Company Presentation March 2018 Forward-Looking Statements This - PowerPoint PPT Presentation

Company Presentation March 2018

Forward-Looking Statements This presentation includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements can be identified by terminology such as “may,” will,” “could,” “should,” “expect,” “plan,” “project,” “forecast,” “intend,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “pursue,” “target,” “outlook,” “continue” the negative of such terms or other comparable terminology. All statements, other than historical facts included in this presentation, that address activities, events or developments that WildHorse Resource Development Corporation (WRD) expects or anticipates will or may occur in the future and such things as WRD’s future capital expenditures (including the amount and nature thereof), business strategy and measures to implement strategy, competitive strengths, goals, expansion and growth of WRD’s business and operations, plans, market conditions, references to future success, references to intentions as to future matters and other such matters are forward-looking statements. All forward looking statements speak only as of the date of this presentation. Although WRD believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Therefore, actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements. WRD cautions you that these forward-looking statements are subject to risks and uncertainties, most of which are difficult to predict and many of which are beyond WRD’s 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; and the timing of development expenditures. Information concerning these and other factors can be found in WRD’s filings with the Securities and Exchange Commission (SEC), including its Forms 10-K, 10-Q and 8-K. Consequently, all of the forward-looking statements made in this presentation are qualified by these cautionary statements and there can be no assurances that the actual results or developments anticipated by WRD will be realized, or even if realized, that they will have the expected consequences to or effects on WRD, its business or operations. WRD has no intention, and disclaims any obligation, to update or revise any forward-looking statements, whether as a result of new information, future results or otherwise. Initial production rates are subject to decline over time and should not be regarded as reflective of sustained production levels. Unless otherwise stated all information presented herein excludes the impact of the North Louisiana divestiture. 2

I. Company Overview 3

Premier E&P Company with Top Tier Returns, Growth and Margins Premier Acreage Position in the Eagle Ford (6) Key Investor Considerations Total Company (6)  TOP TIER RETURNS, GROWTH AND MARGINS Net Acres ~494,000 (2)  78% growth in 2018 total production at guidance midpoint (2) Proved Reserves (MMboe) 454.3 % Liquids 75%  High realizations and low operating costs lead to superior % Oil 62% cash margins PV10 of Proved Reserves ($MM) $3,539 Q4 2017 Production (Mboe/d) 45.9 % Liquids 72%  PROVEN ABILITY TO EXECUTE (3) Second largest Eagle Drilling Locations  Gross 6,179 Outperformance of Gen 3 Eagle Ford wells Ford position in the Net 3,849  Increased the Eagle Ford type curve to an EUR industry of 95 Boe/ft from 91 Boe/ft Eagle Ford North Louisiana  Average of 98 wells, located throughout the Net Acres ~404,000 Net Acres ~90,000 (2) (2) Proved Reserves (MMboe) 385.6 acreage position, are outperforming the 95 Boe Proved Reserves (Bcfe) 412.1 % Liquids 88% % Liquids 2% per foot public Eagle Ford type curve % Oil 73% % Gas 98% PV10 of Proved Reserves ($MM) $3,209 PV10 of Proved Reserves ($MM) $331  20%+ efficiencies in drilling days and cash operating Q4'17 Production (Mboe/d) 36.0 Q4'17 Production (MMcfe/d) 59.3 costs/Boe achieved in 2017 % Liquids 90% % Gas 96% (3) Drilling Locations Drilling Locations Gross 4,785 Gross 1,409  POSITIONED FOR LONG TERM GROWTH Net 3,207 Net 642 (4) (4) Development well IRR 57% Development well IRR 74%  Deep Eagle Ford inventory  3,154 net locations at the 95 Boe/ft type curve (1)  Over 30 years of inventory at current pace Peer Leading Production Growth (5)  Austin Chalk upside potential on ~100,000 net acres 60  Infrastructure in place to support long-term growth  FINANCIAL STRENGTH AND FLEXIBILITY 45  Low leverage profile with no near term maturities MBoe/d 30  Net Debt / Q4’17 Annualized EBITDAX (7) at 1.4x, expected to trend downward 15  Liquidity of $589MM at year end 2017 0 2015 2016 2017 2018E 1. Includes locations outside of CGA’s 3P area. See “Management Locations” in the Appendix section of this presentation for more information. 2. Reserve data based on December 31, 2017 reserve report audited by Cawley, Gillespie & Associates (“CGA”). 3. Includes 71 gross (53 net) Austin Chalk locations. 4. Based on consensus pricing as of 3/1/18: $60.00 / $3.06 for 2018, $60.00 / $3.05 for 2019, $62.00 / $3.13 for 2020, $61.75 / $3.19 for 2021, $57.00 / $3.22 for 2022 and thereafter for WTI and Henry Hub, respectively. 4 5. 2018E based on midpoint of guidance. 6. Includes approximately 90,000 net acres in North Louisiana pending sale to a third party with an expected close date of March 30, 2018. 7. See slide 35 in the appendix for reconciliation of EBITDAX..

2017 Year in Review: Best in Class Execution Production Growth 2017 Highlights Net Production Net Oil Production  WRD delivered best in class execution in 2017 (Mboe/d) (Mbo/d)  Built second largest Eagle Ford position in the industry with 404,000 net acres (1) 45.9  98 Eagle Ford Gen 3 wells online at an average EUR of 99 Boe/ft (2) and 82 Bo/ft (2) 28.2 outperforming the 95 Boe/ft type curve 14.3  Wells located throughout the entire acreage position 5.7  Drilled three successful Austin Chalk wells, creating significant additional upside potential Q4’16 Q4’17 Q4’16 Q4’17  Strengthened balance sheet and liquidity position Leverage & Liquidity ($MM)  Issued $500 million of 6.875% senior unsecured notes Borrowing Base Liquidity  Net Debt / Q4’17 Annualized EBITDAX at 1.4x and expected to trend downward $875  Y-o-Y liquidity increased by $379 million to $589 million $589 $605  Robust and balanced hedge position with commodity price downside protection and upside $450 potential through the use of put options $210 Stock Price Outperformance in 2017 140% YE’16 YE’17 YE’16 YE’17 WRD S&P E&P Index Gen 3 Eagle Ford Wells Online 26% 120% 36% Best E&P Stock Performance of Full Year 2017 (3) Wells Online Eagle Ford Type Curve Incremental Boe/ft 100% 98 Return 95 91 (10%) 80% 76 78 60% 78 76 17 Bo/ft Bo/ft Bo/ft Bo/ft 16 40% YE’16 YE’17 YE’16 YE’17 Jan-17 Mar-17 May-17 Jul-17 Aug-17 Oct-17 Dec-17 1. Includes approximately 17,000 net acres in Lee County, TX acquired on March 1, 2018 2. Eagle Ford wells drilled and completed including refracs as of December 31, 2017, excludes test wells and wells with insufficient production history to estimate an EUR. 3. Based on all E&P companies with an average market capitalization above $200 million in 2017. 5