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Home My WebLink About2022 Northstar Oil Pool Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8486 Joleen.oshiro@hilcorp.com April 1st, 2023 Brett Huber Sr, Chair Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: NORTHSTAR UNIT, NORTHSTAR FIELD, NORTHSTAR OIL POOL, STATE OF ALASKA, 2022 ANNUAL RESERVOIR REVIEW Dear Commissioner Huber: In accordance with Conservation Order No. 458A, Hilcorp Alaska, LLC (“Hilcorp”), as Operator, hereby submits for your review the following Annual Reservoir Review for the Northstar Field. This is the Annual Reservoir Review and corresponds to events during the 2022 calendar year. Note that the Northstar Field has been on production since November 2001. A. Progress of Enhanced Recovery Project and Reservoir Management Summary During 2022, no new wells were drilled or sidetracked in the Northstar Unit. Therefore the locations of all the wells in the Northstar Unit have remained unchanged. Production and injection statistics are summarized in Table 1. Average daily oil production from the Northstar Oil Pool was 4,982 bopd and average daily gas injection was 403 mmscfpd. The reservoir voidage balance values reported do not include oil production or gas injection from outside the Northstar Oil Pool. The outside pool production includes satellite well NS-34A and Kuparuk zone production from wells NS-08, NS-13, NS-15, NS-18, and NS-07. Kuparuk gas injection into wells NS-17 and NS-18 also excluded. During 2022, gas injection was calculated to be 3,359 thousand-reservoir barrels (MRB) less than reservoir voidage. At year end, the reservoir overall cumulative voidage replacement ratio was 0.97. The average reservoir pressure from surveys obtained in 2022 was 5,363 psia, excluding NS-23 due to absent fluid column while obtaining fluid level for BHP calculation. Hilcorp became the official Operator of the Northstar Field effective November 18, 2014. Page 2 As of 12/31/2022 Full year (1) As of Dec-22 (2) Producers 15 14 Injectors 8 7 2022 Cumulative Start- Up through 12/31/22 1,818,436 180,268,656 147,412,075 3,048,453,553 1,744,811 85,236,027 5,214,791 98,153,082 147,273,314 3,404,034,904 103,505 2,308,853 100,146 2,314,744 -3,359 5,891 4,982 403,869 4,780 14,287 403,489 5,363 psiaAverage of surveys obtained in 2022 Water, BWPD Injection Water, BWPD Gas, MCFPD AVERAGE RESERVOIR PRESSURE DAILY AVERAGE RATE DATA 2022 Production Oil, BOPD Gas, MCF/D Gas (MCF) Balance (excludes satellite well NS-34A and Kup Production/Injection ) Cum Production (MRB) Cum Injection (MRB) Over/Under (MRB) Oil (BBL) Gas (MCF) Water (BBL) Injection Water (BBL) into NS10 & NS32 Disposal Well (1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year (2) Active wells as of December 2022 PRODUCTION/INJECTION STATISTICS Production Table 1: NORTHSTAR FIELD 2022 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS NOTES: Page 3 B. Voidage Balance by Month of Produced Fluid and Injected Fluids – 2022 C. Summary and Analysis of reservoir pressure surveys within the pool Static bottom hole pressures collected in 2022 are summarized below. Please note that the reported reservoir pressure of the wells NS-15, NS-13, and NS-17 are from the Kuparuk Reservoir. D. Results and Analysis of Production and Injection log surveys, tracer surveys, observation well surveys and any other special monitoring Month Oil, MRB Free Gas, MRB Water, MRB Total Voidage, MRB Year Cum, MRB Cum since start-up, MRB Total