Economics : Rates of Return/ IRR

Showing 3 Results


2017 Activity Economic Focus During 2017, 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) 140% 140% 130% 122% 129% 120% 120% 125% 120% 100% 2017 109% 100% 2017 91% Drilling Plan 85% Drilling Plan 89% IRRs 80% 80% 86% 78% 65% 77% 57% 57% 60% 60% 52% 55% 48% 46% 53% 52% 35% 49% 40% 36% 40% 29% 42% 28% 43% 27% 32% 32% 26% 15% 23% 20% 20% 12% 26% 24% 11% 19% 13% 10% 11% 0% 0% Gas 2.50 / Oil 42.50 Gas 3.00 / Oil 50.00 Gas 3.50 / Oil 58.00 Gas 4.00 / Oil 67.00 Gas 2.50 / Oil 42.50 Gas 3.00 / Oil 50.00 Gas 3.50 / Oil 58.00 Gas 4.00 / Oil 67.00 Woodford Dry Gas Woodford Wet Gas Woodford Condensate Condensate West Condensate East Wet Gas Springer Oil Springer Gas / Condensate 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 402 528 249 215 354 Gross Undeveloped Locations(3) 139 83 130 191 456 255 Net Undeveloped Locations 65 182 33 72 70 Net Undeveloped Locations 104 62 97 143 342 191 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. 7
Gulfport Energy Corp.
May 2017

Warrior North Economics(1) 2,000 1,200 YE15SEC YE16SEC Upside Case 55% Ethane Recovery(2) Curve Curve 2017 1,800 1,000 All-in Well Cost 5.5 million 6.2 million 6.2 million 1,600 Lateral Length 5,000 ft 6,500 ft 6,500 ft 1,400 800 Cum Gross Prod (MBoe) EUR (MMBOE) 1.2 1.6 1.9 Gross Rate (Boe/d) 1,200 F&D Cost (/BOE) 4.55 3.89 3.32 1,000 600 3.00 NYMEX 800 32% 47% 59% Oil Price: 2017+: 55 400 600 3.00 NYMEX 23% 35% 46% 400 Oil Price: 2017+: 50 200 IRR (3,4,5) 200 3.25 NYMEX 35% 50% 62% Oil Price: 2017+: 55 0 0 0 10 20 30 40 50 60 Production Month Strip Pricing 32% 47% 59% YE15 SEC Curve YE16 SEC Curve Upside Case Avg. 30-day sales rate (MBOE/d) 1.4 1.8 1.3 1.7 1.1 1.5 (1) See note on Hydrocarbon Volumes and disclaimers at beginning of presentation. (2) Economics reflect 55% ethane recovery. (3) Historical price differentials applied to Condensate. Futures differentials applied for gas production for all scenarios. (4) C2 and C3+ NGL prices indexed at 17% and 54% of oil, respectively during the first year strip. (5) Strip Pricing as of 02.13.2017 Oil: 2017: 54.4, 2018: 55.17, 2019: 54.94, 2020: 54.89, 2021: 55.05// Gas: 2017: 3.2, 2018: 3.06, 2019: 2.87, 2020: 2.85, 2021: 2.85 23
Rex Energy Corp
May 2017

Southwest Pennsylvania Modeling Inputs and Economics Reserves Detail Assumptions SWPA Marcellus Type Curve (2.7 Bcfe/1000') Gross EUR (Bcfe) 22.6 IP (MMcfe/d) 19.0 600,000 BTU 1,130 Decline 69% BTAX ROR % (3) B-factor 1.65 500,000 Gas Production (Mcf/month) Interest / Net Locations EUR/1000 (Bcfe) 2.7 Realized Price 8,500' WI / NRI (%) 100% / 89% Lateral Length 8,500 400,000 2.00 39% (1) Wells Per Pad 6 Net Locations 572 2.50 71% Wells Online (3/31/17) 196 Capital ( millions) 7.1 300,000 3.00 109% Avg. PDP Acres/Well 104 Fixed Cost (/mo./well) 730 200,000 LOE (/Mcfe) 0.12 Gathering (/Mcfe) 0.48 100,000 8500' LL 0 0 12 24 36 48 Months After TIL Reserves Detail Assumptions Gross EUR (Bcf) 21.4 IP (MMcf/d) 23.1 SWPA Utica Type Curve (3.1 Bcf/1000') BTU 1,010 Decline 67% 700,000 B-factor 1.20 BTAX ROR % (3) Gas Production (Mcf/month) 600,000 Interest / Net Locations EUR/1000 (Bcf) 3.1 Realized Price 7,000' WI / NRI (%) 100% / 89% Lateral Length 7,000 500,000 2.00 19% (2) Net Locations 855 Wells Per Pad 5 400,000 2.50 34% Wells Online (3/31/17) 1 Capital ( millions) 13.2 300,000 3.00 52% Fixed Cost (/mo./well) 500 LOE (/Mcf) 0.05 200,000 Gathering (/Mcf) 0.23 100,000 7000' LL 0 (1) Assuming 8,500 ft lateral 750 ft inter-lateral spacing, total undeveloped net locations in region 0 12 24 36 48 (2) Assuming 7,000 ft lateral 1,100 ft inter-lateral spacing, total undeveloped net locations in region Months After TIL (3) Escalation not applied to gas pricing, capex, and opex Note: NRI excludes potential partial amendments to existing leases and adverse or third party acreage within drilling units. 29
Consol Energy Inc.
May 2017

   Want More Data? SUBSCRIBE
Subscribe and Get immediate Access

Already a subscriber?Log In here