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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2021 Greater Kuparuk Area
Greater Kuparuk Area
2021 Annual Reservoir Surveillance Reports
Kuparuk, Meltwater, Tabasco, Tarn,
Kuparuk River-Torok, & West Sak Oil Pools
Reporting Period
January 1 to December 31, 2021
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2021
GREATER KUPARUK AREA
ANNUAL SURVEILLANCE REPORTS
Table of Contents
KUPARUK RIVER OIL POOL REPORT
SUMMARY OF EOR PROJECT………………………………………………………………………
Map of EOR Program Status
Plot of Incremental EOR Oil Rate
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
INJECTION SURVEYS…………………………………………………………………………………..
Proposed Injection Profile Survey Plan
Injection Profile Survey Report
PRODUCTION SURVEY DATA………………………………………………………………………
MISCIBLE INJECTANT COMPOSITION………………………………………………………….
CPF1 MI Composition
CPF2 MI Composition
KUPARUK LSEOR DEVELOPMENT PLAN………………………………………………………
MELTWATER OIL POOL REPORT
SUMMARY OF EOR PROJECT & RESERVOIR MANAGEMENT……………………….
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
PRODUCTION LOGS & SPECIAL SURVEYS……………………………………………………
WELL ALLOCATION & SHALLOW GAS SPECIAL MONITORING……………………..
RESULTS OF INNER AND OUTER ANNULI MONITORING……………………………..
DEVELOPMENT PLANS & OPERATIONAL REVIEW……………………………………….
MAP SHOWING DEVELOPMENT AS OF 12/31/2021……………………………………
GKA Annual Surveillance Report Table of Contents 3
ATTACHMENT 1, PG. 11
ATTACHMENT 2, PG. 15
ATTACHMENT 3, PG. 16
ATTACHMENT 4, PG. 21
ATTACHMENT 5, PG. 41
ATTACHMENT 6, PG. 42
ATTACHMENT 7, PG. 43
ATTACHMENT 8, PG. 44
ATTACHMENT 1, PG. 49
ATTACHMENT 2, PG. 51
ATTACHMENT 3, PG. 52
ATTACHMENT 4, PG. 57
ATTACHMENT 5, PG. 58
ATTACHMENT 6, PG. 59
ATTACHMENT 7, PG. 61
ATTACHMENT 8, PG. 72
ATTACHMENT 9, PG. 73
TABASCO OIL POOL REPORT
SUMMARY OF EOR PROJECT…………………………………………..………………………….
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
PRODUCTION LOGS & SPECIAL SURVEYS……………………………………………………
WELL ALLOCATION & TEST EVALUATION SUMMARY …………………………………
DEVELOPMENT PLANS & OPERATIONAL REVIEW……………………………………….
TARN OIL POOL REPORT
SUMMARY OF EOR PROJECT…………………………………………..………………………….
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
PRODUCTION LOGS & SPECIAL SURVEYS……………………………………………………
PRODUCTION ALLOCATION FACTORS………………………………………………………..
DEVELOPMENT PLANS & OPERATIONAL REVIEW……………………………………….
MAP SHOWING DEVELOPMENT AS OF 12/31/2021……………………………………
KUPARUK RIVER-TOROK OIL POOL REPORT
SUMMARY OF EOR PROJECT…………………………………………..………………………….
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
Reservoir Pressure Map
PRODUCTION LOGS & SPECIAL SURVEYS……………………………………………………
WELL ALLOCATION & SPECIAL MONITORING……………………………………………..
RESULTS OF INNER AND OUTER ANNULI MONITORING……………………………..
DEVELOPMENT PLANS & OPERATIONAL REVIEW……………………………………….
GKA Annual Surveillance Report Table of Contents 4
ATTACHMENT 1, PG. 79
ATTACHMENT 2, PG. 80
ATTACHMENT 3, PG. 81
ATTACHMENT 4, PG. 83
ATTACHMENT 5, PG. 87
ATTACHMENT 6, PG. 88
ATTACHMENT 7, PG. 89
ATTACHMENT 1, PG. 95
ATTACHMENT 2, PG. 96
ATTACHMENT 3, PG. 97
ATTACHMENT 4, PG. 98
ATTACHMENT 5, PG. 102
ATTACHMENT 6, PG. 103
ATTACHMENT 7, PG. 104
ATTACHMENT 8, PG. 105
ATTACHMENT 1, PG. 111
ATTACHMENT 2, PG. 112
ATTACHMENT 3, PG. 113
ATTACHMENT 4, PG. 115
ATTACHMENT 5, PG. 121
ATTACHMENT 6, PG. 122
ATTACHMENT 7, PG. 123
ATTACHMENT 8, PG. 126
WEST SAK OIL POOL REPORT
SUMMARY OF EOR PROJECT…………………………………………..………………………….
PRODUCED FLUID VOLUMES……………………………………………………………………..
INJECTED FLUID VOLUMES…………………………………………………………………………
RESERVOIR PRESSURE SURVEYS…………………………………………………………………
Proposed Pressure Survey Plan
Reservoir Pressure Survey Report
INJECTION SURVEY DATA…………………………………………………………………………..
PRODUCTION SURVEY DATA………………………………………………………………………
GEOCHEMICAL OIL PRODUCTION SPLITS……………………………………………………
PRODUCTION ALLOCATION FACTORS………………………………………………………..
DEVELOPMENT PLANS & OPERATIONAL REVIEW……………………………………….
KUPARUK GAS OFFTAKE
TABLE OF MONTHLY GAS OFFTAKE…………………………………………………………….
ATTACHMENT 1, PG. 131
ATTACHMENT 2, PG. 132
ATTACHMENT 3, PG. 133
ATTACHMENT 4, PG. 135
GKA Annual Surveillance Report Table of Contents 5
ATTACHMENT 5, PG. 140
ATTACHMENT 6, PG. 141
ATTACHMENT 7, PG. 143
ATTACHMENT 8, PG. 146
ATTACHMENT 9, PG. 147
ATTACHMENT 1, PG. 153
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KUPARUK
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Kuparuk Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 3, Conservation Order No. 198B, ConocoPhillips Alaska, Inc., operator of the Kuparuk River
Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the
required information pertinent to the field development and enhanced recovery operations from January through
December 2021. The following is an outline of the information provided:
a. A summary of the enhanced recovery project (Attachment 1).
b. Voidage balance, by month, for produced and injected fluids, including low molecular weight
hydrocarbons (Attachments 2 and 3).
c. Analysis of reservoir pressure surveys taken in 2021 (Attachment 4).
d. A tabulation of both injection (Attachment 5) and production (Att achment 6) logs and surveys
analyzed during 2021 from wells in the Kuparuk permit area.
e. Composition of enriched gas injected during 2021 and estimate of Minimum Miscible Pressure
(Attachment 7).
f. Kuparuk Large Scale Enhanced Oil Recovery (LSEOR) development plan (Attachment 8).
If you have any questions concerning this data, please contact Jerissa Hampton at (907)-263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 1
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of the Enhanced Recovery Project
Enhanced Recovery
Miscible water‐alternating‐gas (MWAG) was the main enhanced oil recovery (EOR) process for the Kuparuk Field
in 2021. In September of 2018, NGL imports from Prudhoe Bay (PBU) were brought back into Kuparuk for the first
time since 2014 and continued until September of 2021. With the cessation of Prudhoe Bay NGL imports, only
Kuparuk indigenous NGLs were blended for gas enrichment. This marks the transition from a MWAG (miscible
water alternating gas) process to an EWAG (enriched water alternating gas) tertiary gas inject ion flood. In total,
70 injectors and 24 drillsites received miscible injectant between January and December of 2021.
Kuparuk Field manufactures miscible injectant at two of its Central Processing Facilities (CPFs). Miscible injectant
(MI) is manufactured by blending together produced lean gas (LG) and natural gas liquids (NGLs). Both indigenous
and imported Prudhoe Bay NGLs were used for enhanced recovery programs in 2021.
MWAG
Small-Scale EOR (SSEOR and SSEORX)
Drillsites 1A, 1Y, and 2Z all received MI periodically throughout 2021. The combined 12-month average MI
injection rate was 5.4 mmscf/d.
Large-Scale EOR (LSEOR)
The original LSEOR drillsites include: 1F, 1G, 1Q, 1R, 2A, 2B, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X, and 3F.
Of these drillsites, 1F, 1Q, 2A, 2B, 2C, 2H, 2K, 2M, 2T, and 3F received MI in 2021. The combined 12-month average
MI injection rate was 12.1 mmscf/d.
EOR Expansions
Expansions to the original LSEOR occurred over multiple phases and now include drillsites 1B, 1C, 1D, 1E, 1L, 2S,
3B, 3G, 3H, 3O, 3Q and 3S. Of these drillsites, 1B, 1C, 1D, 1E, 1L, 2S, 3B, 3G, 3O, 3Q and 3S received MI in 2021.
The combined 12-month average MI injection rate was 33.3 mmscf/d.
IWAG
Minimal volumes of lean gas available after blending MI were injected into the field as immiscible water-
alternating-gas (IWAG) periodically throughout 2021. Drillsites 1A, 1C, 1D, 1E, 1Q, 1Y, 2C, 2K, 2Z, 3B, 3F, 3G, 3O,
3Q, 3S received lean gas in 2021. The combined 12-month average LG injection rate was 11.2 mmscf/d.