Injection, MRB Year Cum, MRB Cum since start-up, MRB Net Injection, MRB Year Cum, MRB Cum since start-up, MRB Jan-2022 405 9,341 155 9,901 9,901 2,215,304 10,585 10,585 2,225,183 684 684 9,879 Feb-2022 364 8,644 147 9,155 19,056 2,224,459 9,501 20,086 2,234,684 346 1,030 10,225 Mar-2022 388 9,274 170 9,832 28,888 2,234,291 10,000 30,086 2,244,684 168 1,198 10,392 Apr-2022 355 8,324 167 8,846 37,734 2,243,137 9,117 39,203 2,253,800 271 1,469 10,663 May-2022 343 7,883 157 8,382 46,116 2,251,519 8,358 47,561 2,262,159 -24 1,445 10,639 Jun-2022 325 7,552 158 8,035 54,150 2,259,554 7,730 55,291 2,269,889 -304 1,141 10,335 Jul-2022 329 7,566 160 8,056 62,206 2,267,610 7,756 63,047 2,277,645 -300 841 10,035 Aug-2022 229 5,416 115 5,760 67,966 2,273,370 5,176 68,223 2,282,821 -584 257 9,451 Sep-2022 314 7,510 150 7,974 75,940 2,281,343 7,168 75,391 2,289,989 -806 -549 8,645 Oct-2022 333 8,200 151 8,683 84,623 2,290,027 7,868 83,258 2,297,856 -816 -1,365 7,829 Nov-2022 332 8,416 145 8,893 93,516 2,298,919 7,966 91,224 2,305,822 -927 -2,292 6,903 Dec-2022 356 9,413 165 9,934 103,450 2,308,853 8,922 100,146 2,314,744 -1,012 -3,304 5,891 2022 Totals 4,071 97,539 1,839 103,450 100,146 -3,304 Produced Fluids Injected Fluids (Injection - Production) 6. Oil Gravity: 44 API/47 API 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) NS-14A 50029230260100 O 590100 Ivishak 11091-11089 12/7/22 148 SBHP 255 11000 5357 11100 .31 5388 NS-06 50029230880000 O 590100 Ivishak 10901-11099 12/8/22 1568 SBHP 254 11000 5341 11100 .18 5359 NS-19 50029231220000 O 590100 Ivishak 10954-11069 12/8/22 32664 SBHP 255 10900 5357 11100 .31 5419 NS-20 50029231180000 O 590100 Ivishak 10958-11040 12/9/22 32040 SBHP 255 10900 5341 11100 .085 5358 NS-09 50029230520000 O 590100 Ivishak 10932-11030 12/11/22 80 SBHP 255 11000 5357 11100 0.34 5391 NS-16A 50029230960100 O 590100 Ivishak 11029-11091 12/11/22 85 SBHP 254 10300 5357 11100 0.2 5517 NS-34A 50029233010100 O 590100 Ivishak 11049-11091 12/12/22 85 SBHP 254 11100 5350 11100 0 5350 NS-23 50029231460000 GI 590100 Ivishak 11056-11321 12/12/22 71 Other 11100 .031 4596 NS-28 50029232480000 GI 590100 Ivishak 11108-11150 12/13/22 82 Other 11100 0.45 5404 NS-30 50029232930000 O 590100 Ivishak 10858-11021 12/15/22 97 SBHP 252 11000 5058 11100 0.27 5085 NS-15 50029230730000 O 590150 Kuparuk 8940-8994 12/15/22 93 SBHP 189 9000 2910 9000 0 2910 NS-13 50029230170000 O 590150 Kuparuk 8875-9000 8/11/22 165 SBHP 8492 2237 9000 .09 2283 NS-17 50029231130000 GI 590150 Kuparuk 8859-9079 12/9/22 96 Other 9000 0.45 3493 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: Printed Name Title Date Reservoir Engineer March 23, 2023Gavin Dittman Certified Digital Signature 23. All tests reported herein were made in accordance w ith the applicable rules, regulations, and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. 7. Gas Gravity: Northstar Unit Hilcorp Alaska, LLC 3800 Centerpoint Dr Suite 1400, Anchorage, AK 99503 Northstar Field/Northstar Oil Pool & Hooligan (Kuparuk) Oil Pools -11,100' TVDss/-9000' TVDss 0.75 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: Page 4 No new Ivishak production profiles were obtained in 2022. E. Review of pool production allocation factors and issues over the prior year Theoretical production is calculated for each Northstar producing well on a daily basis. 