Economics : Rates of Return/ IRR

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STACK Core - Provides High ROR Oil/Wet Gas with Dry Gas Optionality IP-30 Gas Lateral Oil Lease Operator Spud Date MMcfe/d % Length Condensate 12 1 Anderson Half Continental 2/2016 17.1 99% 9,676 2 Edith Mae Continental 6/2016 23.6 99% 9,743 Dry Gas 3 Abbott Com Cimarex 8/2017 Flowing Back 10,385 4 Hicks BIA Marathon 7/2017 14.8 99% 9,652 13 10 5 Reece Jane Continental 2/2017 16.6 100% 9,898 9 6 Wyatt Continental 8/2016 16.5 100% 8,805 8 2 1 7 Eagle Continental 9/2017 WOC 9,679 7 8 Gripe FIU Continental 8/2017 16.0 100% 10,175 4 IP-30 Liquids Lateral 5 Lease Operator Spud Date Boe/d % Length 6 3 14 9 Jordan Devon 4/2017 1,636 51% 10,050 10 ML Devon 9/2016 1,766 48% 4,676 11 Carpenter Cimarex 10/2017 WOC 4,786 15 12 Privott Devon 10/2016 4,308 57% 10,112 11 Units Acreage 13 Lorene Continental 7/2017 5,483 30% 10,186 Meramec 14 Geronimo 89 Energy 6/2017 895 58% 4,797 Woodford 15 Rafter J Ranch Marathon 7/2017 1,017 27% 4,111 Denotes Unit working interest Oil Condensate Dry Gas* Type Curve Window Window Window Single Well Economics 250% IP - 30 (Boe/d, Mcfe/d*) 1,706 1,773 15,415* 200% ROR 108% 68% 15% 150% IRR % EUR (Mboe/Bcfe*) 1,939 1,958 18.9* 100% % Liquids/Gas 65% 58% 99% 50% Lateral Length 10,000 10,000 10,000 0% Well Cost (mm) 10.7 10.7 10.9 60 / 2.50 5/1 Nymex 70 / 3.00 80 / 3.50 1 5/1/2018 Strip Price Deck with 1st Production Starting 5/1/2018. Stack Condensate Stack Dry Gas Stack Oil See Q2 2018 Economic Prices in Appendix (also available at www.unitcorp.com/investor/reports/html) 12
Unit Corp.
June 2018

Company Highlights Premier, contiguous Approximately 119,000 net acres mostly in the core of Kingfisher, Canadian and Garfield counties acreage position in the Operator of approximately 76% of our acreage, with an average operated WI of approximately 68% black oil, normal pressure STACK acreage complemented by PDP production from STACK and legacy assets that provide window of the STACK stable cash flow to support STACK development More than 1,000 MMBoe resource base, with proved reserves of 76 MMBoe and proved PV-10 of Large resource base with approximately 625mm(1) as of 12/31/17 high-return inventory Decades of STACK operated drilling locations at the current drilling pace across the Meramec, across different pay Osage and Woodford formations zones Drilling opportunities provide 45% - 100% IRRs(1) Top-quartile D&C well costs in the STACK Highly efficient, low-cost Replaced 604% of 2017 STACK production at low STACK F&D cost of 7.26/Boe STACK assets STACK cash margins of 27.27/Boe in Q1 2018 Pro-forma for the 300mm senior unsecured notes offering, Q1 2018 net leverage of 1.9x (based on LQA Adjusted EBITDA of 118mm) Conservative financial Pro-forma for the 300mm senior unsecured notes offering, Q1 2018 liquidity of 382mm policy and low leverage Active hedge program with 80% of 2018E oil production hedged Ability to fund capital expenditures and near-term cash flow outspend while maintaining low leverage and ample liquidity Long-tenured, Senior management team averaging more than 25 years of O&G industry experience experienced leadership Experienced independent board of directors comprised of current and former C-level leaders team averaging more than 25 years of O&G experience (1) At NYMEX prices from May 17, 2018; five-year average prices 61.49 and 2.74 4
Chaparral Energy
June 2018

2018 ACTIVITY ECONOMIC FOCUS Plan to focus Utica Shale activity in the dry gas windows and SCOOP activity in the wet gas window of the play Allocation of capital split between two top-tier basins with dry gas and liquids inventory SCOOP SINGLE WELL ECONOMICS(1,2) UTICA SINGLE WELL ECONOMICS(1,2) 120% 120% 107% 100% 100% Current 87% 86% Drilling Plan 80% 80% 79% 69% 71% Current 74% 71% 68% Drilling Plan IRRs % 57% 59% 59% 60% 60% 53% 57% 55% 47% 52% 44% 42% 40% 40% 37% 40% 40% 35% 40% 37% 27% 27% 29% 29% 33% 31% 26% 20% 24% 20% 25% 20% 24% 19% 24% 15% 19% 10% 16% 14% 7% 0% 0% Gas 2.50 / Oil 50.00 Gas 2.75 / Oil 55.00 Gas 3.00 / Oil 60.00 Gas 3.25 / Oil 65.00 Gas 2.50 / Oil 50.00 Gas 2.75 / Oil 55.00 Gas 3.00 / Oil 60.00 Gas 3.25 / Oil 65.00 Woodford Dry Gas Woodford Wet Gas Woodford Condensate Condensate West Condensate East Wet Gas Springer Gas / Condensate Springer Oil Dry Gas West Dry Gas Central Dry Gas East Woodford Woodford Woodford Springer Gas Springer Condensate Condensate Wet Dry Gas Dry Gas Dry Gas Dry Gas Wet Gas Condensate Condensate Oil West East Gas West Central East Gross Undeveloped Locations 444 642 350 238 300 Gross Undeveloped Locations(3) 129 73 114 181 441 259 Net Undeveloped Locations 84 230 30 82 64 Net Undeveloped Locations 97 54 86 135 331 194 1. Assumes ethane rejection. 2. Well economics are adjusted for transport fees and regional price differentials. 3. Assumes net undeveloped locations grossed up from 75% working interest. WWW.GULFPORTENERGY.COM 8
Gulfport Energy Corp.
June 2018

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