GKA Annual Surveillance Report Kuparuk Oil Pool 11
GKA Active EOR Patterns
➢70 KRU
➢8 Tarn
➢2 West Sak
SSEOR and SSEORX
LSEOR and LSEORX
EORX1 Expansion in 2002 –4 Wells
EORX1 Expansion in 2001
EORX1 Expansion in 2003
1C WSak EOR Pilot 2003
1D EOR Expansion in 2008
GKA Satellites 1998-2002
2021 EOR Program Status
2L, 2N
(Tarn)
2P
(MW)
2G
3R
3O
3N
3K
3H 3J
3C
1R
1H
1D
3B
1Q
1G
1B
3F
2W
1Y
1A
1F
2T 2U
2X
2Z2V
2C
2D
1L
2A
2B
2F
2E
2K
2M 2H
3I
3A
3Q
1C
3G
3M
1E
3S
W SAK
2S
LSEORX4 Expansion in 2018
GKA Annual Surveillance Report Kuparuk Oil Pool 12
2021 EOR Program Status*
MWAG
WI Only
VRWAG
2L, 2N
(Tarn)
2P
(MW)
2G
3R
3O
3N
3K
3H 3J
3C
1R
1H
1D
3B
1Q
1G
1B
3F
2W
1A
1F
2T 2U
2X
2Z2V
2C
2D
1L
2A
2B
2F
2E
2K
2M 2H
3I
3A
3Q
1C
3G
3M
1E
3S
W SAK
1Y
2S
*Fluid injection capabilities
in December 2021
GKA Annual Surveillance Report Kuparuk Oil Pool 13
2010-2021 Kuparuk EOR+NGL Sales Production –By Drillsite
BOPDDate
GKA Annual Surveillance Report Kuparuk Oil Pool 14
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:2,515,926 3,583,718 5,482,038
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 2,114 3,463 16,859 2,518,040 3,587,181 5,498,897
2 2021 1,822 2,800 13,752 2,519,862 3,589,981 5,512,649
3 2021 2,035 3,199 16,851 2,521,898 3,593,180 5,529,500
4 2021 1,918 2,990 16,412 2,523,816 3,596,169 5,545,912
5 2021 1,987 2,888 17,691 2,525,803 3,599,057 5,563,603
6 2021 1,913 2,974 17,205 2,527,716 3,602,031 5,580,808
7 2021 1,948 2,915 16,874 2,529,664 3,604,946 5,597,682
8 2021 1,904 3,024 16,839 2,531,568 3,607,970 5,614,521
9 2021 1,791 2,941 16,172 2,533,359 3,610,911 5,630,693
10 2021 1,901 3,339 16,908 2,535,260 3,614,250 5,647,601
11 2021 1,756 3,254 15,694 2,537,016 3,617,504 5,663,295
12 2021 1,871 3,262 16,504 2,538,888 3,620,766 5,679,800
2021 TOTAL 22,962 37,048 197,762
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:3,104,652 2,111,150 5,582,515
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 2,609 2,176 17,180 3,107,261 2,113,327 5,599,695
2 2021 2,248 1,712 14,013 3,109,509 2,115,038 5,613,708
3 2021 2,512 1,975 17,172 3,112,021 2,117,013 5,630,880
4 2021 2,367 1,839 16,724 3,114,388 2,118,853 5,647,604
5 2021 2,452 1,719 18,027 3,116,840 2,120,572 5,665,631
6 2021 2,361 1,828 17,532 3,119,201 2,122,399 5,683,163
7 2021 2,403 1,760 17,194 3,121,604 2,124,160 5,700,357
8 2021 2,350 1,876 17,159 3,123,954 2,126,036 5,717,516
9 2021 2,210 1,850 16,480 3,126,165 2,127,886 5,733,995
10 2021 2,346 2,157 17,229 3,128,510 2,130,043 5,751,224
11 2021 2,167 2,144 15,993 3,130,677 2,132,186 5,767,217
12 2021 2,309 2,101 16,818 3,132,986 2,134,288 5,784,035
2021 TOTAL 28,335 23,138 201,519
Produced Fluid Volumes
ATTACHMENT 2
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Kuparuk Oil Pool 15
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:8,164,983 1,334,215 1,452,862
WATER GAS MI CUM WATER CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 22,738 315 1,663 8,187,721 1,334,530 1,454,525
2 2021 19,071 0 1,636 8,206,792 1,334,530 1,456,162
3 2021 21,130 0 1,838 8,227,922 1,334,530 1,457,999
4 2021 20,797 0 1,823 8,248,719 1,334,530 1,459,822
5 2021 20,295 0 1,509 8,269,014 1,334,530 1,461,331
6 2021 19,348 0 1,738 8,288,361 1,334,530 1,463,069
7 2021 19,026 0 1,631 8,307,388 1,334,530 1,464,700
8 2021 19,532 0 1,595 8,326,920 1,334,530 1,466,294
9 2021 18,762 0 2,000 8,345,682 1,334,530 1,468,294
10 2021 19,654 2,203 325 8,365,336 1,336,733 1,468,619
11 2021 19,986 1,560 780 8,385,322 1,338,293 1,469,399
12 2021 20,952 3 1,971 8,406,274 1,338,296 1,471,370
2021 TOTAL 241,291 4,081 18,508
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:8,315,647 1,179,721 780,798
WATER GAS MI CUM WATER CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 23,170 278 1,259 8,338,817 1,179,999 782,057
2 2021 19,434 0 1,239 8,358,250 1,179,999 783,296
3 2021 21,531 0 1,391 8,379,782 1,179,999 784,687
4 2021 21,192 0 1,380 8,400,974 1,179,999 786,067
5 2021 20,681 0 1,142 8,421,654 1,179,999 787,209
6 2021 19,715 0 1,316 8,441,370 1,179,999 788,525
7 2021 19,388 0 1,234 8,460,757 1,179,999 789,759
8 2021 19,903 0 1,207 8,480,661 1,179,999 790,967
9 2021 19,118 0 1,514 8,499,779 1,179,999 792,480
10 2021 20,028 1,945 246 8,519,807 1,181,945 792,726
11 2021 20,365 1,377 591 8,540,172 1,183,322 793,317
12 2021 21,350 3 1,492 8,561,522 1,183,325 794,809
2021 TOTAL 245,876 3,604 14,010
Injected Fluid Volumes
ATTACHMENT 3
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Kuparuk Oil Pool 16
CUM LEAN GAS
CUM LEAN GAS
Attachment 4
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Kuparuk Oil Pool 17
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Kuparuk River Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River
Oil Pool, is hereby submitting the proposed pressure survey plan for 2022.
There were 154 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2021.
In 2022, we expect to conduct approximately 150 pressure surveys, including surveys for new wells prior to initial
sustained production.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
1A-01 50029205900000 O 490100 AC (-5951 - -5992),
(-6002 - -6014),
(-6029 - -6037),
(-6169 - -6178),
(-6185 - -6208)
1/13/2021 138 SBHP 153 6168.72 3397 6200 0.432 3411
1A-04A 50029206210100 WAG 490100 A (-6338 - -6347),
(-6353 - -6386)
7/13/2021 837 PFO 141 6112.04 3767 6200 0.44 3806
1A-05 50029206270000 WAG 490100 AC (-5898 - -6005),
(-6028 - -6032),
(-6038 - -6044),
(-6128 - -6132),
(-6141 - -6168)
6/1/2021 332 SBHP 129 6016.31 3445 6200 0.44 3526
1A-07 50029206580000 WAG 490100 A (-5872 - -5948),
(-5958 - -5972),
(-6098 - -6105),
(-6112 - -6130),
(-6131 - -6148)
5/8/2021 257 SBHP 124 6124.71 4511 6200 0.444 4544
1A-25 50029221160000 O 490100 AC (-6132 - -6138),
(-6148 - -6181),
(-5996 - -6013),
(-6016 - -6032)
8/28/2021 19171 SBHP 153 5995.41 3828 6200 0.43 3916
1A-25 50029221160000 O 490100 C (-6132 - -6138),
(-6148 - -6181),
9/28/2021 19915 SBHP 153 5995.41 3725 6200 0.36 3798
1A-25 50029221160000 O 490100 C (-6132 - -6138),
(-6148 - -6181),
(-5996 - -6013),
(-6016 - -6032)
11/3/2021 20782 SBHP 147 5863.4 3596 6200 0.445 3746
1B-10 50029206560000 O 490100 C (-6530 - -6539),
(-6546 - -6557),
(-6557 - -6575)
10/20/2021 84 SBHP 143 6224.77 2858 6200 0.52 2845
1C-12 50029227190000 O 490100 C (-6449 - -6460), 10/20/2021 120 SBHP 150 6453.89 2705 6200 0.34 2619
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 21
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
1D-01 50029203930000 O 490100 C (-6293 - -6308),
(-6308 - -6350),
(-6354 - -6361),
(-6366 - -6374),
(-6379 - -6388)
3/29/2021 96 SBHP 154 6153.52 2534 6200 0.43 2554
1D-05 50029204170000 WAG 490100 AC (-6346 - -6429)8/12/2021 5328 SBHP 138 6267.87 2951 6200 0.41 2923
1D-11 50029229460000 WAG 490100 C (-6441 - -6452),
(-6470 - -6481)
3/1/2021 816 SBHP 141 6446.86 2603 6200 0.43 2497
1D-36 50029229730000 O 490100 C (-6320 - -6325)2/3/2021 144 SBHP 158 6302.8 2821 6200 0.43 2777
1D-42 50029229790000 O 490100 C (-6141 - -6160)4/6/2021 2016 SBHP 143 5802.84 3014 6200 0.33 3145
1E-08A 50029204960100 WAG 490100 A (-6265 - -6277),
(-6293 - -6299),
(-6342 - -6349)
11/7/2021 408 PFO 131 6003.08 4362 6200 0.44 4449
1E-13 50029207500000 WI 490100 AC (-6270 - -6280),
(-6293 - -6311),
(-6315 - -6326)
1/23/2021 4900 SBHP 146 6313.85 3143 6200 0.317 3107
1E-19 50029209050000 WAG 490100 A (-6004 - -6138),
(-6297 - -6304),
(-6317 - -6344)
8/8/2021 99999 SBHP 157 6297.26 2589 6200 0.31 2559
1E-21 50029208920000 WAG 490100 A (-5952 - -6037),
(-6209 - -6220),
(-6169 - -6170),
(-6170 - -6182),
(-6182 - -6187),
(-6194 - -6196),
(-6196 - -6203)
3/22/2021 552 SBHP 120 6204.33 4438 6200 0.49 4436
1E-27 50029208370000 WAG 490100 A (-5925 - -5966),
(-5975 - -5983),
(-6114 - -6123),
(-6138 - -6161),
(-6168 - -6172)
4/28/2021 360 SBHP 130 6005.19 4119 6200 0.45 4207
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 22
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
1E-27 50029208370000 WAG 490100 A (-5925 - -5966),
(-5975 - -5983),
(-6114 - -6123),
(-6138 - -6161),
(-6168 - -6172)
11/8/2021 504 PFO 131 5817.93 4181 6200 0.44 4349
1E-36 50029229270000 O 490100 C (-5950 - -5962),
(-5913 - -5916),
(-5929 - -5941),
11/13/2021 48 SBHP 151 5713.28 2663 6200 0.35 2833
1F-06 50029208200000 O 490100 C (-6019 - -6064),
(-6232 - -6237)
4/1/2021 144 SBHP 157 6018.53 2379 6200 0.42 2455
1F-16A 50029210290100 WAG 490100 A (-5802 - -5817),
(-5821 - -5836),
(-5967 - -5968),
(-5976 - -5987),
, , ,
4/29/2021 384 SBHP 133 5819 4169 6200 0.34 4299
1F-17 50029226570000 O 490100 AC (-6075 - -6103)5/5/2021 1824 SBHP 160 6089.84 3136 6200 0.399 3180
1G-05 50029209080000 WAG 490100 A (-6144 - -6198),
(-6232 - -6259),
(-6408 - -6411),
(-6419 - -6442)
5/19/2021 247 SBHP 128 6310.03 4228 6200 0.55 4167
1H-04 50029207700000 WI 490100 A (-6235 - -6288),
(-6329 - -6357),
(-6490 - -6494),
(-6502 - -6522)
2/5/2021 206 PFO 98 6376.61 3837 6200 0.44 3759
1H-04 50029207700000 WI 490100 C (-6235 - -6288),
(-6329 - -6357),
(-6490 - -6494),
(-6502 - -6522)
2/5/2021 206 PFO 115 6214.79 3507 6200 0.44 3500
1H-04 50029207700000 WI 490100 AC (-6235 - -6288),
(-6329 - -6357),
(-6490 - -6494),
(-6502 - -6522)
7/12/2021 3985 SBHP 124 6376.61 3258 6200 0.46 3177
1H-19A 50029223120100 WI 490100 A (-6532 - -7764)11/27/2021 6161 SBHP 134 6167.1 2511 6200 0.44 2525
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 23
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
1L-12 50029220330000 O 490100 AC (-5950 - -5973),
(-6025 - -6033)
11/6/2021 2736 SBHP 162 6044.62 3205 6200 0.43 3272
