exposure to declines in the market prices of crude oil and natural gas that we produce and sell, to increases in interest rates and to manage cash flows in support of our annual capital expenditure budget. We also have embedded derivatives related to our debt instruments and convertible preferred stock.

We record all derivatives at fair market value in our Consolidated Balance Sheets at the end of each period. The accounting for the fair market value, and the changes from period to period, depends on the intended use of the derivative and the resulting designation. This evaluation is determined at each derivative’s inception and begins with the decision to account for the derivative as a hedge, if applicable. The accounting for changes in the fair value of a derivative

Endeavour International Corporation

instrument that is not accounted for as a hedge is included in other (income) expense as an unrealized gain or loss. Where we intend to account for a derivative as a hedge, we document, at its inception, the hedging relationship, the risk management objective and the strategy for undertaking the hedge. The documentation includes the identification of the hedging instrument, the hedged item or transaction, the nature of the risk being hedged, and the method that will be used to assess effectiveness of derivative instruments that receive hedge accounting treatment.

Changes in fair value to hedge instruments, to the extent the hedge is effective, are recognized in other comprehensive income until the forecasted transaction occurs. Hedge effectiveness is assessed at least quarterly based on total changes in the derivative’s fair value. Any ineffective portion of the derivative instrument’s change in fair value is recognized immediately in other (income) expense.

We discontinue hedge accounting prospectively when (1) we determine that the derivative is no longer effective in offsetting changes in the fair value or cash flows of a hedged item (including hedged items such as firm commitments or forecasted transactions); (2) the derivative expires; (3) it is no longer probable that the forecasted transaction will occur; (4) a hedged firm commitment no longer meets the definition of a firm commitment; or (5) management determines that designating the derivative as a hedging instrument is no longer appropriate.

Income Taxes

We use the liability method of accounting for income taxes under which deferred tax assets and liabilities are recognized for the estimated future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities, and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates in effect for the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized as part of the provision for income taxes in the period that includes the enactment date. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of, or all of, the deferred tax assets will not be realized.

Stock-Based Compensation Arrangements

We recognize all share-based payments to employees, including grants of employee stock options, based on their fair values. The share-based compensation cost is measured at the grant date, based on the calculated fair value of the award, and is recognized as general and administrative expense over the employee’s requisite service period (generally the vesting period of the equity award). We apply the fair value method in accounting for stock option grants to non-employees using the Black-Scholes Method.

It is our policy to use authorized but unissued shares of stock when stock options are exercised. At December 31,2009, we had approximately 7.0 million additional shares available for issuance pursuant to our existing stock incentive plan.

Endeavour International Corporation

Fair Value

We estimate fair value for the measurement of derivatives, long-lived assets during certain impairment tests, reporting units for goodwill impairment testing, the initial measurement of an asset retirement obligation and the initial measurement of our Series C Preferred Stock upon its redemption and modification. When we are required to measure fair value, and there is not a market observable price for the asset or liability, or a market observable price for a similar asset or liability, we generally utilize an income valuation approach. This approach utilizes management’s best assumptions regarding expectations of projected cash flows, and discounts the expected cash flows using a commensurate risk adjusted discount rate. Such evaluations involve a significant amount of judgment since the results are based on expected future events or conditions, such as sales prices; estimates of future oil and gas production; development and operating costs and the timing thereof; economic and regulatory climates and other factors. Our estimates of future net cash flows are inherently imprecise because they reflect management’s expectation of future conditions that are often outside of management’s control. However, assumptions used reflect a market participant’s view of long-term prices, costs and other factors, and are consistent with assumptions used in our business plans and investment decisions.

