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  Economics : Type Curve

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Assumptions Louisiana 4,600' Lateral Type Curve 100,000 Avg Daily Production (Mcfpd) EUR 13 Bcf (2.8 Bcf/1,000) 10,000 Sales Gas BTU Price 1.020 Adjustment 1,000 Pricing Average - NYMEX less 0.20 / MMBtu Differentials/ Transportation: 0.30 / Mcf Transportation 100 Fixed Opex Fixed Opex: 3,000 / month 0 20 40 60 80 100 120 Months Variable Opex 0.05 / Mcf 4,600' Lateral Severance Tax Severance Tax Abatement Until Payout (Assumed at 12 months), R Sensitivity Analysis Estimates (IRR Sensitivity to EURs and Capex) thereafter 0.09 / Mcf IRRs Based on Composite Curve from Actual Results EUR Capex Ad Val Tax 0.03 / Mcf (Mmcfe) (M) 90% 100% 110% 90% 100% 110% Royalty Burden 27.0% 2.50 62% 84% 109% 2.50 111% 84% 64% 2.75 88% 117% 152% 2.75 155% 117% 91% Gas Price D&C Capex 7.2 MM 3.00 118% 158% 204% 3.00 209% 158% 122% Facilities/Tubing 3.25 154% 206% 268% 3.25 275% 206% 159% 0.200 MM, included in D&C Capex Capex 3.50 197% 263% 346% 3.50 355% 263% 203% Spud to 1st Sale 60 Days Ownership: WI 100% - NRI 73% PV10 Pricing: Flat Pricing 9.3 Million (Post Capex) (3.00/Mcf Pricing) AFE: Two well pad. Economic EURs vary depending on gas price assumptions. 11
Goodrich Petroleum Corp.
November 2021

Optimized Completions in the Cotton Valley Key Points Cotton Valley Completions Optimization Cumulative Gas (MMcf) (1)(2) Significant improvements in well performance are being realized from 5,000 Cumulative Gas (MMcf) larger fracs in the Cotton Valley Completion jobs with higher proppant 4,000 loading, more volume and tighter spacing are significantly increasing recoveries 3,000 High-intensity completion designs are being implemented across the play 2,000 Operators have systematically increased proppant and fluid loading in Central De Soto Cotton Valley acreage 1,000 Generation 3 results significantly outperform earlier vintage frac designs 0 0 6 12 18 24 Months Gen 3 Frac Design (1) Historic Gen 2 Amplify Design Proppant <1,000 lbs/ft 1,500 lbs/ft 2,000 lbs/ft Fluid <1,000 gal/ft 1,350 gal/ft 1,500 gal/ft Stage Spacing 400 250 200 Historic 6 Month Cum. (2) 0.75 Bcf 1.30 Bcf 2.00 Bcf Gen 2 Gen 3 (1) Source: IHS Enerdeq (2) Production data normalized to 6,000 lateral length. 19
Amplify Energy Corp.
July 2017

1st Year Cotton Valley Profile (1) Drill & Total 1st Year Field Level % of Payout Payout Complete Production Cash Flow (2) 1st year Period Cost 4,000 M 2.3 Bcfe (6.3 MMcfe/d) 3,624 M 91% 22 mth 12,000 10,000 8,000 MMcfe/d 6,000 4,000 2,000 - 1 2 3 4 5 6 7 8 9 10 11 12 Month (1) 2014 Avg. well performance; excluding PQ 11 (2) Price assumptions: 2.50/Mcf, 15Bbl of NGL and 40/Bbl of Oil 10
Petroquest Energy Inc.
November 2016
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