1L-18A 50029221450100 WAG 490100 A (-5978 - -5941)4/5/2021 1776 SBHP 137 5716.99 4191 6200 0.44 4404
1L-19 50029220490000 O 490100 AC (-5948 - -5967),
(-6015 - -6029),
(-5832 - -5839),
12/26/2021 4800 SBHP 154 5814.12 3220 6200 0.35 3355
1L-29 50029221570000 O 490100 AC (-6039 - -6056),
(-6102 - -6106)
10/21/2021 4488 SBHP 146 5704.72 2935 6200 0.44 3153
1M-17 50029230580000 O 490100 C PA'd 3/18/2021 99999 SBHP 144 6474.79 2301 6200 0.469 2172
1Q-01 50029212470000 WAG 490100 AC (-6153 - -6159),
(-6241 - -6272),
(-6281 - -6284),
(-6447 - -6501)
12/18/2021 99999 SBHP 150 6282.88 3628 6200 0.439 3592
1Q-02B 50029212480200 WAG 490100 AC (-6608 - -6672)2/1/2021 244 SBHP 130 6430.59 4432 6200 0.436 4331
1Q-05 50029212330000 O 490100 AC (-5964 - -6008),
(-6035 - -6047),
(-6182 - -6196),
(-6204 - -6234),
(-6277 - -6285)
1/24/2021 8007 SBHP 157 6265.55 3669 6200 0.41 3642
1Q-10 50029212150000 O 490100 AC (-5892 - -5953),
(-5993 - -6005),
(-6128 - -6146),
(-6154 - -6173),
(-6208 - -6217)
1/25/2021 2999 SBHP 157 6187.06 3155 6200 0.434 3161
1Q-15 50029213080000 O 490100 A (-6068 - -6085),
(-6160 - -6166)
1/21/2021 176 SBHP 154 6183.81 1457 6200 0.035 1458
1Q-20A 50029225890100 O 490100 A (-6119 - -6121),
(-6164 - -6178)
8/27/2021 15979 SBHP 155 6120.12 3795 6200 0.398 3827
1Q-21 50029225910000 O 490100 AC (-6509 - -6532)1/28/2021 99999 SBHP 157 6294.3 3385 6200 0.368 3350
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 24
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
1Q-26 50029225900000 O 490100 C (-6168 - -6196),
(-5929 - -5941),
(-5941 - -5961),
(-5997 - -6011)
1/25/2021 1361 SBHP 150 6003.5 3266 6200 0.422 3349
1R-10 50029213510000 WAG 490100 AC (-6415 - -6431),
(-6435 - -6454),
(-6471 - -6476),
(-6507 - -6512)
5/29/2021 247 SBHP 129 6404.27 4036 6200 0.45 3944
1R-14 50029213860000 O 490100 A (-6485 - -6513),
(-6642 - -6648),
(-6651 - -6678),
(-6731 - -6737)
1/11/2021 429 SBHP 159 6582.73 2536 6200 0.328 2410
1R-14 50029213860000 O 490100 A (-6485 - -6513),
(-6642 - -6648),
(-6651 - -6678),
(-6731 - -6737)
6/22/2021 4196 SBHP 159 6582.73 2570 6200 0.357 2433
1Y-05 50029209660000 WAG 490100 A (-5872 - -5951),
(-6062 - -6065),
(-6074 - -6091),
(-6107 - -6117)
5/8/2021 231 SBHP 134 5995.93 3496 6200 0.437 3585
1Y-07 50029209500000 WAG 490100 A (-5830 - -5910),
(-5925 - -5937),
(-6017 - -6021),
(-6029 - -6053),
(-6067 - -6078)
4/26/2021 25590 SBHP 141 6037.5 3077 6200 0.435 3148
1Y-09 50029209350000 WAG 490100 A (-5775 - -5848),
(-5858 - -5861),
(-5966 - -5985),
(-5996 - -6008),
(-6008 - -6016)
9/3/2021 185 SBHP 130 5937.32 3506 6200 0.446 3623
1Y-15A 50029209190100 O 490100 AC (-5899 - -5906),
(-5934 - -5949)
10/25/2021 8713 SBHP 147 5668.88 2722 6200 0.35 2908
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 25
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
1Y-26A 50029218530100 O 490100 AC (-5963 - -5967),
(-5974 - -5991),
(-6001 - -6022)
8/31/2021 5657 SBHP 150 5697.33 3262 6200 0.33 3428
1Y-30 50029218510000 O 490100 AC (-6001 - -6005),
(-6053 - -6068),
(-6093 - -6105)
12/4/2021 3446 SBHP 157 6012.62 3133 6200 0.436 3215
2A-13 50103200390000 O 490100 A (-5736 - -5776),
(-5843 - -5885),
(-5924 - -5931)
4/20/2021 477 PBU 148 5483.05 2202 6200 0.35 2453
2A-14 50103200400000 O 490100 AC (-5747 - -5799),
(-5851 - -5859)
1/7/2021 85 SBHP 159 5824.18 2299 6200 0.35 2431
2C-02 50029209720000 WAG 490100 A (-5815 - -5819),
(-5829 - -5849),
(-5873 - -5880)
5/16/2021 96 SBHP 121 5786.99 4436 6200 0.35 4581
2C-16 50029212180000 O 490100 C (-5738 - -5739),
(-5607 - -5609),
(-5694 - -5707),
(-5790 - -5790),
(-5836 - -5853),
(-5813 - -5814),
(-5814 - -5815)
1/29/2021 1520 SBHP 155 5653.58 2257 6200 0.35 2448
2C-16 50029212180000 O 490100 A (-5738 - -5739),
(-5607 - -5609),
(-5694 - -5707),
(-5790 - -5790),
(-5836 - -5853),
(-5813 - -5814),
(-5814 - -5815)
1/29/2021 1520 PBU 155 5756.82 2569 6200 0.35 2724
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 26
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
2D-11 50029211340000 WAG 490100 A (-5877 - -5878),
(-5880 - -5881),
(-5903 - -5904),
(-5908 - -5909),
(-5912 - -5913),
(-5913 - -5914),
(-5920 - -5921),
(-5934 - -5936),
(-5941 - -5942)
12/6/2021 37233 SBHP 125 5909.13 2641 6200 0.1 2670
2E-02 50029235170000 WI 490100 A (-6260 - -6131)1/30/2021 2816 SBHP 143 5784.47 4724 6200 0.44 4907
2E-03 50029235090000 WI 490100 A (-6047 - -6063),
(-6054 - -6068),
(-6072 - -6106)
4/20/2021 669 SBHP 142 6031.8 4927 6200 0.45 5003
2E-10 50029212460000 WI 490100 A (-5907 - -5927),
(-5949 - -5957),
(-5986 - -5994)
4/19/2021 6927 SBHP 131 5897.78 3418 6200 0.35 3524
2E-12 50029212270000 WI 490100 A (-5888 - -5903),
(-5920 - -5946),
(-5958 - -5963)
12/5/2021 26450 SBHP 122 5925.68 2834 6200 0.38 2938
2E-14 50029212140000 WI 490100 A (-5898 - -5914),
(-5924 - -5946),
(-5954 - -5963)
10/30/2021 4611 SBHP 121 5930.23 3450 6200 0.46 3574
2F-04 50029210650000 WAG 490100 A (-5823 - -5831),
(-5842 - -5870)
10/15/2021 26055 SBHP 126 5870.25 4652 6200 0.44 4797
2F-14 50029210350000 WAG 490100 A (-5888 - -5897),
(-5916 - -5934)
3/12/2021 16633 SBHP 109 5911.92 4073 6200 0.29 4157
2F-14 50029210350000 WAG 490100 A (-5888 - -5897),
(-5916 - -5934)
8/15/2021 20375 SBHP 142 5728.81 3984 6200 0.44 4191
2F-16 50029210520000 WAG 490100 AC (-5837 - -5851),
(-5859 - -5904)
12/3/2021 5428 SBHP 109 5764.21 4301 6200 0.44 4493
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 27
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
2F-21 50029235250000 WI 490100 A (-6024 - -6040)(-
6041 - -6132)
4/18/2021 10364 SBHP 148 5941.5 4390 6200 0.35 4480
2F-22 50029235300000 O 490100 C (-5948 - -6083)5/6/2021 2238 SBHP 152 5892.97 2442 6200 0.44 2577
2G-01 50029211500000 WAG 490100 A (-5944 - -5951),
(-5966 - -5986)
5/9/2021 238 SBHP 97 5965.6 4424 6200 0.45 4529
2H-12 50103200530000 O 490100 AC (-5874 - -5889),
(-5975 - -5997)
5/13/2021 2188 SBHP 160 5910.98 2756 6200 0.49 2898
2K-12 50103201090000 WAG 490100 A (-6052 - -6081),
(-6027 - -6038)
5/3/2021 838 SBHP 94 6032.44 4523 6200 0.44 4597
2K-23 50103201250000 WAG 490100 A (-6095 - -6115)5/8/2021 175 SBHP 102 6088.94 5054 6200 0.44 5103
2M-06 50103201760000 WAG 490100 AC (-5829 - -5857)4/13/2021 83 SBHP 125 5838.5 4314 6200 0.443 4474
2M-13 50103201610000 O 490100 A (-5798 - -5811),
(-5811 - -5824)
5/19/2021 2094 SBHP 153 5811.04 3111 6200 0.43 3278
2M-17 50103201500000 WAG 490100 AC (-6005 - -6020),
(-6020 - -6028),
(-6028 - -6030)
4/21/2021 852 SBHP 119 5988.14 4298 6200 0.42 4387
2M-19 50103201580000 WAG 490100 AC (-5826 - -5838),
(-5838 - -5850)
8/19/2021 2882 SBHP 127 5810.78 3679 6200 0.44 3850
2M-22 50103201700000 O 490100 A (-6011 - -6021)4/12/2021 977 SBHP 160 5990.39 3582 6200 0.43 3672
2M-26 50103201720000 WAG 490100 AC (-6006 - -6031),
(-5986 - -5997)
4/17/2021 90 SBHP 121 5988.62 4415 6200 0.45 4510
2M-27 50103201750000 WAG 490100 A (-5915 - -5924),
(-5938 - -5950),
(-5950 - -5965)
8/18/2021 2856 SBHP 159 5938.77 4047 6200 0.44 4162
2M-30 50103201800000 WAG 490100 A (-5949 - -5963),
(-5963 - -5979)
5/3/2021 286 SBHP 121 5947.44 4232 6200 0.45 4346
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 28
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
2M-34 50103202420000 WAG 490100 AC (-6129 - -6140),
(-6140 - -6142),
(-6127 - -6129),
(-6075 - -6088)
4/30/2021 399 SBHP 119 6074.61 4274 6200 0.45 4330
2M-35 50103202430000 WAG 490100 A (-6150 - -6169),
(-6109 - -6125),
(-6125 - -6128)
7/7/2021 28714 SBHP 147 6131.13 4447 6200 0.44 4477
2T-19 50103202140000 O 490100 AC (-5830 - -5835),
(-5805 - -5816)
10/20/2021 3562 SBHP 158 5837.72 2778 6200 0.35 2905
2T-30 50103202190000 O 490100 A (-5711 - -5726)5/13/2021 792 PBU 153 5545.64 3466 6200 0.35 3695
2T-32A 50103202180100 WI 490100 A (-5693 - -5699)5/18/2021 248 SBHP 150 5602.58 4299 6200 0.35 4508
2T-40 50103205280000 O 490100 A (-5731 - -5740),
(-6991 - -7008),
(-6108 - -6124),
(-6497 - -6514)
5/6/2021 60 SBHP 146 5393.48 1795 6200 0.35 2077
2V-11 50029213110000 O 490100 AC (-5651 - -5667),
(-5668 - -5686),
(-5693 - -5696),
(-5701 - -5706),
(-5789 - -5804),
(-5817 - -5844)
10/3/2021 1247 SBHP 160 5742.46 2577 6200 0.458 2787
2W-02 50029212790000 WAG 490100 C (-5769 - -5821),
(-5915 - -5966),
(-6002 - -6012)
10/18/2021 299 SBHP 126 5798.69 3246 6200 0.35 3386
2W-04 50029212750000 WAG 490100 C (-5698 - -5743),
(-5753 - -5761),
(-5858 - -5868),
(-5876 - -5904),
(-5957 - -5964)
10/28/2021 99 SBHP 123 5720.26 2670 6200 0.35 2838
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 29
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
2W-04 50029212750000 WAG 490100 A (-5698 - -5743),
(-5753 - -5761),
(-5858 - -5868),
(-5876 - -5904),
(-5957 - -5964)
10/29/2021 117 PFO 123 5795.99 2564 6200 0.35 2705
2W-05 50029212080000 WAG 490100 AC (-5711 - -5822),
(-5869 - -5872),
(-5996 - -6003),
(-6033 - -6035),
(-6058 - -6061)
10/29/2021 40286 SBHP 127 5765.57 3507 6200 0.35 3659
2W-09 50029212350000 WAG 490100 A (-5710 - -5796),
(-5817 - -5823),
(-5920 - -5964)
8/25/2021 20184 SBHP 136 5592.17 2837 6200 0.35 3050
2W-12 50029212400000 O 490100 A (-5793 - -5795),
(-5795 - -5816)
5/12/2021 101 SBHP 154 5993.55 2495 6200 0.35 2567
2W-13 50029212520000 O 490100 A (-5787 - -5815),
(-5845 - -5849),
(-5960 - -6006),
(-6020 - -6024),
(-6050 - -6055)
2/17/2021 211 SBHP 153 6014.44 2824 6200 0.334 2886
2W-15 50029212540000 O 490100 A (-5747 - -5801),
(-5811 - -5815),
(-5907 - -5959)
11/22/2021 1246 PFO 154 5843.95 3174 6200 0.35 3299
2W-17 50029233700000 O 490100 AC (-5889 - -5912),
(-5948 - -5980)
5/4/2021 648 PBU 156 5564.14 2215 6200 0.35 2438
2X-18 50029226080000 O 490100 AC (-5902 - -5918),
