United States

Securities and Exchange Commission

Washington, D.C. 20549

Form 8-K

Current Report

Pursuant to Section 13 or 15(d)

of the Securities Exchange Act of 1934

Date of Report (Date of earliest event reported) August 5, 2014

Endeavour International Corporation

(Exact name of registrant as specified in its charter)

811 Main Street, Suite 2100, Houston, Texas 77002

(Address of principal executive offices) (Zip code)

(713) 307-8700

Registrant’s telephone number, including area code

None

(Former name, former address and former fiscal year, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

On August 5, 2014, we issued a press release with respect to our second quarter 2014 financial and operational results. The press release is furnished as Exhibit 99.1 to this Current Report on Form 8-K and is incorporated by reference herein. The press release contains measures (discussed below) that may be deemed non-GAAP financial measures as defined in Item. 10 of Regulation S-K under the Securities and Exchange Act of 1934 (the “Exchange Act”). The most directly comparable generally accepted accounting principles (GAAP) financial measures and information reconciling the GAAP and non-GAAP financial measures are also included in the press release.

In the press release, we refer to certain non-GAAP financial measures we call net income as adjusted and adjusted EBITDA. Management believes these measures are key metrics for the Company and our ability to internally fund capital expenditures and service existing debt. Management believes these non-GAAP financial measures are useful information to investors because they exclude non-operating fluctuations in assets and liabilities and are widely used by professional research analysts in the valuation, comparison, rating and investment recommendations of companies within the oil and gas exploration and production industry.

In accordance with General Instruction B.2 of Form 8-K, the foregoing information, including Exhibit 99.1, shall not be deemed “filed” for the purposes of Section 18 of the Exchange Act or otherwise subject to the liabilities of that section, nor shall such information, including Exhibit 99.1, be deemed incorporated by reference into any filing under the Securities Act of 1933 or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

The information set forth under Item 2.02 of this Current Report on Form 8-K and the slide presentation attached as Exhibit 99.2 are hereby incorporated in Item 7.01 by reference.

In accordance with General Instruction B.2 of Form 8-K, the foregoing information, including Exhibits 99.1 and 99.2, shall not be deemed “filed” for the purposes of Section 18 of the Exchange Act or otherwise subject to the liabilities of that section, nor shall such information, including Exhibits 99.1 and 99.2, be deemed incorporated by reference into any filing under the Securities Act of 1933 or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

Date: August 5, 2014

Exhibit 99.1

For immediate release

Endeavour Announces 2014 Second Quarter

Financial and Operational Results

Houston, August 5, 2014 – Endeavour International Corporation (NYSE: END) (LSE: ENDV) today reported physical production for the quarter that exceeded the Company’s revised guidance range of 10,500 – 11,500 barrels of oil equivalent per day (“boepd”) previously announced on June 10, 2014. Physical production for the second quarter of 2014 averaged 12,900 boepd compared to 9,500 boepd for the same quarter of 2013. Sales volumes for the second quarter of 2014 were 7,400 boepd, compared to 14,500 boepd for the same quarter in the prior year.

The Company did not have a lifting of production at the Alba field during the quarter, so revenues were significantly lower than would have been if based on physical production. Physical production for the quarter produced but not lifted is recorded as deferred revenue on the balance sheet. Endeavour estimates that there will be three to four liftings per year at the Alba field. The most recent lifting occurred on July 4, 2014 and the associated revenues of approximately $50 million will be reflected in the Company’s third quarter results. A similar situation occurred in the third quarter of 2013, when there was no lifting at the Alba field.

The Company reported a second quarter 2014 net loss, as adjusted of $38.7 million compared to a net loss, as adjusted of $12.6 million for the same period in 2013. On a GAAP basis, net loss for the second quarter was $36.7 million as compared to net loss of $13.9 million for the same quarter in 2013.