Item 7A.		Quantitative and Qualitative Disclosures About Market Risk

Foreign Exchange Risk

The international scope of our business operations exposes us to the risk of fluctuations in foreign currency markets. As a result, we are subject to foreign currency exchange rate risk due to effects that foreign exchange rate movements have on our costs and on the cash flows that we receive from foreign operations. Our oil revenues are received in U.S. dollars while gas revenues in the U.K. are received in pounds sterling. Capital expenditures, payroll and operating expenses may be denominated in U.S. dollars or pounds sterling. We operate a centralized currency management operation to take advantage of potential opportunities to naturally offset exposures against each other. To date, we have addressed our foreign currency exchange rate risks principally by maintaining our liquid assets in interest-bearing accounts, until payments in foreign currency are required. We have not reduced this risk by hedging to date as the timing expenditures in pounds sterling has been predictable and we have been able to match revenues received in pounds sterling and foreign currency purchases to minimize our exposure to foreign currency exchange rate risk.

Commodity Price Risk

We produce and sell crude oil and natural gas. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and regional gas spot market prices which have been volatile and unpredictable for several years. As a result, our financial results can be significantly impacted as these commodity prices fluctuate widely in response to changing market forces. We

Endeavour International Corporation

may engage in oil and gas hedging activities to realize commodity prices which we consider favorable.

At December 31, 2009, we had the following commodity derivative instruments outstanding:

		2010				2011				Total
Oil:
Fixed Price Swaps (Mbbl)			533				487				1,020
Weighted Average Price ($/Barrel)		$	68.39			$	66.01			$	67.25
Gas: (1)
Fixed Price Swaps (MMcf)			1,032				627				1,659
Weighted Average Price ($/Mcf)		$	8.68			$	8.32			$	8.54

At December 31, 2009 and 2008, the prices used to determine the estimates of future cash inflows were $60.40 and $36.55 per barrel, respectively, for oil and $4.96 and $8.70 per Mcf, respectively, for gas. The fair value of our commodity derivatives was $12.8 million at December 31, 2009.

Interest Rate Risk

We are exposed to changes in interest rates. Changes in interest rates affect the interest earned on cash and cash equivalents and the interest rate paid on certain borrowings under debt. A 250 point change in basis points on LIBOR would not result in a material change in our annual interest expense, given our floating rate debt at December 31, 2009.

Endeavour International Corporation

Item 8.		Financial Statements and Supplementary Data

Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders
Endeavour International Corporation:

We have audited the accompanying consolidated balance sheets of Endeavour International Corporation and subsidiaries as of December 31, 2009 and 2008, and the related consolidated statements of operations, stockholders’ equity and comprehensive income, and cash flows for each of the years in the three-year period ended December 31, 2009. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Endeavour International Corporation and subsidiaries as of December 31, 2009 and 2008, and the results of their operations and their cash flows for each of the years in the three-year period ended December 31, 2009, in conformity with U.S. generally accepted accounting principles.

As discussed in note 2 to the consolidated financial statements, effective January 1, 2008, the Company changed its method of accounting and disclosures for fair value measurements and fair value reporting of financial assets and liabilities. Also as discussed in note 2 to the consolidated financial statements, effective December 31, 2009, the Company has changed it reserve estimates and related disclosures as a result of adopting new oil and gas reserve estimation and disclosure requirements.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Endeavour International Corporation’s internal control over financial reporting as of December 31, 2009, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated March 16, 2010 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

/S/ KPMG LLP
Houston, Texas
March 16, 2010

Endeavour International Corporation
Consolidated Balance Sheets
(Amounts in thousands)

		December 31,
		2009				2008
Assets
Current Assets:
Cash and cash equivalents		$	27,287			$	31,421
Restricted cash			2,879				20,739
Accounts receivable			14,800				22,325
Prepaid expenses and other current assets			10,118				42,194
Current assets of discontinued operations			—				16,726
Total Current Assets			55,084				133,405
Property and Equipment, Net			266,587				232,346
Goodwill			211,886				213,949
Other Assets			5,322				9,165
Long Term Assets of Discontinued Operations			—				148,605
Total Assets		$	538,879			$	737,470