(-5940 - -5954)
9/11/2021 880 SBHP 161 5757.94 2532 6200 0.447 2730
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 30
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
2Z-04 50029209650000 WAG 490100 A (-5776 - -5832),
(-5956 - -5959),
(-5969 - -5988),
(-6009 - -6014),
(-6017 - -6020)
5/20/2021 300 SBHP 121 5987.89 4466 6200 0.35 4540
3A-18 50029226920000 O 490100 AC (-6069 - -6094)1/10/2021 87 SBHP 152 5999.57 2657 6200 0.431 2743
3C-11A 50029213570100 O 490100 A (-6335 - -6344),
(-6412 - -6429)
8/12/2021 2105 PBU 152 6176.48 2693 6200 0.35 2701
3C-13 50029214240000 O 490100 A (-6332 - -6346),
(-6468 - -6502),
(-6518 - -6527),
(-6555 - -6561)
6/6/2021 10268 SBHP 153 6272.08 2218 6200 0.35 2193
3C-17 50029233890000 O 490100 A (-6445 - -6463),
(-6444 - -6445),
(-6409 - -6416)
11/19/2021 99999 SBHP 153 6268.85 4316 6200 0.53 4280
3F-01 50029214460000 O 490100 C (-5694 - -5800),
(-5937 - -5941),
(-5944 - -5972),
(-5992 - -6012)
3/14/2021 92 SBHP 152 5717.82 2422 6200 0.385 2608
3F-02 50029214470000 O 490100 A (-5748 - -5842),
(-5974 - -5981),
(-6004 - -6006),
(-6023 - -6056)
12/6/2021 1318 SBHP 148 5690.74 2821 6200 0.554 3103
3F-03 50029214480000 WAG 490100 AC (-5919 - -5952),
(-5969 - -5986),
(-5995 - -6001)
11/19/2021 289 EXRT1 127 5699.72 3251 6200 0.443 3473
3F-04 50029214490000 WAG 490100 AC (-5968 - -6001),
(-6017 - -6049)
11/19/2021 289 EXRT1 133 5736.91 3917 6200 0.443 4122
3F-08 50029214640000 WAG 490100 C (-5902 - -5931),
(-5944 - -5977)
3/13/2021 97 SBHP 131 5818.05 3017 6200 0.438 3184
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 31
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3F-08 50029214640000 WAG 490100 A (-5902 - -5931),
(-5944 - -5977)
3/15/2021 97 PFO 131 5855.67 3620 6200 0.438 3771
3F-13A 50029214990100 O 490100 A (-5991 - -6003)9/11/2021 1356 SBHP 158 5934.45 3601 6200 0.419 3712
3G-02 50103201460000 O 490100 A (-5730 - -5764)11/6/2021 163 SBHP 155 5712.58 2772 6200 0.44 2986
3G-24 50103201450000 WAG 490100 A (-5749 - -5778)8/22/2021 20632 SBHP 117 5764.63 3484 6200 0.43 3671
3G-24 50103201450000 WAG 490100 A (-5749 - -5778)11/16/2021 22677 SBHP 119 5744.91 3505 6200 0.45 3710
3H-01A 50103200840100 O 490100 A (-5839 - -5911),
(-5835 - -5919)
8/16/2021 312 SBHP 151 5685.22 3270 6200 0.42 3486
3H-12A 50103200880100 WAG 490100 A (-5921 - -5933)7/30/2021 48624 SBHP 137 5814.96 3164 6200 0.43 3330
3H-14B 50103200920200 O 490100 A (-5903 - -5904),
(-6112 - -6116)
3/14/2021 4389 SBHP 143 5657.24 3643 6200 0.35 3833
3H-14B 50103200920200 O 490100 A (-5903 - -5904),
(-6112 - -6116)
7/7/2021 371 SBHP 148 5782.72 3523 6200 0.429 3702
3H-20 50103200930000 O 490100 A (-6005 - -6008),
(-6015 - -6019),
(-6029 - -6043),
(-6043 - -6057)
1/26/2021 13272 SBHP 145 5789.56 4024 6200 0.57 4258
3H-20 50103200930000 O 490100 A (-6005 - -6008),
(-6015 - -6019),
(-6029 - -6043),
(-6043 - -6057)
7/26/2021 17616 SBHP 145 5759.5 4267 6200 0.461 4470
3H-20 50103200930000 O 490100 A (-6005 - -6008),
(-6015 - -6019),
(-6029 - -6043),
(-6043 - -6057)
12/10/2021 20926 SBHP 143 5789.56 4310 6200 0.54 4532
3H-24 50103202350000 WI 490100 AC (-5924 - -5940),
(-5948 - -5972)
11/8/2021 3309 EXRT1 150 5922.78 3815 6200 0.443 3938
3H-26 50103202080000 O 490100 AC (-5883 - -5912)7/3/2021 14200 SBHP 149 5700.9 2671 6200 0.439 2890
3H-31A 50103202050100 O 490100 A (-6004 - -6017)7/21/2021 5832 SBHP 132 5838.38 3917 6200 0.44 4076
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 32
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3H-32 50103203220000 O 490100 AC (-5867 - -5881),
(-5881 - -5895),
(-5883 - -5898),
(-5897 - -5882),
(-5898 - -5897),
(-5898 - -5907),
(-5900 - -5902),
(-5900 - -5898)
10/31/2021 129 SBHP 152 5747.34 2035 6200 0.43 2230
3H-35 50103208050000 WAG 490100 AC (-5849 - -5860)12/12/2021 98 SBHP 136 5738.83 2799 6200 0.44 3002
3I-14 50029215670000 WI 490100 A (-6161 - -6176),
(-6223 - -6228),
(-6132 - -6136),
(-6136 - -6139),
(-6136 - -6136)
6/24/2021 5740 EXRT1 155 6124.85 4866 6200 0.443 4899
3I-16 50029219200000 WI 490100 A (-6019 - -6045)1/6/2021 9230 EXRT1 157 5965.62 4592 6200 0.443 4696
3I-17 50029219220000 O 490100 A (-6141 - -6166)1/20/2021 7464 SBHP 153 5988.25 4643 6200 0.44 4736
3J-06 50029214370000 O 490100 A (-6152 - -6163),
(-6333 - -6362)
1/27/2021 653.5 PBU 154 6216.74 2606 6200 0.4 2599
3K-02 50029216010000 WI 490100 A (-6538 - -6540),
(-6502 - -6504),
(-6502 - -6502),
(-6504 - -6505),
(-6505 - -6509),
(-6509 - -6509),
(-6509 - -6511),
(-6517 - -6519),
(-6519 - -6520),
(-6520 - -6528),
(-6528 - -6528),
(-6528 - -6531),
(-6531 - -6531),
(-6531 - -6533),
(-6533 - -6538)
4/17/2021 64265 EXRT1 122 6495.54 4022 6200 0.434 3894
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 33
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3K-04 50029216030000 WI 490100 A (-6617 - -6620),
(-6533 - -6533),
(-6533 - -6537),
(-6537 - -6537),
(-6537 - -6538),
(-6538 - -6539),
(-6539 - -6541),
(-6547 - -6560),
(-6560 - -6561),
(-6561 - -6565),
(-6565 - -6574),
(-6574 - -6574),
(-6574 - -6575),
(-6575 - -6576),
(-6576 - -6578),
(-6578 - -6585)
4/17/2021 66378.1 EXRT1 127 6493.61 4046 6200 0.434 3919
3K-20 50029230190000 O 490100 A (-6567 - -6584),
(-6540 - -6549),
(-6549 - -6556)
3/17/2021 15525 SBHP 146 6199.82 1946 6200 0.36 1946
3M-05 50029217060000 O 490100 A (-6146 - -6148),
(-6152 - -6154),
(-6112 - -6116),
(-6116 - -6118),
(-6118 - -6140),
(-6140 - -6141)
10/9/2021 147 SBHP 155 6131 3174 6200 0.433 3204
3M-14A 50029217260100 O 490100 A (-5828 - -6206)3/9/2021 637 SBHP 148 5828 3704 6200 0.46 3875
3M-19 50029217370000 O 490100 AC (-6149 - -6149),
(-6153 - -6185),
(-6143 - -6144),
(-6144 - -6146),
(-6146 - -6147),
(-6147 - -6149)
4/12/2021 19929 SBHP 156 6123.43 4030 6200 0.438 4064
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 34
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3N-02A 50029215270100 O 490100 AC (-6255 - -6265),
(-6372 - -6398),
(-6358 - -6361),
(-6361 - -6365),
(-6361 - -6361)
1/14/2021 1638 SBHP 156 6199.69 4288 6200 0.438 4288
3N-04 50029215290000 WI 490100 AC (-6251 - -6257),
(-6263 - -6269),
(-6242 - -6243),
(-6243 - -6244),
(-6244 - -6245),
(-6245 - -6249)
3/2/2021 43607 EXRT1 120 6206.62 4623 6200 0.434 4620
3N-04 50029215290000 WI 490100 AC (-6251 - -6257),
(-6263 - -6269),
(-6242 - -6243),
(-6243 - -6244),
(-6244 - -6245),
(-6245 - -6249)
3/30/2021 44288.6 EXRT1 120 6206.62 4625 6200 0.434 4622
3N-05 50029215370000 WI 490100 A (-6164 - -6185),
(-6123 - -6124),
(-6124 - -6127),
(-6134 - -6142),
(-6142 - -6143),
(-6143 - -6144),
(-6144 - -6148)
3/2/2021 22899 EXRT1 120 6115.96 4352 6200 0.434 4388
3N-05 50029215370000 WI 490100 A (-6164 - -6185),
(-6123 - -6124),
(-6124 - -6127),
(-6134 - -6142),
(-6142 - -6143),
(-6143 - -6144),
(-6144 - -6148)
3/30/2021 23580.5 EXRT1 120 6115.96 4252 6200 0.434 4288
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 35
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3N-05 50029215370000 WI 490100 A (-6164 - -6185),
(-6123 - -6124),
(-6124 - -6127),
(-6134 - -6142),
(-6142 - -6143),
(-6143 - -6144),
(-6144 - -6148)
10/28/2021 28670 SBHP 130 6130.78 4044 6200 0.434 4074
3O-05 50029218390000 WAG 490100 A (-6643 - -6658),
(-6615 - -6631)
1/5/2021 74 SBHP 108 6602.8 5462 6200 0.45 5281
3O-12 50029218040000 WI 490100 AC (-6607 - -6626),
(-6571 - -6590)
1/6/2021 99 SBHP 114 6510.58 5308 6200 0.46 5165
3O-15 50029217970000 O 490100 A (-6416 - -6430),
(-6388 - -6402)
1/25/2021 5952 SBHP 149 6124.91 4560 6200 0.45 4594
3O-17 50029217950000 WAG 490100 A (-6575 - -6590),
(-6533 - -6552)
1/7/2021 123 SBHP 114 6522.53 4869 6200 0.46 4721
3Q-01 50029222200000 WAG 490100 A (-6464 - -6509)1/1/2021 7192 EXRT1 127 6464.32 3887 6200 0.434 3772
3Q-01 50029222200000 WAG 490100 A (-6464 - -6509)3/1/2021 8636 EXRT1 127 6464.32 3814 6200 0.434 3699
3Q-01 50029222200000 WAG 490100 A (-6464 - -6509)3/30/2021 9332.1 EXRT1 127 6464.32 3803 6200 0.434 3688
3Q-01 50029222200000 WAG 490100 A (-6464 - -6509)5/10/2021 10310 SBHP 127 6465.96 3768 6200 0.454 3647
3Q-04 50029222190000 O 490100 A (-6431 - -6438),
(-6438 - -6448),
(-6451 - -6485)
11/24/2021 23000 SBHP 142 5347.49 3866 6200 0.63 4403
3Q-12 50029216770000 WAG 490100 AC (-6383 - -6384),
(-6387 - -6388),
(-6390 - -6391),
(-6411 - -6436)
1/1/2021 7230 EXRT1 120 6383.37 4651 6200 0.434 4571
3Q-12 50029216770000 WAG 490100 AC (-6383 - -6384),
(-6387 - -6388),
(-6390 - -6391),
(-6411 - -6436)
3/1/2021 8647 EXRT1 120 6383.37 4741 6200 0.434 4661
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 36
6. Oil Gravity:
0.91 (water = 1.0)
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 ftTVDSS
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)
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3Q-12 50029216770000 WAG 490100 A (-6383 - -6384),
(-6387 - -6388),
(-6390 - -6391),
(-6411 - -6436)
3/30/2021 9357.7 EXRT1 127 6383.37 4355 6200 0.434 4275
3S-08C 50103204500300 O 490100 C (-5788 - -5788),
(-5792 - -5792),
(-5801 - -5800),
(-5805 - -5805),
(-5805 - -5805),
(-5807 - -5807),
(-5807 - -5807),
(-5808 - -5808),
(-5808 - -5808),
(-5809 - -5809),
(-5813 - -5813),
(-5814 - -5815)
4/4/2021 4591 SBHP 153 5756.95 2551 6200 0.304 2686
3S-24A 50103204560100 O 490100 C (-5841 - -5857)8/24/2021 42744 SBHP 135 5171.78 2157 6200 0.44 2609
Printed Name Carlotta Chernoff Date
23. All tests reported herein were made in accordance with 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.
Signature Title Manager, GKA Asset Development
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Kuparuk Oil Pool 37
March 9, 2022
Page left blank intentionally.
