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  Economics : Type Curve

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Samson ManResources II 2017 was a busy Camp Continues year to Outperform Expectations Daily Gross Gas Rate Key Points Man Camp 23V 9,000 Man Camp 24V 4-well Man Camp pad has continued to 8,000 Man Camp 2V Man Camp 3V outperform, with slightly higher performance 7,000 Man Camp Average Type Curve relative to type curve 6,000 Gas Rate (Mcf/d) 5,000 Performance Summary 4,000 Day 60 Rate Day 87 Rate 3,000 (Mcf/d) (Mcf/d)(1) 2,000 Type Curve 4,019 3,427 1,000 0 Man Camp Avg. 6,021 5,925 30 60 90 120 150 Days Online Delta 50% 56% Cumulative Gross Gas Stronger single well IRR associated with the 700 Core type curve 600 125 Core locations identified with similar 500 Cumulative Gas (MMcf) characteristics to the Man Camp pad (spacing and 400 reservoir characteristics) 300 Man Camp 2V has a fish in the wellbore only half Man Camp 23V of perforations open to flow 200 Man Camp 24V Man Camp 2V Man Camp 24V is also partially constrained due to a 100 Man Camp 3V Man Camp Average fish in the wellbore 0 Type Curve 30 60 90 120 150 Days Online (1) Shortest lived Man Camp well has 87 days of gas production (2) D&C cost of 3.8 MM. 25
Samson Resources II LLC
August 2019

NIOBRARA POSITIONED FOR SUCCESS Premier Niobrara position in the PRB Oil, gas and condensate provides Teapot flexibility Parkman E, A, B/C & Deep 580 undrilled locations Assumes 1,100' 1,320' spacing Surrey Targeted development through 2020 Sussex EUR: 880 mboe ROR: 45% (1) Niobrara Outperforming all U.S. Niobrara horizontal wells to date Turner Frontier Production Mix Mowry (2) CHK Barton Test Oil breakeven price Peak Rate of 1,600+ boe/d (85% Oil) 230 mbo 1-Year Cum. 34% 40 54% 12% DJ Basin, Green River Basin, North Park Basin, Piceance Basin, Oil NGL Natural Gas Powder River Basin and Williston Basin (1) Assumes 3 gas and 60 oil (2) PV10 positive breakeven price assuming 3 gas price (3) IHS data 2016 ANALYST DAY POWDER RIVER BASIN 11
Chesapeake Energy Corp
October 2016

North - Greater Green River Basin Early Horizontal Wells Creating Significant Value boed Luman 10-40H Production 10,000 2015 1st horizontal in eight years 1,000 Eight horizontal wells since September 2015 100 Actual Production Typecurve 10 Horizontal wells delivering up to 45% IRR* 30 Day Average - 1,473 BOED (63% Liquid) 1 0 10 20 30 40 50 60 70 80 Aggressively building drilling inventory Days boed Latham Draw 3-40H Production First multilateral to spud June 2016 10,000 Multilateral development economics projecting 1,000 80% IRR and 9.7/boe development cost at 100 14m well cost in Tier 1 locations Actual Production Typecurve 10 30 Day Average - 2,660 BOED (23% Liquid) 1 0 20 40 60 80 100 120 140 160 180 * At 10m well cost Days Economics are post tax, include capitalized overhead and were run at 3HH and 55WTI 7
BP Plc
June 2016
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