Economics : Type Curve

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Viewfield Bakken Primary Infill Economics Hold Strong Corporate Presentation Bakken Drills (Rate vs. Time) Bakken Drills (Count vs. Time) 140 100% Well Count Percentage Calendar Daily Rate (bbl/d) 120 80% 100 80 60% 60 40% 40 20% 20 0 0% 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 2008-2009 2010-2011 2012-2013 2014-2016 2017 Months Primary Infill 2008 to 2009 2010 to 2011 2012 to 2013 2014 to 2016 75 Infill 100 Infill 350 Waterflood Type Well Economic Indicators Reserves IP NPV10% ROR Payout P/I Type Well Economics (mboe) (bbl/d) (M) (%) (months) (ratio) 50 mbbl 70 105 0.7 51 18 0.5 75 Infill mbbl 111 100 1.4 86 14 1.1 Crescent Point Energy 100 Infill mbbl 146 125 2.1 162 10 1.7 125 mbbl 179 135 3.4 268 8 2.6 150 mbbl 210 135 3.7 267 8 2.8 350 mbbl waterflood 430 125 4.6 158 10 3.6 Effective January 1, 2017 1.3 M D/C/E/T capital, 100% WI, varying CR/FH at 18% split Based on pricing assumption of US 55 WTI 21
Crescent Point Energy Corp.
July 2017

Williston Basin Development Program Large Acreage Position in the Core of the Play ACREAGE 732,819 gross (443,310 net) 99% of North Dakota acreage held by production. MULTIPLE TARGETS Bakken Three Forks Control the sweet-spots of the Central, Eastern and Southern Williston Basin. DEVELOPMENT PLAN 1,280-acre spacing units Targeting 1,000 to 1,500 MBOE EUR wells in 2017. 5,334 potential gross drilling locations as Loomer 44-33-2H of December 31, 2016. 10 MMlb Stimulation Exceeding 1,500 MBOE Type Curve 300,000 COMPLETED WELL COST 250,000 1000 MBOE Horizontal: 7.0 7.6 MM(1) 1500 MBOE 200,000 LOOMER 44-33-2H 150,000 100,000 WLL Acreage 50,000 0 (10) 10 30 50 70 90 110 130 150 (1) Applies to 8-10mm pound completions and includes approximately 800,000 in facilities-related costs (centralized tank battery, pad construction and lift system). NYSE: WLL 4
Whiting Petroleum Corp.
June 2017

Water Cut and Infrastructure Enhances Premier Returns in Eagle Ford Low Cost Access to Fresh Water Enhances Premier Returns WildHorse Eagle Ford Saltwater Disposal Costs Secured dedicated freshwater supply from freshwater ponds and an Low water cut and saltwater disposal costs leads to reduced LOE agreement with the Brazos River Authority Saltwater disposal costs have continued to rise across competing basins Capacity to complete 510 wells per year with no bottlenecks WildHorse Eagle Ford water disposal costs are best in class: D&C water costs are some of the lowest across U.S. shale basins Salt Water Potential to develop fresh water pipeline system to further reduce costs Basin Disposal Costs (/Bbl) (1) across the field WRD Eagle Ford 1.05 Permian 2.00 - 4.00 Dedicated Freshwater Supply Ponds S. Texas Eagle Ford 1.00 - 3.50 Bakken 4.00 - 8.00 Robertson Freshwater Pond Cumulative saltwater disposal costs over the life of well for 91 BOE/ft type curve are 115,000 per well Milam Bbls/d Water Cost Brazos 700 WildHorse Eagle Ford water disposal 70,000 600 cost of 1.05/bbl is significantly lower 60,000 than competing basins 500 50,000 Burleson 400 40,000 300 25% water cut at month 6 30,000 Lee 200 20,000 Washington 100 10,000 0 - 0 20 WRD Month 1 Month 8 Month 15 Month 22 Month 29 Month 36 Miles Fayette APC / KKR Austin Acquisition Bbls/d Water Cumulative Disposal Water Cost 1. Salt Water Disposal cost data per EIA report Trends in U.S. Oil and Natural Gas Upstream Costs, March, 2016 30
WildHorse Resource Development
June 2017

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