UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

SCHEDULE 14A

Proxy Statement Pursuant to Section 14(a) of the

Securities Exchange Act of 1934

(Amendment No.     )

Filed by the Registrant   x                             Filed by a Party other than the Registrant   ¨

Check the appropriate box:

Whiting Petroleum Corporation

(Name of Registrant as Specified In Its Charter)

(Name of Person(s) Filing Proxy Statement, if other than the Registrant)

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On August 5, 2014, Whiting Petroleum Corporation posted the attached corporate presentation to its website.

Whiting Petroleum Corporation ENERGY + TECHNOLOGY = GROWTH Current Corporate Presentation August 2014

Forward-Looking Statements, Non-GAAP Measures, Reserve and Resource Information Forward-Looking Statements, Non-GAAP Measures, Reserve and Resource Information 2 Energy + Technology = Growth                    This presentation contains statements that Whiting Petroleum Corporation (“Whiting”) believes to be “forward-looking statements” within the meaning of Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts, including statements regarding the expected benefits of Whiting’s proposed acquisition (the “Acquisition”) of Kodiak Oil & Gas Corp. (“Kodiak”) to Whiting and Kodiak and their shareholders, the anticipated completion of the Acquisition or the timing thereof, the expected future reserves, production, financial position, business strategy, revenues, earnings, costs, capital expenditures and debt levels of the combined company, and plans and objectives of management for future operations, are forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those expressed in, or implied by, such statements.  These risks and uncertainties include, but are not limited to: the ability to obtain shareholder, court and regulatory approvals of the Acquisition; the ability to complete the proposed Acquisition on anticipated terms and timetable; Whiting’s and Kodiak’s ability to integrate successfully after the Acquisition and achieve anticipated benefits from the Acquisition; the possibility that various closing conditions for the Acquisition may not be satisfied or waived; oil and natural gas prices; level of success in exploration, development and production activities; the impacts of federal and state laws; the impacts of hedging on results of operations; uncertainty regarding future operating results and plans, objectives and expectations; and other risks described under the caption “Risk Factors” in Whiting’s and Kodiak’s  Annual Reports on Form 10-K for the period ended December 31, 2013 and Quarterly Reports on Form 10-Q for the three months ended June 30, 2014. Whiting assumes no obligation, and disclaim any duty, to update the forward-looking statements in this communication.  Whiting’s production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases.                 In this presentation, we refer to Adjusted Net Income, Discretionary Cash Flow and EBITDAX, which are non-GAAP measures that the Company believes are helpful in evaluating the performance of its business. A reconciliation of such non-GAAP measures to the relevant GAAP measures can be found at the end of the presentation.                 Whiting uses in this presentation the terms proved, probable and possible reserves.  Proved reserves are reserves which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs under existing economic conditions, operating methods and government regulations prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain.  Probable reserves are reserves that are less certain to be recovered than proved reserves, but which, together with proved reserves, are as likely as not to be recovered. Possible reserves are reserves that are less certain to be recovered than probable reserves.  Estimates of probable and possible reserves which may potentially be recoverable through additional drilling or recovery techniques are by nature more uncertain than estimates of proved reserves and accordingly are subject to  substantially greater risk of not actually being realized by the Company.                Whiting uses in this presentation the term “total resources,” which consists of contingent and prospective resources, which SEC rules prohibit in filings of U.S. registrants.  Contingent resources are resources that are potentially recoverable but not yet considered mature enough for commercial development due to technological or business hurdles. For contingent resources to move into the reserves category, the key conditions or contingencies that prevented commercial development must be clarified and removed.  Prospective resources are estimated volumes associated with undiscovered accumulations. These represent quantities of petroleum which are estimated to be potentially recoverable from oil and gas deposits identified on the basis of indirect evidence but which have not yet been drilled. This class represents a higher risk than contingent resources since the risk of discovery is also added.  For prospective resources to become classified as contingent resources, hydrocarbons must be discovered, the accumulations must be further evaluated and an estimate of quantities that would be recoverable under appropriate development projects prepared.  Estimates of resources are by nature more uncertain than reserves and accordingly are subject to substantially greater risk of not actually being  realized by the Company.