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Kuparuk River Oil Pool – Proposed Injection Profile Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 4, Conservation Order No. 198B, ConocoPhillips Alaska, Inc., operator of the Kuparuk River
Oil Pool, is hereby submitting the proposed injection profile survey plan for 2022.
There were eight injection surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2021 (Attachment 5). In
2022, we expect to conduct approximately 10 injection surveys, including initial surveys for new wells prior to initial
sustained injection.
Additionally, Attachment 6 provides data for the five production surveys conducted in 2021.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
Page left blank intentionally.
KUPARUK RIVER UNIT
KUPARUK RIVER OIL POOL
CONSERVATION ORDER 198B
RULE 4 - INJECTIVITY PROFILES
2021 ANNUAL SUBMITTAL
WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION
NUMBER NUMBER INITIAL PROFILE/PROFILE/PROFILE/COMPLETION TAKING BWPD /
50-INJECTION SURVEY SURVEY SURVEY TYPE INJECTION MSCFD
1G-02 0292081300 - 00 10/29/85 02/20/21 SPINNER A/C SPLITS DUAL SELECTIVE AC 1898
1Q-02B 0292124802 - 01 11/09/05 04/29/21 SPINNER A/C SPLITS SINGLE AC 466
256
1Q-08A 0292122501 - 02 02/27/99 04/30/21 SPINNER A/C SPLITS SINGLE AC 1497
346
1R-08 0292133300 - 03 09/30/85 05/03/21 SPINNER A/C SPLITS SINGLE AC 800
400
1R-13 0292138500 - 04 02/08/88 06/27/21 SPINNER A/C SPLITS SINGLE SELECTIVE AC 2600
242
3F-04 0292144900 - 05 05/04/86 07/24/21 SPINNER A/C SPLITS SINGLE AC 4515
625
3B-01 0292131800 - 06 01/23/87 10/12/21 SPINNER A/C SPLITS SINGLE SELECTIVE A 2700
100
1Q-09 0292120900 - 07 07/29/96 11/16/21 SPINNER A/C SPLITS SINGLE SELECTIVE AC 1500
210
8 >>Total IPROF Count for 2021
Attachment 5
GKA Annual Surveillance Report Kuparuk Oil Pool 41
Attachment 6
KUPARUK RIVER UNIT
KUPARUK RIVER OIL POOL
CONSERVATION ORDER 432
RULE 9 - PRODUCTIVITY PROFILES
2021 ANNUAL SUBMITTAL
WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES PRODUCTION
NUMBER NUMBER INITIAL PROFILE/PROFILE/PROFILE/COMPLETION PROD-OIL WATER GAS
50-PRODUCTION SURVEY SURVEY SURVEY TYPE UCING BOPD BWPD MSCFD
1Q-15 0292130800 - 00 07/31/85 04/28/21 SPINNER A/C SPLITS SINGLE A 58 270 93
1R-20 0292220700 - 01 05/31/92 06/02/21 SPINNER A/C SPLITS SINGLE SELECTIVE AC 287 2043 368
A 20 143 26
1Y-17 0292236800 - 02 03/31/94 07/01/21 SPINNER A/C SPLITS SINGLE SELECTIVE AC 53 3547 311
53 689 238
2M-11 1032015900 - 03 04/30/92 08/27/21 SPINNER A/C SPLITS SINGLE AC 74 1616 162
69 1609 153
1Y-06A 0292095801 - 04 9/30/1997 11/1/2021 SPINNER A/C SPLITS SINGLE AC 160 3860 970
130 368 425
5 >>Total PPROF Count for 2021
Note:
GKA Annual Surveillance Report Kuparuk Oil Pool 42
Attachment 7
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
Miscible Injectant Composition
Miscible Injectant (MI) is manufactured at two Central Processing Facilities, CPF‐1 and CPF‐2. The compositions
of both the lean gas and enriching fluids (NGLs) are measured periodically throughout the year to ensure that
the MI meets the design Minimum Miscible Pressure (MMP). Detailed compositional analyses and MMP
(target of 3300 psia) of the MI from each CPF is provided in tabular form below. A lower MMP implies a higher
NGL content in the MI.
Most of the Prudhoe Bay imported NGLs were blended to MI at CPF2 in 2021. NGL imports from Prudhoe Bay ceased
in September of 2021, after which “indigenous” Kuparuk NGLs were the only enrichment source for blending. The
resulting leaner injection composition marked the transition from MWAG (miscible water alternating gas) to an
EWAG (enriched water alternating gas) tertiary flood.
GKA Annual Surveillance Report Kuparuk Oil Pool 43
Attachment 8
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
LSEOR Development Plan
During 2021, the Greater Kuparuk Area (GKA) averaged 7,865 BPD of indigenous and 3,483 BPD of imported NGLs
from Prudhoe Bay for an annual average of 109 million standard cubic feet per day (MMSCFD) of miscible injectant
(MI) manufactured, 53.4 MMSCFD of which was used for downhole injection for tertiary recovery. NGL imports
from Prudhoe Bay ceased in August of 2021. Of the total MI production in 2021, 50.7 MMSCFD was injected into
the main Kuparuk Field. Within the main Kuparuk Field, 5.4 MMSCFD was allocated for SSEOR and SSEROX, and
45.3 MMSCFD was allocated for the LSEOR and LSEORX expansion which included drillsites 1F, 1Q, 2A, 2B, 2C, 2G
2H, 2K, 2M, 2T, 3F, 1B, 1C, 1D, 1E, 1L, 2S, 3B, 3G, 3O, and 3Q.
GKA Annual Surveillance Report Kuparuk Oil Pool 44
MELTWATER
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Meltwater Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 10, Conservation Order No. 456A (CO 456A) and Rule 9, Area Injection Order 21B (AIO
21B), ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance
report on the Meltwater Oil Pool. This report documents the required information pertinent to the field
development and enhanced recovery operations from January through December 2021. The following is an outline
of the information provided:
a) Progress of EOR project and reservoir management summary (Attachment 1) per CO 456A Rule 10 Item A
and AIO 21B Rule 9 Item A.
b) Voidage balance, by month, for produced and inject ed fluids (Attachments 2 and 3) per CO 456A Rule 10
Item B and AIO 21B Rule 9 Item B.
c) Analysis of reservoir pressure surveys taken in 2021 (Attachment 4) per CO 456A Rule 10 Item C and AIO
21C Rule 9 Item C.
d) Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2021
(Attachment 5) per CO 456A Rule 10 Item D and AIO 21B Rule 9 Item D, F and H.
e) Results of well allocation and test evaluation for Rule 7, and any other sp ecial monitoring (Attachment 6)
per CO 456A Rule 10 Item E and AIO 21B Rule 9 Item E.
f) Results of inner and outer annulus monitoring for all wells within a ¼-mile radius of a Meltwater injector
(Attachment 7) per AIO 21B Rule 9 Item G.
g) Development Plan and Operation Review (Attachments 8 and 9) per CO 456A Rule 10 Item F and AIO 21B
Rule 9 Items I and J.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 1
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of EOR Project and Reservoir Management Summary
Background
In 2001, ConocoPhillips Alaska, Inc. (CPAI) received approvals for formation of the Meltwater Oil Pool in the
Kuparuk River Unit, an Area Injection Order for Meltwater, expansion of the Kuparuk River Unit, and
formation of the Meltwater Participating Area. The Meltwater Pool Rules and Area Injection Order were
approved on August 1, 2001. The Unit Expansion and Participating area were approved effective June 1,
2001. The Area Injection Order was modified on January 29, 2013 and again on October 8, 2015.
Miscible gas injection (MI) began in January 2002 and the miscible water -alternating gas (MWAG) process
was implemented in May 2003. The Meltwater MWAG process used Kuparuk spec miscible injectant (MI). In
2009, the water injection line to Meltwater was proactively shut-in due to internal corrosion and the field
was converted to MI flood only. In July 2014, natural gas liquids (NGLs) imported from the Prudhoe Bay Field
Central Gas Facility into the Greater Kuparuk Area ceased and the Meltwater field was subsequently
converted to lean gas injection (LGI) only.
In September 2018, NGL imports resumed and the field was returned to miscible injectant (MI) flood only
after the first phase of injection line work was completed in November 2018. This period of MI continued
until August 2019, after which the injection line was fully converted to water injection. Over the next year
injection rates in Meltwater continued to decline to the point where it was unable to provide support to
producers. Water injection pressures is limited by the sandface pressure limit that have been imposed for
2P injectors. A study was conducted in 2021 to evaluate the economic feasibility of the 2P drillsite, following
which a decision was taken to abandon the Meltwater reservoir and P&A the wells.
The Meltwater field currently has 19 total wells (11 producers and 8 injectors). See Attachment 9 for well
locations.
Progress of EOR Project
Development activities in 2021 followed the plans described in the Pool Rules, Area Injection Order, Unit
Expansion, and Participating Area (PA) applications. Below is a listing of the key events related to the
Meltwater Pool and PA in 2021:
1. As of December 31, 2021,all wells in Meltwater have been shut-in.
2. There are no plans for any further production or injection in Meltwater .
Reservoir Management Summary
Meltwater came on‐line in November of 2001 and has cumulatively produced 20.2 million barrels of oil
(MMBO), 3.7 million barrels of water (MMBW), and 68.9 billion standard cubic feet (BSCF) of gas by year‐
end 2021. MI injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative
injection through year‐end 2020 at Meltwater was 27.6 MMBW and 91.4 BSCF of gas (59.1 BSCF of MI and
32.3 BSCF of lean gas). Water injection ceased in October 2009 when the water injection line had to be
GKA Annual Surveillance Report Meltwater Oil Pool 49
taken out of service due to operational constraints caused by areas of excessive under‐deposit corrosion
pitting. A gas only flood leads to increasing GORs and made the wells uneconomic to produce. Therefore,
CPAI converted Meltwater back to water injection. Currently all the injectors are being operated below the
sandface injection pressure of 3400 psi required by AIO21C. Due to the lower mobility of water in the
reservoir, combined with sandface pressure limitations, overall injection rate of water and voidage
replacement has been challenging. Several of the injectors had to be shut -in due to their inability to inject
below the maximum allowable sandface pressure. The producers were on gas lift before the water injection
conversion. After the conversion, gas was no longer available at the drillsite. After a thorough study on 2P
economics, the decision was taken to shut in 2P and P&A the wells.
Cumulative I/W at Meltwater as of 12/31/2021 was 1.19. Instantaneous I/W’s varied throughout the year
depending on which injectors or producers were on. Average I/W in 20 21 was 0.51 calculated based on total
injected and produced volumes in the year from Meltwater.
Monthly I/W cumulative and rate are shown in Table 1-1 to satisfy AIO21C Rule 9 Item B: ‘reservoir voidage
balance by month of produced and injected fluids’.
Table 1-1. Reservoir voidage balance by month of produced and injected fluids in Meltwater.