Recent Events:

“During the quarter we were able to establish production from both wells at the Rochelle field. We experienced periods during the quarter where production rates exceeded 100 million cubic feet of gas per day (“mmcfd”) and 4,000 boepd. This confirms our confidence in the Rochelle field’s potential,”

said William L. Transier, chairman, chief executive officer and president. “However, we continue to be challenged by unexpected downtime and lower production efficiency rates which are directly attributable to the production facilities we do not control. We are working with the operators at Alba and Rochelle to improve ongoing performance.”

Operational Update

North Sea

At Rochelle, the West Rochelle (W1) development well was returned to production in mid-May. The E2 and W1 wells produced together during the quarter and achieved production rates greater than 100 million cubic feet equivalent per day (“mmcfed”) for 32 days during the second quarter. The Scott Platform began its planned shutdown period on July 27, 2014 and so the Rochelle Field is expected to be shut-in for three weeks until the Scott Platform goes back into service. The shutdown at the Scott Platform is being executed to coincide with the previously announced maintenance work occurring on the Forties Pipeline System. Endeavour has a 44% working interest in Rochelle.

At Alba, the A69 well is being completed and is expected to start production this month. Progress was made in the southern part of the field with partial water injection being reinstated. Installation of the replacement pipeline is planned early in the first quarter of 2015, with start-up expected in the second quarter. The partial reinstatement of water injection in the southern part of the field has sustained production throughout the second quarter. Well A69 is expected to increase overall production rates in the third quarter. Endeavour has a 25.68% working interest in Alba.

Bacchus continues to perform at rates above the Company’s expectations. The B3Y well has not, as expected, been turned into a water injector because of certain technical issues. Future options for the B3Y well continue to be evaluated. Endeavour has a 30% working interest in the field.

North America

In the Pennsylvania Marcellus, Endeavour successfully completed hydraulic fracture stimulation of the C-13 horizontal well, the third completion this year in the Daniel Field. The Company’s operated activity included more than double the number of frac stages on the longest laterals to date relative to previous wells. Following these successful well completions, operatorship of the Marcellus assets was transferred to Samson Exploration, LLC. Later this year, the wells will be tied into a new third-party pipeline being commissioned by EQT Corporation that allows firm capacity of up to 10 mmcfd, with potential for future expansion.

In the Piceance Basin Rim play in Northwest Colorado, Endeavour has two projects targeting liquids-rich Niobrara and Frontier objectives. At present, a rig has commenced drilling an initial horizontal Niobrara test at the Company’s Wiley prospect. Endeavour has leasehold and drilling options on 40,000 gross acres and 27,000 net acres.

Finance

In May, Endeavour entered into a third forward sale agreement receiving a payment of $22.5 million. This effectively hedged a portion of production by locking in pricing for in excess of 200,000 barrels of oil, over a six-month delivery period. The forward sale is expected to be fulfilled in November 2014. The first forward sale commitment was fulfilled in June 2013 and the second in March 2014.

In January of this year, the Company refinanced its revolving credit facility ($115 million at 13%) and two reimbursement agreements ($120 million at 13% and $33 million at 9% interest) into a new senior

secured first lien term loan with an interest rate of 8.25% (libor + 700 basis points). During the second quarter, the first full quarter reflecting the refinancing impact, Endeavour realized cash interest expense savings of $4 million ($16 million on annualized basis). In addition, gross general and administrative expenses were reduced, as a result of the previously announced consolidation of the Company’s U.K. offices, headcount reductions and other cost reduction initiatives.

Also during the quarter, the Company settled an insurance claim for the Rochelle E1Y well, which was damaged in early 2013, for £7.5 million (approximately $12.6 million). The proceeds from the settlement were received in June.

Third Quarter Production Guidance and Maintenance Downtime

In the U.K. North Sea, the third quarter is typically the time to perform maintenance and other tasks on infrastructure. During 2014, Endeavour anticipates that all of its producing fields will be modestly impacted. These shutdowns will be less invasive than those experienced in 2013, but will still have an impact on third quarter physical production.

