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  Economics : Type Curve

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EAGLE FORD REVENUE PER INVESTMENT 2018 design wells are driving outperformance of historical revenue per investment by 10% at 300 days on average RPI definition is: Realized per Boe x Cumulative NRI Boe WI CAPEX Historical Offset is the most proximal or similar offset to the 2018 well EP Energy Corporation RPI calculation does not include the benefit of any drilling carry 8 To produce a comparison of design efficiency, current realized prices, and current unit service costs were used for the calculation of both 2018 RPI and immediate Historical Offsets This chart contains 2018 activity only in green versus immediate offset wells in blue
EP Energy Corp
March 2019

D&C Evolution Has Led to Increased Returns and Superior Well Performance Drilling and Completion Design Evolution Increased Intensity Has Improved EURs (EUR / 1,000 ft) Generation 1 Generation 2 Generation 3 MBoe Hybrid completions Slickwater Slickwater XL 98 100 New completion designs have enhanced average actual well EUR from 76 81 76 MBoe / 1,000 Ft to 98 MBoe / 1,000 Ft (29% increase) 80 Slickwater XL technique (Gen 3) increased sand concentration and 60 clusters per stage to further stimulate the reservoir and increase fractures in the target zone 40 7 15 9 Gen 3 completion designs coupled with restricted choke management are expected to increase the long-term EUR of the well 20 6,225 6,447 6,739 90% improvement in drilling feet / day through process 0 optimization and high spec rigs Gen 1 Gen 2 Gen 3 64% reduction in flat times through use of multi-well pads, offline Wells Drilled Avg Lat Length (ft) cementing, walking packages and speedheads Gen Proven and improving 3 Completions results in theType Outperforming EagleCurve Ford (6 Mo Cum) Eagle Ford Average D&C Costs per Lateral Foot Cum. Production (Boe) / ft 100,000 2,958 3,000 13% 80,000 Outperformance 2,500 60,000 2,000 1,500 40,000 1,111 966 1,000 20,000 500 0 0 30 60 90 120 150 180 0 Days Gen 1 Gen 2 Gen 3 Gen 3 Avg Boe Cum Burleson Main Type Curve 14
WildHorse Resource Development
January 2017

El Halcn Type Curve Economics IRR vs. Oil Price 70% 60% 50% 40% IRR % 30% 20% 10% 0% 40 45 50 55 60 65 70 75 80 /Bbl NYMEX Oil El Halcon Tier 1 Type Curve (430 Mboe) Pricing & Expense Assumptions D&C Assumptions Gas Price (/MMBtu) 3.00 D&C Cost 6.3 MM Oil (% of NYMEX) 98% Completed Lateral Length 7,500 Gas (% of NYMEX) (1) 46% Stages 25 Avg. Working Interest 89% Proppant Type / Amount White Sand / 1,700 lbs/ft Avg. Royalty Burden 23% Fluid Type Hybrid, minimal gel Production Tax 7.6% - 10.5% Amount of Fluid 6,500 bbls/stage Note: See Cautionary Statements on page 3 for a description of EURs. 23 (1) Gathering, transportation and processing fees incorporated; gas differential presented on a gross wellhead basis.
Battalion Oil Corp.
November 2016

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