Economics : Type Curve

Showing 3 Results


First SandRidge Niobrara C Bench Lateral Hebron 4-18H cumulative oil production exceeds type curve by 32% 539 Boepd (92% oil) 30-Day IP DAILY OIL RATE CUMULATIVE OIL Jet Pump Installed 13
Sandridge Energy, Inc.
May 2017

Delaware Basin Resilient Economics with Untapped Upside Base Case Economic Summary with Development Cost Structure Type Well Profile Comparison Eastern Wolfcamp A Eastern Wolfcamp B Central Wolfcamp A/B Western Wolfcamp A (XRL) Type Well Eastern Wolfcamp A SRL CWC EUR F&D Cost(1) IRR(2) PV10(2) ROI Development; MM MBoe Per Boe % MM Undiscounted 6.0 1,000 8.67 60% 5.9 3.2 Eastern Wolfcamp B SRL 6.0 750 11.62 35% 3.6 2.6 Central 6.0 1,050 7.89 34% 3.5 2.6 Wolfcamp A/B SRL 9.0 1,200 10.45 30% 4.8 2.5 Western Wolfcamp A XRL 5/5/2017 (1) F&D defined as CWC/net reserves per well; (2) Base case pricing assumes 3.14/Mcf NYMEX gas in 2017 and 3.05/Mcf flat in 20182020 and NYMEX oil of 53, 55, 60, 65/bbl 20172020 13
PDC Energy, Inc.
May 2017

Niobrara 1.5-mile Average Type Curve and Economics Standard Completions Oil Type Curve and Operated Well Production(1) As of December 31, 2016 125 operated Niobrara wells with 30 days of production history; average lateral MBbl length of 6,001 Lateral Length 1.5 mile 120 Total Well Costs 3.96 MM Cum. Average Well Average 30-Day IPs of 719 Boe/d(1) Outperformance EUR (MBoe)(2) 575 (20 Months): 8% 106 Boe/d per 1,000 of lateral % Liquids 69% Average 180-day cumulative production of 95 MBoe(1) 100 LOE / Month per Well 9,925 Oil Mix: 3-stream 2-stream IRR / NPV (3) 50% / 2,916 30-day 62% 69% 80 180-day 56% 64% Life of Well 43% 51% 60 Type curve implies short payback period of 25 months at 12/31/16 strip pricing 40 IRR Sensitivity(3) 100% Average Oil 80% 20 60% 84% Oil Type Curve 40% 59% 37% 20% 19% 0 0% 0 5 150 10 300 15 450 20 600 40 50 60 70 Months NYMEX WTI (1) Production data normalized to 1.5 mile, 6,800 feet, equivalents and adjusted for operational downtime. Reflects wellhead data. (2) Average type curve presented per Management analysis. Average type curve EUR reflects 3-stream economic EUR at 12/31/16 strip pricing. (3) Gas held flat at 3.08/MMbtu (5-year average HHub as of 12/31/16) and subject to a 1.1x BTU adjustment, a (20%) POP differential, and a (0.16)/Mcf basin differential; NGLs assumed at 30% of NYMEX and subject to (20%) POP differential; Oil subject to (7) differential at all price levels; Assumed 100% WI and 80% NRI; NPV values discounted at 10%. 14
Extraction Oil and Gas
April 2017

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