At present, there is a 16 day shutdown on the Forties Pipeline System planned in August that will affect oil production from Bacchus and Rochelle. Currently underway is a three week Rochelle shutdown which coincides with the work being done at Forties. At Alba during August, a short shutdown of three days is planned to test the emergency systems. Average daily physical production volumes are expected to be in the range of 9,500 – 10,500 boepd for the third quarter of 2014.

Earnings Conference Call, Tuesday, August 5, 2014 at 9:00 a.m., Central Time, 3:00 p.m. British Summer Time

Endeavour International will host a conference call and web cast to discuss its 2014 second quarter financial and operating results on Tuesday, August 5, 2014 at 9:00 a.m. Central Time, 3:00 p.m. British Summer Time. A supporting slide deck for the conference call is available on the home page of Endeavour’s website at www.endeavourcorp.com and under the Investor Relations section in conjunction with the details for the conference call. To participate and ask questions during the conference call, dial the local country telephone number and the confirmation code 3569591. The toll-free numbers are 888-221-3886 in the United States and 0-808-101-7548 in the United Kingdom. Other international callers should dial 913-312-1453 (tolls apply). To listen only to the live audio web cast access Endeavour’s home page at www.endeavourcorp.com. A replay will be available beginning at 12:00 p.m. Central Time on August 5, 2014 through 12:00 p.m. on August 11, 2014 by dialing toll free 888-203-1112 (U.S.) or 719-457-0820 (international), confirmation code 3569591.

Endeavour International Corporation is an oil and gas exploration and production company focused on the acquisition, exploration and development of energy reserves in the North Sea and the United States. For more information, visit www.endeavourcorp.com.

Additional information for investors:

Certain statements in this news release should be regarded as “forward-looking” statements within the meaning of the securities laws. These statements speak only as of the date made. Such statements are subject to assumptions, risk and uncertainty. Actual results or events may vary materially.

The Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only proved reserves, but also probable reserves and possible reserves that meet the SEC’s definitions for such terms, and

price and cost sensitivities for such reserves, and prohibits disclosure of resources that do not constitute such reserves. We may use certain terms in our news releases, such as “reserve potential,” that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. In addition, we do not represent that the probable or possible reserves described herein meet the recoverability thresholds established by the SEC in its new definitions. Investors are urged to also consider closely the disclosure in our filings with the SEC, available from our website at www.endeavourcorp.com. Endeavour is also subject to the requirements of the London Stock Exchange and considers the disclosures in this release to be appropriate and/or required under the guidelines of that exchange.

For further information:

Endeavour International Corporation

Condensed Consolidated Balance Sheets

(Amounts in thousands)

Endeavour International Corporation

Condensed Consolidated Statement of Operations

(Unaudited)

(Amounts in thousands, except per share data)

Endeavour International Corporation

Condensed Consolidated Statement of Cash Flows

(Unaudited)

(Amounts in thousands)

Endeavour International Corporation

Operating Statistics

(Unaudited)

Endeavour International Corporation

Reconciliation of GAAP to Non-GAAP Measures

(Unaudited)

(Amounts in thousands)

As required under Regulation G of the Securities Exchange Act of 1934, provided below are reconciliations of net loss to the following non-GAAP financial measures: net income (loss), as adjusted and Adjusted EBITDA. We use these non-GAAP measures as key metrics for our management and to demonstrate our ability to internally fund capital expenditures and service debt. The non-GAAP measures are useful in comparisons of oil and gas exploration and production companies as they exclude non-operating fluctuations in assets and liabilities.

