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Home My WebLink About2022 Deep Creek UnitPage 2 Reservoir Review Items per CO553 Rule 4 a) Summary and analysis of reservoir pressure by major formation. Because all of the Happy Valley wells have commingled production (from numerous sands), it is difficult to obtain precise individual sand reservoir pressures. Estimates can be made by reviewing pressures in wells with only one major zone open. The most recent shut-in wellhead pressures of wells with a single primary producing zone were compared to previous surveys (to verify fluid level for correcting to datum pressure using a gas gradient of 0.03 psi/ft) are shown below. The resulting average reservoir pressure by major zone is shown below. Since no new static surveys were conducted in 2022, updates for all sands are based upon the latest SITP value and assumed pressure gradient to datum. Note these data points may not be accurate due to unknown fluid columns but fall in line with the produced volumes. b) Workovers & surveys of the existing wells. a. Happy ValleyB 16A was drilled in 2022 and successfully targeted the Tyonek sands. It had an IP of 1.2 mmscfd at 47 psig flowing tubing pressure. b. Happy Valley A-10 add perfs. The add perfs added ~250mcfd from the Beluga sands. Well Top Perf Depth (MD) Major Formation Pressure at Datum (psig) Shut-in Tubing Pressure (psig) Date Pressure Taken HVA-01 7,155 Lower Tyonek 1,145 875 3/10/2022 HVA-08 4,972 Beluga 1,121 971 7/14/2022 HVB-13 3,798 Upper Tyonek 829 604 12/31/2021 HVB-14 1,689 Sterling 350 290 3/10/2022 HVB-16 3,446 Upper Beluga 1,205 1100 3/10/2022 Happy Valley Major Formations Sterling Upper Beluga Beluga Upper Tyonek Lower Tyonek Datum Depth (TVDss)2,000 3,500 5,000 7,500 9,000 Initial Pressure (psig)860 1,505 2,150 3,225 3,870 Est. Pressure (psig)350 1,205 1,121 829 1,145 Page 3 c) Production for 2022 Calendar Year (sub-divided by major formation) d) Progress and tests to expand pool productive limits. HVB-16A was an infill drill well. There were no tests done to expand the pools productive limits. Page 2 Reservoir Review Items per CO553 Rule 4 a) Summary and analysis of reservoir pressure by major formation. Because all of the Happy Valley wells have commingled production (from numerous sands), it is difficult to obtain precise individual sand reservoir pressures. Estimates can be made by reviewing pressures in wells with only one major zone open. The most recent shut-in wellhead pressures of wells with a single primary producing zone were compared to previous surveys (to verify fluid level for correcting to datum pressure using a gas gradient of 0.03 psi/ft) are shown below. The resulting average reservoir pressure by major zone is shown below. Since no new static surveys were conducted in 2022, updates for all sands are based upon the latest SITP value and assumed pressure gradient to datum. Note these data points may not be accurate due to unknown fluid columns but fall in line with the produced volumes. b) Workovers & surveys of the existing wells. a. Happy ValleyB 16A was drilled in 2022 and successfully targeted the Tyonek sands. It had an IP of 1.2 mmscfd at 47 psig flowing tubing pressure. b. Happy Valley A-10 add perfs. The add perfs added ~250mcfd from the Beluga sands. Well Top Perf Depth (MD) Major Formation Pressure at Datum (psig) Shut-in Tubing Pressure (psig) Date Pressure Taken HVA-01 7,155 Lower Tyonek 1,145 875 3/10/2022 HVA-08 4,972 Beluga 1,121 971 7/14/2022 HVB-13 3,798 Upper Tyonek 829 604 12/31/2021 HVB-14 1,689 Sterling 350 290 3/10/2022 HVB-16 3,446 Upper Beluga 1,205 1100 3/10/2022 Happy Valley Major Formations Sterling Upper Beluga Beluga Upper Tyonek Lower Tyonek Datum Depth (TVDss)2,000 3,500 5,000 7,500 9,000 Initial Pressure (psig)860 1,505 2,150 3,225 3,870 Est. Pressure (psig)350 1,205 1,121 829 1,145 Page 3 c) Production for 2022 Calendar Year (sub-divided by major formation) d) Progress and tests to expand pool productive limits. HVB-16A was an infill drill well. There were no tests done to expand the pools productive limits.