2022 Production Allocation Method A well’s theoretical production is calculated using metered field volumes and hours on production as follows: Gas Allocation Gross Produced Gas = total return metered at test separator. Net Produced Gas = Gross Produced Gas – Gaslift Gas. Theoretical Produced Gas = all well tests Net Produced Gas prorated by the month. (Proration calculation will include adjustments for shut in or downtime periods) Field Gas Injection = metered prior to injection Total Net Produced Gas = Field Gas Injection + Fuel Gas + Flare Gas + PPA Gas - Buy Gas (Buy Gas = imported or Caribou Crossing acquired gas). 𝑇𝑜𝑡𝑎𝑙 𝑁𝑒𝑡 𝑃𝑟𝑜𝑑𝑢𝑐𝑒𝑑 𝐺𝑎𝑠 𝑇ℎ𝑒𝑜𝑟𝑒𝑡𝑖𝑐𝑎𝑙 𝑃𝑟𝑜𝑑𝑢𝑐𝑒𝑑 𝐺𝑎𝑠=𝐺𝑎𝑠 𝐴𝑙𝑙𝑜𝑐𝑎𝑡𝑖𝑜𝑛 𝐹𝑎𝑐𝑡𝑜𝑟 Gas Allocation Factor x Theoretical Produced Gas (individual well) = Allocated Gas (individual well). Oil Allocation Actual Field Oil Production = oil volume metered by LACT (sold/delivered to Northstar crude oil pipeline) (Adjusted for BS&W, temperature, and API gravity in accordance with API standards and BSEE regulations.) Gross Produced Oil = total return metered at test separator. Theoretical Well Oil Production = all well tests Gross Produced Oil prorated by the month. (Proration calculation will include adjustments for shut in or downtime periods) Theoretical Field Oil Production = Sum of Theoretical Well Oil Production Field Natural Gas Liquid (NGL) Production = metered prior to commingling with oil 𝐴𝑐𝑡𝑢𝑎𝑙 𝐹𝑖𝑒𝑙𝑑 𝑂𝑖𝑙 𝑃𝑟𝑜𝑑𝑢𝑐𝑡𝑖𝑜𝑛+𝐹𝑖𝑒𝑙𝑑 𝑁𝐺𝐿 𝑃𝑟𝑜𝑑𝑢𝑐𝑡𝑖𝑜𝑛 𝑇ℎ𝑒𝑜𝑟𝑒𝑡𝑖𝑐𝑎𝑙 𝐹𝑖𝑒𝑙𝑑 𝑂𝑖𝑙 𝑃𝑟𝑜𝑑𝑢𝑐𝑡𝑖𝑜𝑛=𝑂𝑖𝑙 𝐴𝑙𝑙𝑜𝑐𝑎𝑡𝑖𝑜𝑛 𝐹𝑎𝑐𝑡𝑜𝑟 Oil Allocation Factor x Theoretical Well Oil Production = Allocated Oil Production (individual well). Water Allocation Actual Field Water Production = water volume metered prior to injection disposal Net Field Water Production = Actual Field Water Production – Metered Grey Water Gross Produced Water = total metered at test separator. Theoretical Well Water Production = all well tests Gross Produced Water prorated by the month. (Proration calculation will include adjustments for shut in or downtime periods) Theoretical Field Water Production = Sum of Theoretical Well Water Production 𝑁𝑒𝑡 𝐹𝑖𝑒𝑙𝑑 𝑊𝑎𝑡𝑒𝑟 𝑃𝑟𝑜𝑑𝑢𝑐𝑡𝑖𝑜𝑛 𝑇ℎ𝑒𝑜𝑟𝑒𝑡𝑖𝑐𝑎𝑙 𝐹𝑖𝑒𝑙𝑑 𝑊𝑎𝑡𝑒𝑟 𝑃𝑟𝑜𝑑𝑢𝑐𝑡𝑖𝑜𝑛=𝑊𝑎𝑡𝑒𝑟 𝐴𝑙𝑙𝑜𝑐𝑎𝑡𝑖𝑜𝑛 𝐹𝑎𝑐𝑡𝑜𝑟 Water Allocation Factor x Theoretical Well Water Production = Allocated Water Production (individual well). Page 5 F. & G. Future Development Plans & Review of Annual Plan of Operations and Development In 2022, Hilcorp continued to maintained unit production through optimization opportunities. The field study of the Northstar Unit continued. Well histories, production and injection data, material balance calculations, geological, and geophysical work were studied and updated as necessary. Projects completed during the 2022 calendar year:  NS-05 (Ivishak) – Surface twin Projects planned for the 2023 calendar year: In 2023, Hilcorp will pursue increased unit production through additional well intervention projects, any necessary infrastructure and facility repairs, and other optimization opportunities as they arise. No drilling activities are planned at Northstar within the 2023 calendar year. Gas debottlenecking in the Northstar facilities is currently under evaluation. This project would benefit Ivishak by increasing the gas handling capacities and potentially allowing for increased production in select well. Hilcorp will continue update the full field study of the Northstar Unit. This may include re-mapping productive horizons, updating well histories, reviewing production and injection data, material balance calculations, and reviewing results of any recent well intervention projects. Sincerely, Gavin Dittman Reservoir Engineer - Northstar