Second Quarter 2014 Earnings Review August 5, 2014 Exhibit 99.2

2 This presentation contains certain forward-looking statements regarding various oil and gas discoveries, oil and gas exploration, development and production activities, anticipated and potential production and  flow rates; anticipated revenues; the economic potential of properties and estimated exploration costs.  Accuracy of the projections depends on assumptions about events that change over time and is thus  susceptible to periodic change based on actual experience and new developments. Endeavour cautions  readers that it assumes no obligation to update or publicly release any revisions to the projections in this  presentation and, except to the extent required by applicable law, does not intend to update or otherwise revise the projections. Important factors that might cause future results to differ from these projections  include: variations in the market prices of oil and natural gas; drilling results; access to equipment and  oilfield services; unanticipated fluctuations in flow rates of producing wells related to mechanical, reservoir   or facilities performance; oil and natural gas reserves expectations; the ability to satisfy future cash  obligations and environmental costs; and general exploration and development risks and hazards. The Securities and Exchange Commission permits oil and gas companies in their filings with the SEC to  disclose only proved reserves that a company has demonstrated by actual production or conclusive  formation tests to be economically and legally producible under existing economic and operating  conditions. SEC guidelines prohibit the use in filings of terms such as “probable,” “possible,” P2 or P3 and  “non-proved” reserves, reserves “potential” or “upside” or other descriptions of volumes of reserves  potentially recoverable through additional drilling or recovery techniques.  These estimates are by their  nature more speculative than estimates of proved reserves and accordingly are subject to greater risk of  being actually realized by the company. Certain statements should be regarded as “forward-looking”  statements within the meaning of the securities laws. These statements speak only as of the date made.  Such statements are subject to assumptions, risk and uncertainty. Actual results or events may vary  materially.  The estimates of recoverable resources per well and completed well costs included herein are  based upon other typical results in these shale plays and may not be indicative of actual results.

3 Physical production and sales volumes • Physical production averaged 12,900 barrels of oil equivalent per day (“boepd”) compared to 9,500 boepd during Q2 2013 • Production rates at Rochelle exceeded 100 million cubic feet equivalent/per day (“mmcfed”) for 32 days during the quarter • Sales volumes were 7,400 boepd compared to 14,500 boepd during Q2 2013. The Company did not have a lifting at Alba during the second quarter, affecting sales volumes. Restarted production from the West Rochelle (W1) well, flowing both wells together for the first time • During the quarter, the field experienced periods where flow rates were in excess of 100 million cubic feet of gas per day (“mmcfd”) and 4,000 boepd, representing 9,000 boepd – 9,500 boepd net to Endeavour Finished the hydraulic fracture of a Pennsylvania Marcellus well • The third completion in the Daniel Field in 2014 Executed a forward sale in May for $22.5 million • This third forward sale is expected to be fulfilled in November 2014 Received insurance proceeds of $12.6 million for the Rochelle E1Y well damaged in early 2013 2014 Second Quarter – Operational/Financial Results

Sales Volumes and Physical Production (BOE per day)      Physical production volume for the second quarter averaged 12,900 boepd compared to 9,500 boepd during Q2 2013 Q2 sales volumes were affected during the quarter by no lifting occurring at the Alba field Consolidated second quarter realized prices 2014 Q2 Sales = 7,400 2013 Q2 Sales = 14,500 4 • Oil and condensate price = $106.32 per barrel • Gas price = $7.03 per Mcf US Gas      UK Oil UK Gas 38% 52% 10% 91% 9%

Key Commodities - Forward Pricing* 5 *Data as of August 1, 2014 1£ = $1.70 U.K. Oil U.K. Gas $95 $100 $105 $110 $115 Brent Strip (ICE) $6 $7 $8 $9 $10 $11 $12 National Balancing Point (NBP) Strip (ICE)

U.K. Hedged Oil and Gas Position 6 The current hedging program involves embedding collars within existing production marketing contracts and includes the forward sale completed in May 2014 1,000 2,000 3,000 4,000 5,000 6,000 1Q2014 2Q2014 3Q2014 4Q2014 $0 $20 $40 $60 $80 $100 $120 Hedged Production Ave Ceiling Ave Floor