Date I/W Cum (RVB/RVB) I/W Rate (RVB/RVB)
1/31/2021 1.191 0.407
2/28/2021 1.191 0.917
3/31/2021 1.191 4.073
4/30/2021 1.189 0.228
5/31/2021 1.189 0.577
6/30/2021 1.189 0.67
7/31/2021 1.188 0.752
8/31/2021 1.188 0.282
9/30/2021 1.187 0.152
10/31/2021 1.187 0
11/30/2021 1.187 0
12/31/2021 1.187 0
GKA Annual Surveillance Report Meltwater Oil Pool 50
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:20,243 68,394 3,723
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 4.5 83.5 0.1 20,247 68,477 3,723
2 2021 2.1 35.5 1.0 20,249 68,513 3,724
3 2021 1.7 10.7 0.9 20,251 68,523 3,725
4 2021 5.8 174.6 1.4 20,257 68,698 3,726
5 2021 9.0 50.9 1.0 20,266 68,749 3,727
6 2021 6.6 33.9 0.5 20,272 68,783 3,728
7 2021 2.8 46.4 0.1 20,275 68,829 3,728
8 2021 7.7 68.4 3.8 20,283 68,898 3,732
9 2021 0.7 10.2 0.2 20,283 68,908 3,732
10 2021 0.0 0.0 0.0 20,283 68,908 3,732
11 2021 0.0 0.0 0.0 20,283 68,908 3,732
12 2021 0.0 0.0 0.0 20,283 68,908 3,732
2021 TOTAL 41 514 9
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:27,024 61,978 3,775
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 6.0 89.5 0.1 27,030 62,067 3,775
2 2021 2.8 38.0 1.1 27,033 62,105 3,776
3 2021 2.3 10.7 0.9 27,035 62,116 3,777
4 2021 7.7 189.7 1.4 27,043 62,306 3,778
5 2021 12.0 50.4 1.1 27,055 62,356 3,779
6 2021 8.8 33.1 0.5 27,064 62,389 3,780
7 2021 3.7 49.5 0.1 27,067 62,439 3,780
8 2021 10.3 70.5 3.9 27,078 62,509 3,784
9 2021 0.9 10.8 0.2 27,079 62,520 3,784
10 2021 0.0 0.0 0.0 27,079 62,520 3,784
11 2021 0.0 0.0 0.0 27,079 62,520 3,784
12 2021 0.0 0.0 0.0 27,079 62,520 3,784
2021 TOTAL 54 542 9
Produced Fluid Volumes
ATTACHMENT 2
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Meltwater Oil Pool 51
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:27,333 32,195 59,119
WATER GAS MI CUM WATER CUM LEAN GAS CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 38.4 0.0 0.0 27,372 32,195 59,119
2 2021 37.8 0.0 0.0 27,410 32,195 59,119
3 2021 55.9 0.0 0.0 27,465 32,195 59,119
4 2021 44.6 0.0 0.0 27,510 32,195 59,119
5 2021 36.1 0.0 0.0 27,546 32,195 59,119
6 2021 28.2 0.0 0.0 27,574 32,195 59,119
7 2021 39.6 0.0 0.0 27,614 32,195 59,119
8 2021 23.6 0.0 0.0 27,638 32,195 59,119
9 2021 1.8 0.0 0.0 27,639 32,195 59,119
10 2021 0.0 0.0 0.0 27,639 32,195 59,119
11 2021 0.0 0.0 0.0 27,639 32,195 59,119
12 2021 0.0 0.0 0.0 27,639 32,195 59,119
2021 TOTAL 306 0 0
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:27,716 35,704 47,295
WATER GAS MI CUM WATER CUM LEAN GAS CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 38.9 0.0 0.0 27,755 35,704 47,295
2 2021 38.3 0.0 0.0 27,793 35,704 47,295
3 2021 56.6 0.0 0.0 27,850 35,704 47,295
4 2021 45.3 0.0 0.0 27,895 35,704 47,295
5 2021 36.6 0.0 0.0 27,932 35,704 47,295
6 2021 28.6 0.0 0.0 27,960 35,704 47,295
7 2021 40.2 0.0 0.0 28,001 35,704 47,295
8 2021 23.9 0.0 0.0 28,025 35,704 47,295
9 2021 1.8 0.0 0.0 28,026 35,704 47,295
10 2021 0.0 0.0 0.0 28,026 35,704 47,295
11 2021 0.0 0.0 0.0 28,026 35,704 47,295
12 2021 0.0 0.0 0.0 28,026 35,704 47,295
2021 TOTAL 310 0 0
Injected Fluid Volumes
ATTACHMENT 3
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Meltwater Oil Pool 52
Attachment 4
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Meltwater Oil Pool 53
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission 333 West
7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Meltwater Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 7, Conservation Order No. 456A and Rule 9 Item C, Area Injection Order 21C,
ConocoPhillips Alaska, Inc., operator of the Meltwater Oil Pool, is hereby submitting the proposed pressure survey
plan for 2022.
One pressure survey was reported for the Meltwater Oil Pool to the AOGCC in 2021. In 2022, we do not expect to
conduct pressure surveys as a decision has been taken to abandon the reservoir.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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6. Oil Gravity:
0.85 (water = 1.0)
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 ftTVDSS
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)
2P-451 50103204020000 O 490140 A (-5113 - -5129)06/20/21 5825 PBU 128 4919 2570 5400 0.320 2724
Printed Name Carlotta Chernoff Date
23. All tests reported herein were made in accordance with 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.
Signature Title Manager, GKA Asset Development
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Meltwater Oil Pool -5400' SS 0.74
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Meltwater Oil Pool 57
March 9, 2022
Attachment 5
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Production Logs and Special Surveys (d, f, h)
This section is meant to fulfill AIO 21C Rule 9 item d ‘results and where appropriate, analysis of production
and injection log surveys, tracer surveys and observation well data or surveys’ and h ‘results of any special
monitoring’.
No special logging was completed in 2021.
MITs performed at Meltwater in 2021 are listed below. This section is meant to fulfill AIO21C Rule 9 item f
‘summary of MIT results’. SW refers to state witnessed tests.
Table 5-2. MITs completed in 2021
Well Date Test Result
2P-441 9/5/2021 CMIT PASS
2P-451 9/4/2021 MITT PASS
GKA Annual Surveillance Report Meltwater Oil Pool 58
Attachment 6
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Well Allocation, Test Evaluation, and Special Monitoring
Well Allocation
Meltwater drillsite 2P facilities were fabricated with a conventional test separator. Test separator backpressure
corrections were applied to wells that experienced greater than 100 psi backpressure over header pressure.
Correction to stock tank barrel conditions were made by applying Meltwater specific pressure corrections, derived
from the PVT analysis of Meltwater North #1 crude oil samples, and API temperature corrections.
Miscible gas was used for injection and gas lift at drillsite 2P through July 2014. From July 2014 forward, lean gas was
used for injection and gas lift until November 2018 when NGL imports resumed and the drillsite was converted back
to miscible gas. From August 2019, gas injection stopped and the drillsite was converted to water injection.
Production volumes were tracked through an automated production monitoring SCADA system (IP.21) utilizing
meters that transmit data in real-time for monitoring. The 2021 Meltwater allocation factors by month are listed
below. Production in 2P stopped after September 2021.
Month Oil Gas Water
Jan-21 0.8834 0.8228 1.0000
Feb-21 0.8921 0.7641 1.0058
Mar-21 0.8934 0.7938 1.0295
Apr-21 0.8786 0.8111 1.0403
May-21 0.8934 0.7866 1.0528
Jun-21 0.8882 0.7839 1.0707
Jul-21 0.8530 0.8497 1.0273
Aug-21 0.8995 0.8442 1.0439
Sep-21 0.8655 0.7968 1.0638
Oct-21 0.0000 0.0000 0.0000
Nov-21 0.0000 0.0000 0.0000
Dec-21 0.0000 0.0000 0.0000
Shallow Gas Special Monitoring
Wells 2P-406, 2P-417, 2P-431, 2P-432, 2P-434, 2P-438, 2P-441, 2P-447, 2P-448A and 2P-451 have a history of
elevated outer annulus (OA) pressures. Based upon the information gathered, and technical analyses completed to
date, it is likely the initial migration of injected fluids out of the Bermuda interval was a result of a large pressure
differential between injectors and producers. This pressure differential was exacerbated by low permeability and
stratigraphic and/or structural discontinuities within the Bermuda interval.
The Operator has continued to monitor OA pressures on a routine basis. There are currently no indications that
injection has occurred out of the Bermuda interval in 2021. Gas sampling was discontinued once water injection was
implemented as sampling of gas will no longer indicate a loss of containment. In addition, the extended bleed of the
outer annulus of well 2P-431 is continuously monitored in an effort to deplete the source charging the outer annulus.
The OA pressure of 2P-432 is also being monitored to understand the dynamics of pressure charging the OA.
2021 IA and OA pressure trends for all wells are included in Attachment 7.
GKA Annual Surveillance Report Meltwater Oil Pool 59
Significant Studies in Progress
This section is meant to include the documentation to satisfy Rule 9 Item E ‘assessment of fracture propagation into
adjacent confining intervals’.
1. No new studies on the fracture propagation into adjacent confining intervals has been completed that
has not previously been reported to the AOGCC.
2. A new Meltwater reservoir management plan was put in place in July 2012 and continued to serve as the
reservoir management strategy through 2021. This reservoir strategy included imposing a well head
injection pressure limit on Meltwater injectors. The sandface injection pressure limit of 3,400 psi imposed
on Meltwater injectors is predicated upon FIT/LOT (For mation Integrity Test / Leak‐off Test) data
obtained from Meltwater wells with production casing set at the top of the Bermuda interval. Since
implementing the reservoir management strategy changes, production and reservoir data continue to be
collected and shared with the AOGCC.
During 2013-2018, all Meltwater outer annuli were part of the semi-annual bleed project that was conducted as a
method to monitor the change in recharge rate over time. Each OA was bled semi-annually with the criteria of either
a 4 hour maximum bleed, fluid returns at surface, or pressure reduction to 50 psi. This semi-annual bleed project
was later discontinued as OA pressures fell and bleeding was performed only when necessary.
GKA Annual Surveillance Report Meltwater Oil Pool 60
Attachment 7
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Monitoring Inner and Outer Annuli
Summary of results of inner and outer annulus monitoring for all production wells, injection wells, and any wells that
are not cemented across the Meltwater Oil Pool and are located within ¼-mile radius of a Meltwater injector.
Information below contains the inner annulus (IA) and outer annulus (OA) pressures for each well , the well head
injection pressure (WHIP) for injection wells, and flowing tubing pressure (FTP) for production wells. Any WHIP above
2,900 PSI is attributed to a shut-in event for that well.
Injectors:
_________________________________________________________________________________
GKA Annual Surveillance Report Meltwater Oil Pool 61
GKA Annual Surveillance Report Meltwater Oil Pool 62
GKA Annual Surveillance Report Meltwater Oil Pool 63
GKA Annual Surveillance Report Meltwater Oil Pool 64
GKA Annual Surveillance Report Meltwater Oil Pool 65
Producers:
__________________________________________________________________________________
GKA Annual Surveillance Report Meltwater Oil Pool 66
GKA Annual Surveillance Report Meltwater Oil Pool 67
GKA Annual Surveillance Report Meltwater Oil Pool 68
GKA Annual Surveillance Report Meltwater Oil Pool 69
GKA Annual Surveillance Report Meltwater Oil Pool 70
GKA Annual Surveillance Report Meltwater Oil Pool 71
Attachment 8
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Development Plan and Operational Review
Development
A detailed study was conducted in 2021 to evaluate the economic feasibility of the 2P drillsite, following
which a decision was taken to abandon the Meltwater reservoir and P&A the wells.
Pipeline Operations
Currently all pipelines to and from 2P drillsite have been temporarily abandoned in place and final abandonment
will be executed in 2022 summer.
Exploration/Delineation
No further exploration work is currently planned for the Bermuda interval.
Surveillance plans for 2022
In accordance with AIO21C Rule 9 Item I the following bullets are key to 2022 reservoir surveillance plans.
• Continuous monitoring of OA pressures through the SCADA system and bleed as necessary, till the
wells are P&A’ed.
GKA Annual Surveillance Report Meltwater Oil Pool 72
Attachment 9
Meltwater Oil Pool
2021 Annual Reservoir Surveillance Report
Map showing Development as of December 31, 2021
GKA Annual Surveillance Report Meltwater Oil Pool 73
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TABASCO
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Tabasco Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 11, Conservation Order No. 435, ConocoPhillips Alaska, Inc., ope rator of the Kuparuk River
Unit, is hereby submitting the annual surveillance report on the Tabasco Oil Pool. This report documents the
required information pertinent to the field development and enhanced recovery operations from January through
December 2021. The following is an outline of the information provided:
a. A summary of the enhanced recovery project (Attachment 1).
b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3).
c. Analysis of reservoir pressure surveys taken in 2021 (Attachment 4).
d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2021
(Attachment 5).
e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment
6).
f. Future development plans (Attachment 7).
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 1
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of the Enhanced Recovery Project
Producers: 9 completed 5 online
Injectors: 3 completed 2 online
Well 2T-204 had its perforations isolated with cement in 2013 due to low productivity and is not economic to
produce at this time. In 2018, one producer was offline due to high watercut. One producer was offline due to a
stuck coiled tubing string from a packer leak repair job. One producer was converted to an injector. As of
December 31, 2021, Tabasco oil pool was producing with five producers and two injectors online. One of the
injectors was shut-in due to high shut-in bottomhole pressure measured in the well.