Whiting Overview Whiting Petroleum Corporation’s Solberg 34-11 Tripad wells with Nabors drilling rig B15 on the Zalesky 34-8 Tripad, in background. Whiting Overview Whiting Petroleum Corporation is an independent oil and gas company that explores for, develops, acquires and produces crude oil, natural gas and natural gas liquids primarily in the Rocky Mountain and Permian Basin regions of the United States.  The Company’s largest projects are in the Bakken and Three Forks plays in North Dakota, the Redtail Niobrara play in northeast Colorado and its enhanced oil recovery field in Texas.  The Company trades publicly under the symbol WLL on the New York Stock Exchange. Q2 2014 Production 109.8 MBOE/d Proved Reserves (1) 438.5 MMBOE % Oil Reserves (1) 79% (89% Liquids) R/P Ratio (2) 13 years (1) Whiting reserves at December 31, 2013 based on independent engineering. (2) R/P ratio based on year-end 2013 proved reserves and 2013 production. 3 Energy + Technology = Growth

Whiting Petroleum – A Company on the Move Five Significant Second Quarter Achievements 4 (1) Please refer to the Reconciliation of Net Cash Provided by Operating Activities to  Discretionary Cash Flow later in this presentation. Energy + Technology = Growth 1) Announced Agreement to Acquire Kodiak Oil & Gas Corp. on July 13, 2014 2) Record Discretionary Cash Flow of $556.2 Million (1) ; Record Williston Basin Production of 80,195 BOE/d, Up 33% YoY 3) Raised Production Guidance to a mid-point of 20%; Q2 Production Exceeds Top-End of Production Guidance 4) New Completions Using Cemented Liners and Plug and Perf Technology Yielded a 23% Increase in EURs Compared to Wells With Uncemented Liners and Sliding Sleeve Technology 5) Spud the 30F Super Pad in the Horsetail Area to Test 32-Well Spacing Pattern in Niobrara A, B and C Benches in early June 2014; Razor 27I 8-Well Pad Currently Producing Approximately  4,700 BOE/d as of July 21, 2014

A Focused Company Major Asset Areas 5 Energy + Technology = Growth (1) At December 31, 2013 based on independent engineering. 86% 11% 3% 16.8 26.3 30.3 48.9 63.5 80.2 - 20.0 40.0 60.0 80.0 100.0 2009 2010 2011 2012 2013 Q2 2014 Bakken / Three Forks Production MBOE/d Q2 2014 Net Production 109.8 MBOE/d Rocky Mountains Permian Other

Property Area 2014 CAPEX (MM) Gross Wells Net Wells % of Total Northern Rockies 1,101 199 137.2 39% Central Rockies 575 120 104.9 21% EOR Project 203 NA (3) NA (3) 7% Libby Ranch CO2 Develop. (1) 56 2% Other Exploration Drilling 44 9 7.3 2% Non-Operated 332 12% Land 116 4% Facilities 151 5% Exploration Expense (2) 72 3% Well Work, Misc. Costs, Other 150 5% Total Budget $2,800 328 249.4 100% Capital Budget for Key Property Areas in 2014 2014 Mid-Point Production Growth Guidance of +20% (1) For development of CO prospect at Bravo Dome in northeastern New Mexico. (2) Comprised primarily of exploration salaries,   lease delay rentals and seismic activities. (3) This multi-year CO  project involves many re-entries, workovers and conversions. Therefore, it is budgeted on a project basis not a well basis. 6 Energy + Technology = Growth Northern Rockies $1,101 MM Central Rockies $575 MM EOR Project (3) $203 MM Libby Ranch CO2 Development $56 MM (1) Other Exploration Drilling $44 MM Non-Operated $332 MM Land $116 MM Facilities $151 MM Exploration Expense (2) $72 MM Well Work, Misc. Costs, Other $150 MM 2 2

