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Home My WebLink About2024 Northstar-Kuparuk Oil Pool Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/564-5246 Gavin.Dittman@hilcorp.com April 1st, 2025 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 KUPARUK OIL POOL, STATE OF ALASKA, 2024 ANNUAL RESERVOIR REVIEW Dear Commissioner Huber: In accordance with Conservation Order No. 739, Hilcorp Alaska, LLC (“Hilcorp”), as Operator, hereby submits for your review the following Annual Reservoir Review for the Kuparuk Oil Pool in the Northstar Field. This is the Annual Reservoir Review under Conservation Order No. 739 that corresponds to events during the 2024 calendar year. Note that the Northstar Field has been on production since November 2001, with the Kuparuk Oil Pool beginning continuous production in November 2010. A. Progress of Enhanced Recovery Project and Reservoir Management Summary During 2024, 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 statistics are summarized in Table 1. Average daily oil production from the Kuparuk Oil Pool field was 1602 bopd and average daily gas injection was 132 mmscfpd. During 2024, the negative reservoir voidage was calculated at 2414 thousand-reservoir barrels (MRB). Note that lean gas re-injection began in wells NS-18 and NS-17 in January and October 2019 respectively. The average reservoir pressure for 2024 was 2980 psia. Page 2 As of 12/31/2024 Full year (1) As of Dec-23 (2) Producers 6 5 Injectors 2 2 2024 Cumulative Start- Up through 12/31/24 586,338 10,800,009 63,595,852 473,604,278 1,386,494 5,779,514 0 0 48,253,225 226,370,772 5,647 43,158 3,233 18,400 -2,414 -24,758 1,602 173,759 3,788 0 131,839 2,980 psiaAverage of surveys obtained in 2024 Injection Water, BWPD Gas, MCFPD AVERAGE RESERVOIR PRESSURE DAILY AVERAGE RATE DATA 2024 Production Oil, BOPD Gas, MCF/D Water, BWPD Balance (excludes satellite well NS-34A and Ivishak Production ) Cum Production (MRB) Cum Injection (MRB) Over/Under (MRB) Gas (MCF) Water (BBL) Injection Water (BBL) Gas (MCF) (2) Active wells as of December 2024 PRODUCTION/INJECTION STATISTICS Production Oil (BBL) Table 1: NORTHSTAR KUPARUK OIL POOL 2024 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS NOTES: (1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year Page 3 B. Voidage Balance by Month of Produced Fluid and Injected Fluids – 2024 C. Summary and Analysis of reservoir pressure surveys within the pool Static bottom hole pressures collected in 2024 are summarized below. Please note this data includes Ivishak reservoir pressure data. D. Results and Analysis of Production and Injection log surveys, tracer surveys, observation well surveys and any other special monitoring No new Kuparuk production profiles were obtained in 2024. There was no other special monitoring for this reporting period. 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. Month Oil, RB Free Gas, RB Water, RB Total Voidage, RB Year Cum, RB Cum since start-up, RB Formation Gas, RB Flare & Import Gas, RB Total Injection, RB Year Cum, RB Cum since start-up, RB Net Injection, RB Year Cum, RB Cum since start-up, RB Jan-2024 0 394,478 134,547 529,025 529,025 38,040,026 340,345 0 340,345 340,345 15,508,187 -188,680 -188,680 -22,531,839 Feb-2024 0 332,387 112,472 444,859 973,884 38,484,885 319,347 0 319,347 659,692 15,827,534 -125,512 -314,192 -22,657,351 Mar-2024 0 341,758 115,951 457,709 1,431,593 38,942,594 333,524 0 333,524 993,216 16,161,058 -124,185 -438,377 -22,781,536 Apr-2024 0 372,635 112,030 484,665 1,916,259 39,427,260 321,339 0 321,339 1,314,555 16,482,397 -163,327 -601,704 -22,944,863 May-2024 0 375,017 121,650 496,667 2,412,926 39,923,927 323,238 0 323,238 1,637,793 16,805,635 -173,430 -775,133 -23,118,292 Jun-2024 0 364,919 115,437 480,356 2,893,282 40,404,283 319,072 0 319,072 1,956,864 17,124,706 -161,285 -936,418 -23,279,577 Jul-2024 0 332,715 107,497 440,212 3,333,494 40,844,495 281,600 0 281,600 2,238,464 17,406,306 -158,612 -1,095,030 -23,438,189 Aug-2024 0 301,186 102,395 403,581 3,737,074 41,248,075 158,913 0 158,913 2,397,377 17,565,219 -244,667 -1,339,697 -23,682,856 Sep-2024 0 370,261 115,824 486,085 4,223,159 41,734,160 183,377 0 183,377 2,580,755 17,748,597 -302,708 -1,642,405 -23,985,564 Oct-2024 0 381,576 120,088 501,664 4,724,823 42,235,824 173,059 0 173,059 2,753,813 17,921,655 -328,605 -1,971,010 -24,314,169 Nov-2024 0 352,388 117,005 469,393 5,194,217 42,705,218 205,780 0 205,780 2,959,593 18,127,435 -263,614 -2,234,624 -24,577,783 Dec-2024 0 341,602 111,598 453,200 5,647,416 43,158,417 273,373 0 273,373 3,232,966 18,400,808 -179,826 -2,414,450 -24,757,609 2024 Totals 0 4,260,922 1,386,494 5,647,416 3,232,966 0 3,232,966 -2,414,450 Produced Fluids Injected Fluids Net Injection (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-06 50029230880000 O 590100 Ivishak 10901-11099 8/10/2024 288 SBHP 253 11099 5108 11100 0.16 5108 NS-19 50029231220000 O 590100 Ivishak 10954-11069 8/11/2024 8064 SBHP 253 11000 5088 11100 0.09 5097 NS-09 50029230520000 O 590100 Ivishak 10932-11030 7/18/2024 312 SBHP 236 10399 5033 11100 0.10 5100 NS-15 50029230730000 O 590150 Kuparuk 8940-8994 8/16/2024 11232 SBHP 193 9000 2974 9000 0.42 2974 NS-23 50029231460000 O 590150 Kuparuk 8953 - 9009 8/15/2024 5760 SBHP 195 9100 3028 9000 0.42 2986 NS-11 50029233030000 O 590100 Ivishak 10988 - 11058 2/4/2024 984 SBHP 252 11000 5097 11100 0.09 5106 NS-12 50029230910000 O 590100 Ivishak 10996 - 11057 8/12/2024 96 SBHP 251 11000 5084 11100 0.09 5093 NS-24 50029231110000 O 590100 Ivishak 10826 - 11047 8/14/2024 17664 SBHP 248 10999 5056 11100 0.44 5100 NS-20 50029231180000 O 590150 Kuparuk 9012 - 9059 1/19/2024 24 SBHP 196 9000 2735 9000 0.44 2735 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: Printed Name Title Date Reservoir Engineer March 7, 2025Gavin 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 2024 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). F. & G. Future Development Plans & Review of Annual Plan of Operations and Development A full field study of the Northstar Kuparuk Reservoir will continue in 2025. Well histories, review of production and injection data, material balance calculations, geological, and geophysical work will be reviewed. Projects completed during the 2024 calendar year:  NS-20 (Kuparuk) – Begin process of converting NS-20 to Kuparuk water injection Page 5 Projects planned for the 2025 calendar year: In 2025, Hilcorp will pursue increased unit production through additional well intervention projects, any necessary infrastructure and facility repairs, and other optimization opportunities as they arise. Approval from the AOGCC to consider produced water an approved injection fluid was received in 2023. Additional approvals for both surface and subsurface work associated with this project are required from BSEE. The subsurface approval was granted in 2024. Surface approval from BSEE is anticipated in 2025 and water injection in the Kuparuk is planned to begin at that time. No drilling activities are planned at Northstar within the 2025 calendar year. Hilcorp is continuing to update the reservoir model to analyze the economics and viability of PBU gas imports to maintain pressure in the Kuparuk reservoir. Facility gas debottlenecking projects are currently being reviewed in conjunction with the gas importation feasibility study. Sincerely, Gavin Dittman Reservoir Engineer - Northstar