Whiting Petroleum Corporation Evolution of Whiting's Bakken / Three Forks Development Program March 17, 2017 1
Forward-Looking Statements and Non-GAAP Measures This presentation contains statements that Whiting Petroleum Corporation ( Whiting ) believes to be forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than historical facts, including, without limitation, statements regarding the expected future reserves, production, future financial position, business strategy, projected revenues, earnings, costs, capital expenditures and debt levels of Whiting, 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: declines in, or extended periods of low, oil, NGL or natural gas prices; our level of success in exploration, development and production activities; risks related to our level of indebtedness, ability to comply with debt covenants and periodic redeterminations of the borrowing base under our credit agreement; impacts to financial statements as a result of impairment write-downs; our ability to successfully complete asset dispositions and the risks related thereto; revisions to reserve estimates as a result of changes in commodity prices, regulation and other factors; adverse weather conditions that may negatively impact development or production activities; the timing of our exploration and development expenditures; inaccuracies of our reserve estimates or our assumptions underlying them; risks relating to any unforeseen liabilities of ours; our ability to generate sufficient cash flows from operations to meet the internally funded portion of our capital expenditures budget; our ability to obtain external capital to finance exploration and development operations; federal and state initiatives relating to the regulation of hydraulic fracturing and air emissions; unforeseen underperformance of or liabilities associated with acquired properties; the impacts of hedging on our results of operations; failure of our properties to yield oil or gas in commercially viable quantities; availability of, and risks associated with, transport of oil and gas; our ability to drill producing wells on undeveloped acreage prior to its lease expiration; shortages of or delays in obtaining qualified personnel or equipment, including drilling rigs and completion services; uninsured or underinsured losses resulting from our oil and gas operations; our inability to access oil and gas markets due to market conditions or operational impediments; the impact and costs of compliance with laws and regulations governing our oil and gas operations; our ability to replace our oil and natural gas reserves; any loss of our senior management or technical personnel; competition in the oil and gas industry; the potential impact of changes in laws, including tax reform, that could have a negative effect on the oil and gas industry; cyber security attacks or failures of our telecommunication systems; and other risks described under the caption Risk Factors in our Quarterly Report on Form 10-Q for the period ended September 30, 2016 and Annual Report on Form 10-K for the period ended December 31, 2016. We assume no obligation, and disclaim any duty, to update the forward-looking statements in this news release. 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 (Loss) and Discretionary Cash Flow, which are non-gaap measures that Whiting 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. 2
Evolution of Whiting's Bakken/Three Forks Development Program Whiting s Focus on Bakken Program Advances in Completion Design Optimizing Recovery Efficiency Improvements in Well Performance 3
A Focused Company HEADQUARTERS Denver, Colorado Williston Basin Bakken / Three Forks 108,850 BOE/d (Q4 2016) Redtail Niobrara A, B, C & Codell/Ft Hays 9,210 BOE/d (Q4 2016) 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 Mountains region of the United States. The Company s largest projects are in the Bakken and Three Forks plays in North Dakota and Montana and the Redtail Niobrara play in northeast Colorado. The Company trades publicly under the symbol WLL on the New York Stock Exchange. Q4 2016 Net Production 118,890 BOE/d 8% 1% 91% Major Asset Areas Williston Basin Redtail Other 4
2017 Capital Budget 96% Allocated to Development that Drives Growth Non Op $60MM Exploration $24MM Land $10MM Facilities $6MM Redtail $420MM (1) Williston Basin $580MM (1) Includes $324 million for DUC completions. Williston Basin Redtail Non Op Exploration Land Facilities 5
Leading Rockies Oil Producer (2014-2015) With more than a thousand companies reporting sales in the Rocky Mountain region during 2015, Whiting Oil and Gas (Whiting) was again the top crude producer. Primarily the result of the firm s horizontal activities in both the Williston and D-J basins, Whiting extracted 60,975,339 bo last year, up 9 percent or 5.1 mmbo compare to 2014. Approximately 85 percent of Whiting s recovery came from North Dakota s BRS. May 20, 2016 6
Williston Basin Development Program Large Acreage Position in the Core of the Play ACREAGE 735,968 gross (443,839 net) 99% of North Dakota acreage held by production. MULTIPLE TARGETS Bakken Three Forks Control the sweet-spots of the Central, Eastern and Southern Williston Basin. DEVELOPMENT PLAN 1,280-acre spacing units Targeting 900 to 1,500 MBOE EUR wells in 2017. 5,334 potential gross drilling locations as of December 31, 2016. COMPLETED WELL COST Horizontal: $7.0 $7.6 MM (1) WLL Acreage (1) Applies to 8-10mm pound completions and includes approximately $800,000 in facilities-related costs (centralized tank battery, pad construction and lift system). 7
Custom Development & Completion Design Basinwide footprint with 7 technical teams working Williston Basin sweet spots Development drilling and completion design customized to unique geologic and logistical conditions Prolific development program allows for rapid deployment, testing and selective integration of new technologies Bakken Three Forks WLL DSUs Pronghorn Prospect, Stark County, ND In-house core lab streamlines WLL petrophysics support Focus on technical and excellence and economic results 2015-2016 Drilling Activity 8
Evolution of Whiting Completion Design - Proppant Volume key to Doubling Well Performance* *Whiting Wells drilled since June, 2014 9
Evolution of Whiting Completion Design Polar Prospect Area 10
Evolution of Whiting DSU Development 2010 2012 2015 2016 Wells per DSU 4 8 6 6 Proppant (MM#) 2.2 3.5 5.4 7.5 Stages 24 30 34 35 Effective Entry Points 30 35 83 113 Proppant / Entry Point (M#) 74 100 65 66 Fracture Half-length (ft) 62 83 54 55 90-Day Average Rate (BOE) 655 468 748 1057 1280 Acre Drilling-& Spacing Unit Drainage Insufficient Insufficient Good Best Interferrence Minimal High Minimal Minor 11
Evolution of Completion Design Proppant Distribution - Polar Prospect Area 12
Q4 Williston Basin Large Volume Completions Deliver Outstanding Results (1) 180,000 160,000 140,000 120,000 100,000 BOE 80,000 60,000 40,000 20,000 20 40 60 80 100 120 140 Days Average Cumulative Production 1500 MBOE 900 MBOE (1) Fourth quarter average for 10+mm pound wells includes four wells completed in McKenzie County, North Dakota. 13
Williston Basin Drill Times (1) 36% Decline from Beginning of 2014 25.0 21.6 Technology driving times down Multiple wells being drilled off pads Advancements in drill bit design(heat resistance) Mud motor design(more torque) 20.0 19.6 18.4 17.7 18.2 Days 15.0 15.9 15.5 14.6 13.1 12.2 13.1 13.9 10.0 5.0 0.0 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2014 2015 2016 (1) Represents spud to rig release drill times or the time it takes a rig to drill a well and the rig to move off location. 14
Top Performer in the Bakken Initial 90-Day Average Rate (BOEPD) for Wells Completed between December 2015 and November 2016 (1) BOEPD 1,400 1,200 1,000 800 600 WLL 1,203 997 816 692 680 572 567 400 328 200 WLL Peer A Peer B Peer C 17 18 22 10 33 14 34 27 Wells (1) Data for all wells completed in the Bakken formation between December 2015 and November 2016 that had at least 90 days of production for operators with more than 10 wells. Source: North Dakota Industrial Commission (NDIC) Peer group includes Oasis Petroleum, EOG Resources, QEP Resources, Hess Corp., Burlington Resources, XTO Energy, SM Energy. Peer D Peer E Peer F Peer G 15