Field Target Gross Acres Net Acres Sanish / Parshall Middle Bakken Three Forks 174,665 82,462 Pronghorn Pronghorn Sand 180,911 116,848 Lewis & Clark Three Forks 172,009 118,039 Hidden Bench Middle Bakken Three Forks 61,024 37,667 Tarpon Middle Bakken Three Forks 8,805 6,267 Starbuck Middle Bakken Three Forks Red River 52,020 42,707 Missouri Breaks Middle Bakken Three Forks 93,678 66,956 Cassandra Middle Bakken Three Forks 29,827 13,953 Big Island Red River 166,126 135,122 Other ND & Montana 120,892 54,141 Total 1,059,957 674,162 Williston Basin Highlights June 30, 2014 7 Energy + Technology = Growth Slickwater Test Sundheim 21-27-1H had 44% greater 120-day rate than offsetting well Waldock Federal 14-4- 3XH completed with 93 stage coiled tubing frac Q2 2014 Completions in Hidden Bench (11 Wells ) Average IP of 2,872 BOE/d Skaar Federal 41-3TFHU completed June 7, 2014 flowing 6,071 BOE/d from the 2nd Bench of the Three Forks

Annulus Stages Frac Ports per Stage Potential Entry Points Free fluid between packers 30 1 30 Annulus Stages Perforation Clusters per Stage Potential Entry Points Cemented 40 3 120 Older Style Sliding Sleeve Completion New Style Cemented Liner Completion Maximizing Recovery Efficiency Improving Frac Distribution 8 Energy + Technology = Growth

Exploiting the Bakken and Three Forks in the Williston Primary and Prospective Drilling Locations 9 Energy + Technology = Growth MISSOURI BREAKS 8 WELLS CASSANDRA 12 WELLS SANISH 15 WELLS PRONGHORN 6 WELLS TARPON 12 WELLS HIDDEN BENCH 16 WELLS

Redtail Development Program Economic Sweet Spot (Weld County, Colorado) OBJECTIVE Niobrara “B” Shale Niobrara “A” Shale DEVELOPMENT PLAN Mix of 960 and 640-acre spacing units 8 Wells per spacing unit Niobrara “B” 8 Wells per spacing unit Niobrara “A” 3,300+ potential drilling locations ACREAGE Whiting has assembled 180,115 gross (128,721 net) acres in our Redtail prospect in the northeastern portion of the DJ Basin. • Average WI of 71% • Average NRI of 59% COMPLETED WELL COST Horizontal:  $5.5 MM DRILLING HIGHLIGHTS First 8-well pad, the Razor 27I (4 Niobrara “A”; 4 Niobrara “B”) pad came online April 15, 2014. The pad was producing 4,699 BOE/d as of July 21, 2014 .  We spud our Horsetail 30F super pad that will test 32-well spacing in the Niobrara “A”, “B” and “C” zones.  10 Source: IHS and internal Whiting production database Energy + Technology = Growth Pre 2013 2013 - 14 BOEPD 1 – 350 350 – 450 450 – 550 550 – 650 650 – 750 > 750 Niobrara Initial 30-Day Average Rate (Gas converted to oil price equivalent ratio 17:1)

