Corporate Update November 2018
Forward Looking Statements and Cautionary Statements Forward-Looking Statements This presentation contains forward-looking statements within the meaning of the federal securities laws. All statements, other than statements of historical facts, included in this presentation that address activities, events or developments that Extraction Oil and Gas, Inc. and its subsidiaries (collectively, the “Company” or “Extraction”) expects, believes or anticipates will or may occur in the future are forward-looking statements. The words “believe,” “expect,” “anticipate,” “plan,” “intend,” “estimate,” “project,” “foresee,” “should,” “would,” “could,” or other similar expressions are intended to identify forward-looking statements. However, the absence of these words does not mean that the statements are not forward-looking. Without limiting the generality of the foregoing, forward-looking statements contained in this presentation specifically include estimates of the Company’s reserves, expectations of plans, strategies, objectives and anticipated financial and operating results of the Company, including as to the Company’s drilling program, production, hedging activities, capital expenditure levels and other guidance included in this presentation. These statements are based on certain assumptions made by the Company based on management’s experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. The Company cautions you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the exploration for and development, production, gathering and sale of natural gas and oil. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating natural gas and oil reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, and the other risks described in our filings with the Securities Exchange Commission (“SEC”), including in our Annual Report on Form 10-K for 2017 filed on February 27, 2018 and in our Quarterly Reports on Form 10-Q filed on May 8, 2018, August 7, 2018 and November 6, 2018. Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. Industry and Market Data This presentation has been prepared by the Company and includes market data and other statistical information from sources believed by it to be reliable, including independent industry publications, government publications or other published independent sources. Some data are also based on the Company’s good faith estimates, which are derived from its review of internal sources as well as the independent sources described above. Although the Company believes these sources are reliable, it has not independently verified the information and cannot guarantee its accuracy and completeness. Reconciliation of Non-GAAP Financial Measures This presentation includes financial measures that are not in accordance with generally accepted accounting principles (“GAAP”), including Adjusted EBITDAX and Adjusted EBITDAX, Unhedged. While management believes that such measures are useful for investors, they should not be used as a replacement for financial measures that are in accordance with GAAP. For a reconciliation of Adjusted EBITDAX and Adjusted EBITDAX, Unhedged to the nearest comparable measures in accordance with GAAP, please see the Appendix. Oil & Gas Reserves The Company’s proved reserves are those quantities of oil and gas, 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, and under existing economic conditions (using the trailing 12-month average first-day-of-the-month prices), 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, regardless of whether deterministic or probabilistic methods are used for the estimation. In this presentation, proved reserves attributable to the Company at December 31, 2017 are estimated utilizing SEC reserve recognition standards and pricing assumptions based on the trailing 12-month average first-day-of-the-month prices of $51.34/Bbl for oil and $2.98/MMBtu for natural gas. These prices were adjusted by lease for quality, transportation fees, geographical differentials, marketing bonuses or deductions and other factors affecting the price received at the wellhead. The Company’s estimate of its total proved reserves is based on reports prepared by Ryder Scott Company, L.P., independent petroleum engineers. The Company may use the terms “EUR” and “upside potential” to describe estimates of potentially recoverable hydrocarbons that the SEC rules prohibit from being included in filings with the SEC. These are based on internal estimates of hydrocarbon quantities that may be potentially discovered through exploratory drilling or recovered with additional drilling or recovery techniques. These quantities may not constitute “reserves” within the meaning of the Society of Petroleum Engineer’s Petroleum Resource Management System or SEC rules. These estimates are inherently more speculative than proved reserves estimates. Actual locations drilled and quantities that may be ultimately recovered from the Company’s interests could differ substantially. There is no commitment by the Company to drill all of the drilling locations, which have been attributed to these quantities. Factors affecting ultimate recovery include the scope of the Company’s ongoing drilling program, which will be directly affected by the availability of capital, drilling and production costs, availability of drilling services and equipment, drilling results, lease expirations, transportation constraints, regulatory approvals, actual drilling results, including geological and mechanical factors affecting recovery rates, and other factors. Estimates may change significantly as development of the Company’s oil and natural gas assets provide additional data. The Company’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. 2
Capital Structure and Market Summary Capital Structure Market Capitalization (As of November 5, 2018) $1.5 billion Series A Preferred $185 million Net Debt $1.3 billion Enterprise Value $2.9 billion Net Debt / EBITDAX (1) 2.1x Market Summary Trading Price (As of November 5, 2018) $8.72 Ticker Symbol (NASDAQ) XOG Common Shares Outstanding 175.9 million Convertible Preferred Shares Outstanding (as converted basis) 11.5 million Average Daily Trading Volume (shares) (2) 2.1 million Management Ownership ~7% (1) Last 6 months annualized as of September 30, 2018. See p. 25 for detail and reconciliation. Covenant under credit agreement calculated using trailing 12 months EBITDAX. (2) Represents year-to-date as of November 5, 2018. 3
Extraction Company Overview DJ Basin Net Acreage DJ Basin-Focused Position of Scale • ~325,000 net acres with ~170,000 in Core DJ Basin CO Laramie Kimball • Contiguous acreage blocks allow for longer laterals • Limited vertical well drainage Extensive Low-Risk, High Return Inventory • 5,800+ Gross / 3,700+ total net locations (1) • ~20 yr Inventory @ 300 wells/yr pace (1) Industry Leading Results Weld • PUD Development Cost ~ $8.72/Boe with top 50% of Larimer locations ~$6.22/Boe (2) • Operating Margin ~75% (3) Significant Financial Flexibility and Liquidity Morgan • Current borrowing base of $800MM (4) • Target long-term Net Debt/Adjusted EBITDAX of ~1.5x • Protect cash flow through hedge program Boulder Top Operators Extraction Experienced and Aligned Management Team SRC Energy • ~7% Management ownership Pacific Energy Broomfield PDC Energy • Operated D&C of 600+ Wattenberg Hz wells Adams Bonanza Creek HighPoint Q3-18 Production Update Whiting Denver Jefferson Noble • Q3-18 production of 75.7 Mboe/d Arapahoe Anadarko EOG • Turned 71 gross (61 net) wells to sales during Q3 with ConocoPhillips Elbert average lateral length of ~9,600’ Douglas (1) Represents locations on a one-mile equivalent basis as of 12/31/17. Does not include locations in the Northern Extension. (2) Calculated as future development costs per proved undeveloped reserves. Development costs/boe are as of 12/31/17. (3) Calculated as unhedged realized price / Boe less LOE, production taxes, transportation and marketing, and cash G&A / Boe. Quarter ended 9/30/2018. 4 (4) Current elected commitment size is $650 million.
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