Water breakthrough has occurred at all producers in the Tabasco Oil Pool. Production and injection logs,
coupled with the structural positions and water breakthrough histories of the producers, suggest that the
water production mechanism is dominated by gravity‐induced slumping and flow through high-permeability facies.
GKA Annual Surveillance Report Tabasco Oil Pool 79
Tabasco produced 355 thousand barrels (MSTB) of oil, 47 million standard cubic feet (MMSCF) of gas and 5.7
million barrels of water (MMBW) during 2021. Water injection was 6 MMBW over the same period. Cumulative
oil, gas, and water production through year‐end 2021 were 21.9 million barrels of oil, 3.6 billion standard cubic
feet of gas, and 119.6 MMBW, respectively. Cumulative water injection through year-end 2021 was 129.8
MMBW. The cumulative year‐end 2021 injection-withdrawal ratio, based on current formation volume factors, is
estimated at 0.90 for Tabasco.
Year‐end 2021 Tabasco well count (Kuparuk River Unit drillsite 2T) was:
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:21,500 3,568 113,883
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 32.2 4.1 487.1 21,532 3,572 114,371
2 2021 30.4 3.7 446.1 21,563 3,576 114,817
3 2021 31.8 4.0 472.4 21,594 3,580 115,289
4 2021 31.8 4.0 498.8 21,626 3,584 115,788
5 2021 29.0 3.8 533.4 21,655 3,587 116,321
6 2021 21.7 3.0 483.2 21,677 3,591 116,804
7 2021 20.9 3.1 461.3 21,698 3,594 117,266
8 2021 27.4 4.1 541.5 21,725 3,598 117,807
9 2021 30.4 4.1 468.3 21,756 3,602 118,275
10 2021 35.4 4.6 480.6 21,791 3,606 118,756
11 2021 29.2 4.0 398.8 21,820 3,610 119,155
12 2021 34.9 4.8 471.7 21,855 3,615 119,627
2021 TOTAL 355 47 5,743
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:22,165 89 107,687
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 34.7 0.0 487.1 22,200 89 108,174
2 2021 32.8 0.0 446.1 22,233 89 108,620
3 2021 34.2 0.0 472.4 22,267 89 109,092
4 2021 34.3 0.0 498.8 22,302 89 109,591
5 2021 31.3 0.0 533.4 22,333 89 110,124
6 2021 23.3 0.0 483.2 22,356 89 110,608
7 2021 22.5 0.0 461.3 22,379 89 111,069
8 2021 29.5 0.0 541.5 22,408 89 111,610
9 2021 32.7 0.0 468.3 22,441 89 112,079
10 2021 38.1 0.0 480.6 22,479 89 112,559
11 2021 31.5 0.0 398.8 22,511 89 112,958
12 2021 37.6 0.0 471.7 22,548 89 113,430
2021 TOTAL 383 0 5,743
Produced Fluid Volumes
ATTACHMENT 2
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Tabasco Oil Pool 80
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:123,864 0 0
WATER GAS MI CUM WATER CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 531.7 0.0 0.0 124,396 0 0
2 2021 413.5 0.0 0.0 124,809 0 0
3 2021 539.4 0.0 0.0 125,348 0 0
4 2021 470.2 0.0 0.0 125,819 0 0
5 2021 513.8 0.0 0.0 126,332 0 0
6 2021 483.4 0.0 0.0 126,816 0 0
7 2021 501.0 0.0 0.0 127,317 0 0
8 2021 519.0 0.0 0.0 127,836 0 0
9 2021 486.4 0.0 0.0 128,322 0 0
10 2021 494.5 0.0 0.0 128,817 0 0
11 2021 494.5 0.0 0.0 129,311 0 0
12 2021 518.0 0.0 0.0 129,829 0 0
2021 TOTAL 5,965 0 0
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:123,864 0 0
WATER GAS MI CUM WATER CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 531.7 0.0 0.0 124,396 0 0
2 2021 413.5 0.0 0.0 124,809 0 0
3 2021 539.4 0.0 0.0 125,348 0 0
4 2021 470.2 0.0 0.0 125,819 0 0
5 2021 513.8 0.0 0.0 126,332 0 0
6 2021 483.4 0.0 0.0 126,816 0 0
7 2021 501.0 0.0 0.0 127,317 0 0
8 2021 519.0 0.0 0.0 127,836 0 0
9 2021 486.4 0.0 0.0 128,322 0 0
10 2021 494.5 0.0 0.0 128,817 0 0
11 2021 494.5 0.0 0.0 129,311 0 0
12 2021 518.0 0.0 0.0 129,829 0 0
2021 TOTAL 5,965 0 0
Injected Fluid Volumes
ATTACHMENT 3
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Tabasco Oil Pool 81
CUM LEAN GAS
CUM LEAN GAS
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Attachment 4
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
There were no pressure surveys run for Tabasco in 2021.
GKA Annual Surveillance Report Tabasco Oil Pool 83
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission 333 West
7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Tabasco Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 8, Conservation Order No. 435A, ConocoPhillips Alaska, Inc., operator of the Tabasco Oil
Pool, is hereby submitting the proposed pressure survey plan for 2021.
No pressure surveys were reported for the Tabasco Oil Pool to the AOGCC in 2021.
No formal pressure surveys are scheduled for 2022. Tabasco producers are all lifted with downhole pumps
equipped with pressure gauges. Surveys may be conducted using ESP pressure gauges should any well be shut in
for an extended period.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 5
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
Production Logs and Special Surveys
Special logging performed at Tabasco in 2021 are listed below in Table 5-1.
Table 5-1. Special logging performed in 2021.
Well Date Test Result
2T-207 06/09/2021 Caliper/Spinner N/A
MITs performed at Tabasco in 2021 are listed below in Table 5-2.
Table 5-2. MITs completed in 2021. This includes both State witnessed (SW) and unwitnessed tests.
Well Date Test Result
2T-215 1/30/2021 MITIA PASS
2T-220 4/22/2021 CMIT PASS
2T-207 5/29/2021 MITIA FAIL
2T-209 6/2/2021 CMIT PASS
2T-210 6/4/2021 MITIA PASS
2T-201 6/18/2021 MITIA PASS
2T-217A 6/18/2021 MITIA PASS
2T-207 8/2/2021 MITT PASS
2T-207 8/16/2021 MITIA PASS
GKA Annual Surveillance Report Tabasco Oil Pool 87
Attachment 6
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Well Allocation
A minimum of two well tests per month are conducted on production wells. Fluid samples are obtained on a
regular basis, and water cut corrections are applied to well tests as required based on subsequent lab analysis.
Generally, good agreement was observed for water cuts comparing phase dynamics and shakeout analysis.
Production volumes are tracked through an automated production monitoring SCADA system (IP.21). In 2002,
Tabasco switched from an allocation factor of 1.0 to floating production allocation factors. Tabasco 2021
production allocation factors were as follows:
Month Oil Gas Water
Jan-21 0.8822 0.8199 1.0171
Feb-21 0.8921 0.7595 1.0022
Mar-21 0.8914 0.7934 1.0418
Apr-21 0.8770 0.7995 1.0401
May-21 0.8889 0.7818 1.0474
Jun-21 0.8886 0.7837 1.0592
Jul-21 0.8796 0.7943 1.0581
Aug-21 0.8990 0.8330 1.0478
Sep-21 0.9170 0.8362 1.0550
Oct-21 0.9004 0.8392 1.0543
Nov-21 0.8976 0.8944 1.0293
Dec-21 0.9127 0.8777 1.0221
GKA Annual Surveillance Report Tabasco Oil Pool 88
Attachment 7
Tabasco Oil Pool
2021 Annual Reservoir Surveillance Report
Development Plans and Operational Review
GKA Annual Surveillance Report Tabasco Oil Pool 89
Tabasco injection-withdrawal ratios are monitored to maintain an instantaneous value of approximately 1.0.
Adjustments to injection and/or production rates are made to achieve this to maintain pressure support for the
Tabasco reservoir and keep gas in solution. The 2021 injection strategy continued replacing voidage by splitting water
injection between two injectors: 2T‐201 and 2T‐217A. 2T-209 was shut-in in 2020 when a high shut-in bottomhole
pressure was measured in the well. The high pressure showed inadequate offtake from the 2T-209 pattern and the
injector was shut-in in an abundance of caution to prevent any out of zone injection. The injection rates in the
remaining injectors (2T-201 and 2T-217A) were increased to offset the loss of injection from 2T-209 to maintain an
I/W of 1.0.
In November 2014, chemical tracers were injected into the two in-service injectors, 2T-201 and 2T-217A. From 2015
to 2017, all active producers were sampled on a regular basis for the presence of these tracers. The concentration
and duration of the chemical tracer breakthrough was used to evaluate heterogeneities within the Tabasco reservoir
and found the majority of current sweep to be taking place in the periphery of the field. This finding was key to the
proposal to convert the 2T-209 from production to injection in 2019.
Waterflood operations continued to be optimized in 2021. The reservoir management strategy is predicated upon
injecting water deep into the central canyon and produce from the periphery. These high permeability facies are
prevalent in the central canyon injectors but not in the peripheral wells. The gravity slumping of the injected water
combined with recovery higher up in the structure leads to a gravity stable waterflood. This has been key in keeping
Tabasco water cut under control and improve overall oil recovery. Among Tabasco producers 2T-218, is approaching
high watercut (> 96%) which in future may make the well uneconomic. To flatten it’s watercut rise, drawdown in 2T -
203 has been increased by ramping up the ESP of the well and diverting some fluids from 218 to 203. As a result 218
watercut has gone down slightly whereas more oil is being recovered from 2T-203. This strategy will be continued in
2022 and further actions will be taken based on the results of this approach.
No additional development drilling wells are planned at this time.
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TARN
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Tarn Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 11, Conservation Order No. 430, ConocoPhillips Alaska, operator of the Kuparuk River
Field, is hereby submitting the annual surveillance report on the Tarn Oil Pool. This report documents the required
information pertinent to the field development and enhanced recovery operations from January through
December 2021. The following is an outline of the information provided:
a. A summary of the enhanced recovery project (Attachment 1).
b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3).
c. Analysis of reservoir pressure surveys taken in 2021 (Attachment 4).
d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2021 (Attachment
5).
e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6).
f. Development Plan and Operational Review (Attachments 7 and 8).
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 1
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of EOR Project and Reservoir Management Summary
Background
In 1998, Arco Alaska, Inc. received approvals for formation of the Tarn Oil Pool in the Kuparuk River Unit, an Area
Injection Order for Tarn, expansion of the Kuparuk River Unit, and formation of the Tarn Participating Area. The
Tarn Pool Rules and Area Injection Order were approved on July 21 and July 20, 1998, respectively. The Unit
Expansion and Participating area were approved effective July 1, 1998.
Construction of the Tarn road, pads, power lines, and pipelines took place in the 1998-1999 winter construction
season. Tarn development drilling commenced in April of 1998. Tarn production began in July 1998 and injection
of miscible injectant (MI) began in November 1998. Tarn switched to a miscible water-alternating gas (MWAG)
recovery process in July 2001.
Progress of EOR Project
The permanent 12” water injection line was completed and brought on‐line in July 2001. This allowed Tarn to
switch from a strictly MI flood to a MWAG recovery process which increases ultimate recovery from the Tarn
reservoir. Water injection capacity has been good, and total fluid injection has been able to match reservoir
voidage.
Through July 2014, the Tarn MWAG process used Kuparuk spec MI injected above the minimum miscibility
pressure. Refer to Section 7 of the Kuparuk Annual Surveillance Report for compositional analysis of the Kuparuk
spec MI. Following the cessation of imported natural gas liquids from the Prudhoe Bay Field Central Gas Facility
at the end of July 2014, immiscible water-alternating gas utilizing lean gas was applied to the Tarn reservoir.
On September 2018, NGL imports from Prudhoe resumed, thereby enabling the MWAG process to return to Tarn.
In 2021 NGL imports from Prudhoe had ceased; however CPF2 continued to blend gas in a configuration that has
allowed MI to be sent to Tarn for injection purposes.