Niobrara  Reservoir Whiting RAZOR 25-2514H GR                   Zone        PHI           Minerals        BVFluid                  RES 0                         200 30                          -10                            0                           100 0.2                  2000     A A B B C C Niobrara  Resource Potential (1) * ** GOR=500 cf/bo Stimulated Rock Volume Reservoir Porosity (%) Thickness (ft) OOIP     (MMBOE/ 960ac)* % WLL Wells # Gross Wells NIO A 13% 35 19 81 1,344 NIO B 13% 65 40 81 1,343 NIO C 11% 25 11 80 1,316 70 OOIP by Zone Recoverable Oil 16 Well / DSU Density (Total OOIP A Zone + B Zone = 59 MMBOE/DSU)** 16 wells             10% Recovery 16 wells             15% Recovery 16 wells             20% Recovery 370 MBOE 560 MBOE 740 MBOE (1) Please refer to the beginning of this presentation for disclosures regarding “Reserve and Resource Information.” Estimates updated as of December 31, 2013 Recoverable Oil 32 Well / DSU Density (Total OOIP A Zone + B Zone + C Zone = 70 MMBOE/DSU)** 32 wells             15% Recovery 32 wells             20% Recovery 32 wells             25% Recovery 330 MBOE 440 MBOE 550 MBOE Redtail Development Program Niobrara Reservoirs 11 Energy + Technology = Growth

27L Pad Drilling Density - 16 Wells/DSU - 330 ft. Target:   B-B-B-B Status: Flowing 27K Pad Drilling Density - 16 Wells/DSU - 330 ft. Target:   A-B-A-B Status: Flowing Razor Pilot 16 Wells / 960ac DSU 30F Pad Drilling Density - 32 Wells/DSU - 165 ft. Target: C-B-A-B- A-B-C-B Status: Drilling Horsetail Pilot 32 Wells / 960ac DSU Planned Wells Producing Wells Future Infill Wells Redtail Development Planning Defining Optimal Well Density 12 Energy + Technology = Growth

Redtail Niobrara A & B Type Curve: 420 MBOE Per Well Results: 85%-100% IRRs (1)(2)(3) 13 Energy + Technology = Growth EUR - 420 MBOE, Development Phase CAPEX $5.5 MM NYMEX Oil Price/Bbl $90 $100 ROI 3.2 3.7 IRR (%) 85% 100% Payout (Yrs.) 1.2 1.0 PV10 ($MM) 6.28 7.87 10 100 1000 0 20 40 60 80 100 120 140 160 180 Months on Production (1) Please refer to the beginning of this presentation for disclosures regarding "Reserve and Resource Information."   All volumes shown are un-risked.  Our pre-tax PV10% values do not  purport to present the fair value of our oil and natural gas reserves. (2) EURs, ROIs, IRRs and PV10% values will vary well to well.  Estimates updated as of December 31, 2013. (3) Based on a mix of 17 640- and 960-acre spaced wells drilled since March 21, 2013.

Redtail Infrastructure Plan: A Great Place to Find an Oil Field! June 2014 Redtail Facilities Plan Planned Gathering System Gas Gathering Lines 141 Miles Oil Gathering Lines 111 Miles SW Gathering Lines 54 Miles Frac Water Supply Lines 16 Miles Redtail Gas Plant Train 1 Capacity (Online) 20 MMcf/d Train 2 Capacity (Q1 2015) 50 MMcf/d Train 3 Capacity (2016) 70MMcf/d Takeaway Capacity (2016) 140 MMcf/d Capital Investment Gas Plant $100 MM Gas Gathering / Field Compression $95 MM Oil Gathering / LACTs $80 MM Electricity $40 MM Total $315 MM 14 Energy + Technology = Growth Kinder Morgan Interstate Trailblazer 8” Residue Pipeline Constructed By TallGrass Pony Express Redtail Plant Terrace Plant TallGrass Pawnee Terminal Northeast Colorado Lateral to Pony Express TallGrass Buckingham Terminal

Strong CFPS Growth While Maintaining a Healthy Balance Sheet 15 (1) Please refer to the Reconciliation of Net Cash Provided by Operating activities to Cash Flow Per Share later in this presentation. (2) Please refer to the Reconciliation of Net Income to EBITDAX and Long-term Debt to Net Debt later in this presentation. Energy + Technology = Growth 1.33x 0.77x 1.04x 1.19x 1.05x 0.00x 0.20x 0.40x 0.60x 0.80x 1.00x 1.20x 1.40x 2009 2010 2011 2012 2013 Net Debt to EBITDAX (2) $4.53 $9.25 $10.05 $11.77 $14.59 $0.00 $2.00 $4.00 $6.00 $8.00 $10.00 $12.00 $14.00 $16.00 2009 2010 2011 2012 Cash Flow Per Share Growth (1) 2013