7 Summary Financial Results A July 4, 2014 lifting at the Alba field represents approximately $50 million in revenues. The monies will be reflected in Oil and Gas Revenues in the third quarter Measure ($ in millions) 2014 2013 2014 2013 Oil and gas revenues 44.9 $             126.2 $           139.0 $           183.8 $           Operating expenses 6.8 $               38.1 $             34.0 $             55.6 $             Adjusted cash flow from operations 38.1 $             88.1 $             105.0 $           128.2 $           Second Quarter Ending June 30, Six Months Ending    June 30,

8 Adjusted EBITDA Measure ($ in millions) 2014 2013 2014 2013 Net income (loss) (36.7) $            (13.9) $            (81.5) $            (27.9) $            Unrealized (gain) loss on derivatives (2.0)                 1.3                  (4.7)                 (0.3)                 Net interest expense 31.4                24.5                62.9                45.8                Litigation settlement -                     -                     19.0                -                     Letter of credit fees 2.3                  7.1                  6.1                  18.5                Loss on early extinguishment of debt -                     -                     3.5                  -                     Depreciation, depletion and amortization 32.3                51.9                77.2                74.9                Impairment of U.S. oil and gas properties -                     -                     -                     3.5                  Income tax expense (benefit) (0.4)                 11.3                3.2                  12.2                Adjusted EBITDA 26.9 $             82.2 $             85.7 $             126.7 $           Second Quarter Ending June 30, Six Months Ending    June 30,

9 Adjusted Net Income (Loss) Measure ($ in millions, except per share data) 2014 2013 2014 2013 Net income (loss) (36.7) $          (13.9) $          (81.5) $          (27.9) $          Impairment of U.S. oil and gas properties - - - 3.5 Unrealized (gain) loss  on derivatives (net of tax) (2.0) 1.3 (4.7) (0.3) Loss on early extinguishment of debt (next of tax) - - 3.5 - Litigation settlement - - 19.0 - Net income (loss) as adjusted (38.7) $          (12.6) $          (63.7) $          (24.7) $          Weighted-average basic shares                      outstanding (in millions) 51.6 47.1 50.6 47.1 Adjusted earning (loss) per basic share (0.75) $          (0.27) $          (1.26) $          (0.52) $          Second Quarter Ending June 30, Six Months Ending    June 30,

10 Capex and Asset Retirement Obligations Update Measure ($ in millions) 2014 2013 2014 2013 Direct oil & gas capex      U.K. 10.6 $            64.4 $            20.8 $            97.5 $                 U.S. 1.0                 2.0                 2.1                 2.8                 Total direct oil & gas capex 11.6               66.4               22.9               100.3             Capitalized interest 2.4                 7.6                 5.0                 13.8               Capitalized G&A 2.9                 1.8                 6.0                 6.8                 Asset retirement obligation and other capex -                   (7.7)                4.8                 (3.5)                Total capital expenditures 16.9 $            68.1 $            38.7 $            117.4 $          Asset retirement obligations paid 4.1 $              9.4 $              20.6 $            14.3 $            Second Quarter Ending June 30, Six Months Ending    June 30,

2014 Direct Capital Expenditure Budget 11 U.S. Other Colorado Alba U.K. Other 2014 Direct Capex = $60 million - $80 million • U.K. = $40 million - $55 million • U.S. = $20 million - $25 million Decommissioning costs for IVRR, Renee and Rubie fields = $50 million

12 Debt Maturity Schedule Convertible Notes due 2016 ($18.51 per share conversion price) Convertible Bonds due 2016 ($16.52 per share conversion price) Senior Notes due 2018 Senior Secured First Lien Term Loan due 2017 Convertible Notes due 2017 ($4.66 per share conversion price) $135 $125 $554 $82 $17.5 $0 $100 $200 $300 $400 $500 2014 2015 2016 2017 2018

LSE:ENDV NYSE:END www.endeavourcorp.com Darcey Matthews Director of Investor Relations (713) 307-8711 darcey.matthews@endeavourcorp.com INVESTOR CONTACTS: