Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2023 Northstar-Kuparuk Oil Pool
Hilcorp Alaska, LLC
Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8486
Joleen.oshiro@hilcorp.com
April 1st, 2024
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,
2023 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 2023
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 2023, 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
1694 bopd and average daily gas injection was 152 mmscfpd.
During 2023, the negative reservoir voidage was calculated at 1369 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 2023 was 3140 psia.
Page 2
As of 12/31/2023 Full year (1) As of Dec-23 (2)
Producers 7 6
Injectors 2 2
2023
Cumulative Start-
Up through
12/31/23
618,156 10,800,009
55,487,442 473,604,278
1,485,334 5,779,514
0 0
57,216,631 226,370,772
5,203 37,511
3,834 15,167
-1,369 -22,344
1,694
152,020
4,069
0
156,758
3,140 psiaAverage of surveys obtained in 2023
Injection
Water, BWPD
Gas, MCFPD
AVERAGE RESERVOIR PRESSURE
DAILY AVERAGE RATE DATA 2023
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 2023
PRODUCTION/INJECTION STATISTICS
Production
Oil (BBL)
Table 1: NORTHSTAR KUPARUK OIL POOL
2023 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 – 2023
C. Summary and Analysis of reservoir pressure surveys within the pool
Static bottom hole pressures collected in 2023 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 2023.
There was no other special monitoring for this reporting period.
E. Review of pool production allocation factors and issues over the prior year
Month Oil, MRB Free Gas, MRB Water, MRB
Total
Voidage,
MRB
Year
Cum, MRB
Cum since
start-up, MRB
Formation
Gas, MRB
Flare &
Import
Gas, MRB
Total
Injection,
MRB
Year
Cum, MRB
Cum since
start-up,
MRB
Net
Injection,
MRB
Year
Cum, MRB
Cum since
start-up,
MRB
Jan-2021 0 332,589 126,804 459,393 459,393 32,767,402 361,268 0 361,268 361,268 11,695,596 -98,125 -98,125 -21,071,806
Feb-2021 0 291,356 115,192 406,548 865,941 33,173,950 322,606 0 322,606 683,874 12,018,202 -83,942 -182,067 -21,155,748
Mar-2021 0 322,136 126,433 448,569 1,314,510 33,622,519 358,634 0 358,634 1,042,508 12,376,836 -89,935 -272,002 -21,245,682
Apr-2021 0 319,856 122,765 442,621 1,757,131 34,065,140 355,025 0 355,025 1,397,533 12,731,861 -87,596 -359,598 -21,333,279
May-2021 0 266,168 124,214 390,382 2,147,513 34,455,522 343,310 0 343,310 1,740,843 13,075,171 -47,072 -406,671 -21,380,351
Jun-2021 0 252,739 117,125 369,864 2,517,377 34,825,386 318,362 0 318,362 2,059,205 13,393,533 -51,502 -458,172 -21,431,853
Jul-2021 0 253,018 130,552 383,570 2,900,947 35,208,955 322,034 0 322,034 2,381,239 13,715,567 -61,536 -519,708 -21,493,389
Aug-2021 0 209,520 102,087 311,607 3,212,555 35,520,563 209,454 0 209,454 2,590,693 13,925,021 -102,153 -621,861 -21,595,542
Sep-2021 0 298,852 111,283 410,135 3,622,690 35,930,698 286,288 0 286,288 2,876,982 14,211,309 -123,847 -745,708 -21,719,389
Oct-2021 0 389,925 118,118 508,043 4,130,733 36,438,741 294,095 0 294,095 3,171,077 14,505,405 -213,948 -959,656 -21,933,336
Nov-2021 0 382,851 119,545 502,396 4,633,128 36,941,137 319,554 0 319,554 3,490,631 14,824,959 -182,841 -1,142,497 -22,116,178
Dec-2021 0 398,648 171,216 569,864 5,202,993 37,511,001 342,883 0 342,883 3,833,514 15,167,842 -226,981 -1,369,478 -22,343,159
2023 Totals 0 3,717,659 1,485,334 5,202,993 3,833,514 0 3,833,514 -1,369,478
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-14A 50029230260100 O 590100 Ivishak 11091-11089 7/15/2023 2448 SBHP 254 11000 5159 11100 0.09 5169
NS-19 50029231220000 O 590100 Ivishak 10954-11069 7/16/2023 3840 SBHP 252 10900 5049 11100 0.08 5065
NS-20 50029231180000 O 590100 Ivishak 10958-11040 7/18/2023 3816 SBHP 250 10983 5150 11100 0.09 5162
NS-09 50029230520000 O 590100 Ivishak 10932-11030 8/21/2023 120 SBHP 251 11056 5092 11100 0.08 5097
NS-15 50029230730000 O 590150 Kuparuk 8940-8994 7/15/2023 1680 SBHP 190 9000 3098 9000 - 3098
NS-23 50029231460000 O 590150 Kuparuk 8953 - 9009 4/26/2023 - SBHP 201 9000 2937 9000 0.33 2937
NS-11 50029233030000 O 590100 Ivishak 10988 - 11058 8/22/2023 144 SBHP 256 11000 5096 11100 0.07 5103
NS-12 50029230910000 O 590100 Ivishak 10996 - 11057 8/22/2023 144 SBHP 252 11000 5089 11100 0.10 5099
NS-24 50029231110000 O 590100 Ivishak 10826 - 11047 8/24/2023 76368 SBHP 251 11020 5166 11100 0.10 5174
NS-20 50029231180000 O 590150 Kuparuk 9012 - 9059 11/22/2023 - SBHP 196 9000 3385 9000 0.17 3385
NS-24 50029231110000 O 590100 Sag 10717 - 10757 7/18/2023 75480 SBHP 250 10900 5304 11100 0.47 5397
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator: 2. Address:
Printed Name
Title
Date
Reservoir Engineer
March 27, 2024Gavin 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
Theoretical production is calculated for each Northstar producing well on a daily basis.
2023 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 2024. Well histories, review of production
and injection data, material balance calculations, geological, and geophysical work will be reviewed.
Projects completed during the 2023 calendar year:
Page 5
NS-23 (Ivishak) – recomplete to the Kuparuk reservoir as a producer
NS-20 (Ivishak) - recomplete to the Kuparuk reservoir as a producer
NS-16A (Ivishak) - recomplete to the Kuparuk reservoir as a producer
NS-15A (Kuparuk) – water injection test to verify injectivity underpinning water injection implementation
(2024)
Projects planned for the 2024 calendar year:
In 2024, 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. As such,
water injection in the Kuparuk is planned to begin in 2024. No drilling activities are planned at Northstar within
the 2024 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