(1) Includes hedging adjustments. Consistently Delivering Strong EBITDA Margins (1) $45.01 $61.48 Oil $93.03/Bbl NGL $39.30/Bbl Gas $6.95/Mcf $73.88 $69.85 $76.76 Oil Focused Strategy Delivers Consistently Strong Margins 16 Energy + Technology = Growth $82.16/BOE $80.00 $0.00 $10.00 $20.00 $30.00 $40.00 $50.00 $60.00 $70.00 $80.00 $90.00 2009 2010 2011 2012 2013 Q1 2014 Q2 2014 26% 18% 17% 18% 16% 16% 15% 7% 7% 8% 8% 9% 8% 8% 5% 5% 5% 5% 5% 5% 4% 5% 2% 2% 3% 4% 3% 2% $25.71/57% $41.58/68% $50.65/68% $46.16/66% $50.89/66% $54.31/68% $58.51/71% Lease Operating Expense Production Taxes G&A Exploration Expense EBITDA

Appendix

Reconciliation of Net Cash Provided by Operating Activities to Discretionary Cash Flow (1) Discretionary cash flow is a non-GAAP measure.  Discretionary cash flow is presented because management believes it provides useful information to investors for analysis of the Company’s ability to internally fund acquisitions, exploration and development.  Discretionary cash flow should not be considered in isolation or as a substitute for net income, income from operations, net cash provided by operating activities or other income, cash flow or liquidity measures under U.S. GAAP and may not be comparable to other similarly titled measures of other companies. Discretionary Cash Flow (1) ($ in Thousands) 18 Energy + Technology = Growth Three Months Ended Six Months Ended June 30, June 30, 2014 2013 2014 2013 Net cash provided by operating activities ………… $ 567,769 $ 442,617 $ 891,666 $ 740,231 Exploration …………………………………………………. 13,466 24,343 37,588 43,209 Exploratory dry hole costs …………………………… (70) (11,628) (3,622) (11,628) Changes in working capital ………………………….. (24,978) (14,191) 112,516 70,668 Preferred stock dividends paid ……………………….. - (269) - (538) Discretionary cash flow      ...…………………………. (1) . $ 556,187 $ 440,872 $ 1,038,148 $ 841,942

Reconciliation of Net Cash Provided by Operating Activities to Cash Flow Per Diluted Share Cash Flow Per Diluted Share ($ in Thousands) 19 Cash Flow Per Share: Year Ended December 31, 2009 2010 2011 2012 2013 Net cash provided by operating activities......................... $   453,824 $     997,289 $  1,192,083 $  1,401,215 $  1,744,745 Weighted average diluted shares outstanding (1) .................. 100,088 107,846 118,668 119,028 119,588 Cash flow per share......................................................... $          4.53 $            9.25 $          10.05 $          11.77 $          14.59 (1) Energy + Technology = Growth All share and per share amounts have been retroactively restated for the 2009 and 2010 periods to reflect Whiting’s two –for-one stock split in February 2011.

Reconciliation of Net Income to EBITDAX EBITDAX ($ in Thousands) 20 EBITDAX Reconciliation: Year Ended December 31, 2009 2010 2011 2012 2013 Net Income (Loss)…………………………………………. $  (106,882) $     336,653 $     491,628 $     414,099 $     366,003 Amortization of Deferred  Gain.……………………. (16,596) (15,613) (13,937) (29,458) (31,737) Gain on Sale of Properties......………………………. (5,947) (1,388) (16,313) (3,423) (128,648) Interest Income…………………………………………….. (208) (343) (208) (283) (1,134) Depreciation, Depletion & Amortization………. 394,792 393,897 468,203 684,724 891,516 Exploration……………………………………………………. 46,875 32,846 45,861 59,117 94,755 Impairment…………………………………………………... 26,139 26,525 38,783 107,855 358,455 Stock Compensation……………………………………… 7,650 8,871 13,509 18,190 22,436 Interest Expense............................................... 64,608 59,078 62,516 75,210 112,936 Change in LT PPP.............................................. 3,267 12,091 (865) 13,824 (6,980) Noncash (Gain) Loss on MTM Derivatives........ 218,255 (40,736) (63,093) (115,733) (20,830) Income Taxes (Benefit)..................................... (55,953) 204,790 288,691 247,912 205,868 EBITDAX Total.................................... $   576,000 $  1,016,671 $  1,314,775 $  1,472,034 $  1,862,640 Energy + Technology = Growth

Reconciliation of Long-term Debt to Net Debt Net Debt ($ in Thousands) 21 Year Ended December 31, 2009 2010 2011 2012 2013 Long-term Debt......... $779,585 $800,000 $1,380,000 $1,800,000 $2,653,834 Less Cash................... 11,960 18,952 15,811 44,800 699,460 Net Debt.................... $767,625 $781,048 $1,364,189 $1,755,200 $1,954,374 Energy + Technology = Growth

22 Energy + Technology = Growth Important Additional Information and Where to Find It This communication does not constitute an offer to sell or the solicitation of an offer to buy any securities or a solicitation of a vote or proxy. The proposed Acquisition anticipates that the Whiting shares to be issued pursuant to the Acquisition will be exempt from registration under the United States Securities Act of 1933, as amended (the "Securities Act"), pursuant to Section 3(a)(10) of the Securities Act. Consequently, the Whiting shares will not be registered under the Securities Act or any state securities laws. In connection with the proposed Acquisition,  Whiting and Kodiak intend to file relevant materials with the SEC and other governmental or regulatory authorities, including a joint proxy statement and circular. INVESTORS ARE URGED TO READ THE JOINT PROXY STATEMENT AND CIRCULAR AND ANY OTHER RELEVANT MATERIALS WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT WHITING, KODIAK AND THE PROPOSED ACQUISITION. The joint proxy statement and circular and certain other relevant materials (when they become available) and other documents filed by  Whiting or Kodiak with the SEC may be obtained free of charge at the SEC’s website at http://www.sec.gov. In addition, investors may obtain copies of these documents (when they become available) free of charge by written request to Whiting Investor Relations, 1700 Broadway, Suite 2300, Denver, CO 80290-2300 or calling (303) 390-4051 or by written request to Kodiak Investor Relations, 1625 Broadway, Suite 250, Denver, CO 80202-4765 or calling (303) 592-8030. Participants in the Solicitation Whiting, Kodiak and their respective executive officers and directors may be deemed to be participants in the solicitation of proxies in connection with the proposed Acquisition. Information about the executive officers and directors of Whiting and the number of shares of Whiting’s common stock beneficially owned by such persons is set forth in the proxy statement for Whiting’s 2014 Annual Meeting of Stockholders which was filed with the SEC on March 23, 2014, and Whiting’s Annual Report on Form 10-K for the period ended December 31, 2013. Information about the executive officers and directors of Kodiak and the number of Kodiak’s ordinary shares beneficially owned by such persons is set forth in the proxy statement for Kodiak’s 2014 Annual Meeting of Shareholders which was filed with the SEC on May 9, 2014, and Kodiak’s Annual Report on Form 10-K for the period ended December 31, 2013. Investors may obtain additional information regarding the direct and indirect interests of Whiting, Kodiak and their respective executive officers and directors in the Acquisition by reading the joint proxy statement and circular regarding the Acquisition when it becomes available.