Reservoir Management Summary
In 2021, Tarn produced 1.8 million barrels of oil, 5.1 million barrels of water (MMBW), and 2.49 billion standard
cubic feet (BSCF) of gas. The injection totals for 2021 were 0 BSCF Lean Gas, 0.9 BSCF MI, and 8.5 MMBW. At the
end of 2021, the cumulative injection/withdrawal ratio for Tarn was 1.15. Plans are to continue maintaining
reservoir pressure by balancing monthly production and injection rates.
GKA Annual Surveillance Report Tarn Oil Pool 95
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:128,681 206,497 117,006
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 191 239 562 128,872 206,735 117,567
2 2021 169 242 469 129,041 206,977 118,036
3 2021 180 278 520 129,221 207,255 118,556
4 2021 178 237 481 129,399 207,492 119,037
5 2021 155 194 449 129,554 207,686 119,486
6 2021 129 163 406 129,683 207,849 119,892
7 2021 132 137 295 129,815 207,985 120,187
8 2021 119 199 421 129,934 208,184 120,608
9 2021 149 194 407 130,083 208,378 121,015
10 2021 146 219 408 130,229 208,597 121,424
11 2021 119 197 324 130,348 208,794 121,748
12 2021 115 195 350 130,463 208,989 122,098
2021 TOTAL 1,782 2,493 5,092
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:172,932 142,551 118,644
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 260 88 569 173,193 142,639 119,213
2 2021 230 102 475 173,423 142,741 119,688
3 2021 245 125 528 173,668 142,866 120,216
4 2021 242 95 488 173,910 142,961 120,704
5 2021 210 73 455 174,121 143,034 121,159
6 2021 175 62 412 174,296 143,096 121,571
7 2021 180 39 299 174,475 143,135 121,869
8 2021 162 96 427 174,637 143,230 122,297
9 2021 202 76 413 174,839 143,306 122,710
10 2021 199 97 414 175,038 143,403 123,123
11 2021 162 94 329 175,200 143,498 123,452
12 2021 156 95 355 175,356 143,593 123,807
2021 TOTAL 2,423 1,042 5,163
Produced Fluid Volumes
ATTACHMENT 2
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Tarn Oil Pool 96
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:255,359 33,131 197,356
WATER GAS MI CUM WATER CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 816 0 53 256,175 33,131 197,409
2 2021 700 0 0 256,875 33,131 197,409
3 2021 764 0 0 257,639 33,131 197,409
4 2021 762 0 0 258,401 33,131 197,409
5 2021 784 0 0 259,185 33,131 197,409
6 2021 728 0 0 259,913 33,131 197,409
7 2021 747 0 0 260,660 33,131 197,409
8 2021 793 0 0 261,453 33,131 197,409
9 2021 737 0 53 262,190 33,131 197,462
10 2021 690 76 83 262,880 33,207 197,545
11 2021 474 0 350 263,354 33,207 197,895
12 2021 516 0 368 263,870 33,207 198,263
2021 TOTAL 8,511 76 907
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:258,629 37,661 160,965
WATER GAS MI CUM WATER CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 828 0 43 259,457 37,661 161,008
2 2021 710 0 0 260,167 37,661 161,008
3 2021 775 0 0 260,942 37,661 161,008
4 2021 772 0 0 261,715 37,661 161,008
5 2021 795 0 0 262,509 37,661 161,008
6 2021 738 0 0 263,248 37,661 161,008
7 2021 757 0 0 264,005 37,661 161,008
8 2021 804 0 0 264,809 37,661 161,008
9 2021 747 0 42 265,556 37,661 161,050
10 2021 700 85 67 266,256 37,745 161,117
11 2021 481 0 280 266,737 37,745 161,397
12 2021 523 0 294 267,260 37,745 161,691
2021 TOTAL 8,630 85 726
Injected Fluid Volumes
ATTACHMENT 3
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Tarn Oil Pool 97
CUM LEAN GAS
CUM LEAN GAS
Attachment 4
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Tarn Oil Pool 98
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Tarn Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 8, Conservation Order No. 430A, ConocoPhillips Alaska, Inc., operator of the Tarn Oil Pool,
is hereby submitting the proposed pressure survey plan for 2022.
There were 2 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2021.
In 2022, we expect to conduct approximately two pressure surveys, including initial surveys for new wells prior to
initial sustained production or injection.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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6. Oil Gravity:
0.83 (water = 1.0)
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
ftTVDSS
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)
2L-323 50103202820000 WAG 490165 A (-5222 - -5243),
(-5266 - -5282),
(-5295 - -5369)
05/07/21 195 SBHP 110 5216 3957 5200 0.323 3952
2N-322 50103206780000 O 490165 A (-5139 - -5246)04/03/21 332 SBHP 139 5247 1152 5200 0.327 1137
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Tarn Oil Pool -5200' SS 0.74
Printed Name Carlotta Chernoff Date
23. All tests reported herein were made in accordance with 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.
Signature Title Manager, GKA Asset Development
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Tarn Oil Pool 101
March 9, 2022
Attachment 5
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Production Logs and Special Surveys
This section is meant to fulfill AIO19 Rule 9 item d ‘results and where appropriate, analysis of production
and injection log surveys, tracer surveys and observation well data or surveys’ and ‘results of any special
monitoring’.
Table 5-1. Special surveys performed in 2021.
Well Date Comment
2L-318 02/23/2021 Injection Profile Log
2N-333 08/17/2021 Cement Bond Log
2L-321 09/19/2021 Leak Detect Log
2N-318 11/13/2021 Gyro/CBL/Caliper/RST
MITs performed at Tarn in 2021 are listed below. This section is meant to fulfill AIO19 Rule 9 item f
‘summary of MIT results’.
Table 5-2. MITs completed in 2021 - Includes both State Witnessed (SW) and Unwitnessed Tests
Well Date Test Result
2N-309 1/15/2021 MITIA PASS
2N-309 1/15/2021 MITIA PASS
2N-342 4/5/2021 MITIA PASS
2L-320 7/23/2021 CMIT PASS
2L-310 8/30/2021 MITIA PASS
2N-333 9/14/2021 MITT PASS
2N-318A 9/18/2021 MITIA PASS
GKA Annual Surveillance Report Tarn Oil Pool 102
Attachment 6
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Well Allocation
Production volumes were tracked through an automated production monitoring SCADA system (IP.21) utilizing
meters that transmit data in real-time for monitoring. The 2021 Tarn allocation factors by month are listed
below.
Month Oil Gas Water
Jan-21 0.8821 0.8183 1.0170
Feb-21 0.8920 0.7596 1.0020
Mar-21 0.8913 0.7924 1.0404
Apr-21 0.8773 0.7999 1.0394
May-21 0.8893 0.7818 1.0474
Jun-21 0.8884 0.7839 1.0592
Jul-21 0.8789 0.7938 1.0584
Aug-21 0.8996 0.8333 1.0475
Sep-21 0.8971 0.8292 1.0544
Oct-21 0.9007 0.8346 1.0536
Nov-21 0.8977 0.8943 1.0295
Dec-21 0.9128 0.8787 1.0213
GKA Annual Surveillance Report Tarn Oil Pool 103
GKA Annual Surveillance Report Tarn Oil Pool 104
Attachment 7
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Development Plan and Operational Review
Development Drilling
No development wells were drilled at Tarn in 2021.
Producer to Injector Conversions
No well service conversion projects were executed in Tarn in 2021.
Artificial Lift
Tarn was originally designed to artificially lift producers using miscible gas. However, paraffin deposition in the tubing string
occurs when the production fluid temperature falls below the cloud point of 92°F. This is the
case of longer reach wells and lower liquid rate production wells. Excessive paraffin build‐up and the high frequency of
required paraffin scrapes in some wells led to a change in artificial lift methodology towards surface‐powered downhole jet
pumps. In 2001, after successful pilot tests in 1999 and 2000, 13 of the gas lifted wells were converted to jet pump using hot
produced water as power fluid.
This technique has proven to be very successful in mitigating paraffin deposits. Slickline scrapes and hot oil treatments was
virtually eliminated leading to production increases of about 10%. Unfortunately, the untreated saline produced water
injected down the inner annuli (power fluid) has accelerated tubing and casing corrosion.
Three well integrity failures occurred on jet‐pumped wells due to both tubing and well casing corrosion in 2006‐ 2007: 2L‐
321, 2N‐318, and 2N‐305. These wells were shut‐in and secured. Wells 2N‐305 and 2N‐318 were both sidetracked in 2009. A
workover to install an additional casing string was successfully completed for 2L‐321 during 2008.
In 2009 and 2010, three additional wells were shut-in after failing mechanical integrity tests: 2N‐319, 2N‐303, and 2L‐313.
These wells were in jet pump service when the failures occurred. Wells 2N-319 and 2N-303 were both sidetracked in 2014.
Well 2L-313 will likely remain shut-in and secured until a rotary sidetrack is executed targeting a more prolific area of the
reservoir.
After water breakthrough occurs in producing wells, paraffin deposition is less likely due to increased well flowing
temperatures resulting from the heat capacity of water being greater than that of oil. Consequently, completion designs and
alternatives to jet pumps are being considered for new and existing wells. All new producers drilled in 2014-2015 utilized lift
gas for artificial lift.
In 2016, a mixed approach to artificial lift was adopted. The wells with the highest downtime & cost for paraffin remediation,
combined with an expectation of short remaining tubular life were targeted for jet pumps. This resulted in 2L-330 being
converted from gas lift to jet pump and brought the Tarn total to five active jet pump wells.
In the past few years, the artificial lift strategy has remained largely unchanged. In 2018, the 2N-304 was converted from
surface powered jet pump to gas lift to reduce water handling costs and corrosion tendency. The well has successfully
produced on gas lift with no downtime due to paraffin remediation. In 2019, a similar artificial lift change was done in 2L-321
where the lift mechanism was changed to gas lift from jet pump. The well has a higher tendency for paraffin plugging due to
the smaller size of tubing. To mitigate plugging, the well undergoes frequent hot diesel flushes and slickline scrapes. 2N-339
underwent a Rig Workover (RWO) to replace leaking tubing. The well was put on jet pump service after RWO and oil
production has been restored. In 2020, 2L-311 was found to have flow erosion in the sliding sleeve. Repeated attempts to lift
the well with jet pump failed due to the jet pump failing to seat and seal across the sleeve. To keep the well producing, the
well was converted to gas lift, following which 2L-311 was put back into service. The year 2021 saw several changes in the
field management strategy for Tarn West End, which continues to exhibit high water cut as the area approached maturity.
2N-333 watercut became uncompetitive as a result the well was recompleted by isolating the watered out perforations and
adding new perforations shallower. In a similar exercise the lower perforations of 2N-347 have been isolated to reduce
water production, thus allowing the shallower perforations to continue to produce. The injection rates have been
accordingly adjusted to maintain a VRR of 1 in the area.
In 2021 measurement issues were also discovered with the 2L Accuflow test separator. After a cleanout of the accuflow, the
measurement issues improved, and it was discovered that the liquid rates in 2L is much lower than previously being
measured. Subsequently the micromotion meter was replaced recently in February 2022, after which reliable test results
are currently being obtained.
Attachment 8
Tarn Oil Pool
2021 Annual Reservoir Surveillance Report
Map showing Development as of December 31, 2021
GKA Annual Surveillance Report Tarn Oil Pool 105
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TOROK
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Kuparuk River-Torok Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 8, Conservation Order No. 725 (CO 725) and Rule 8, Area Injection Order 39 (AIO 39),
ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surv eillance report
on the Kuparuk River-Torok Oil Pool (Torok Oil Pool). This report documents the required information pertinent to
the field development and enhanced recovery operations from January through December 2021. The following is
an outline of the information provided:
a) Progress of EOR project and reservoir management summary (Attachment 1) per CO 725 Rule 8 Item A
and AIO 39 Rule 8 Item A.
b) Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3) per CO 725 Rule 8
Item A and AIO 39 Rule 8 Item B.
c) Analysis of reservoir pressure surveys taken in 2021 (Attachment 4) per CO 725 Rule 8 Item A and AIO 39
Rule 8 Item C.
d) Results of production surveys, and any special surveys or monitoring, taken on the Torok Oil Pool in 2021
(Attachment 5) per CO 725 Rule 8 Item A and AIO 39 Rule 8 Item D, F, and H.
e) Results of well allocation, test evaluation, and any other special monitoring (Attachment 6) per CO 725
Rule 8 Item A and AIO 39 Rule 8 Item E.
f) Results of inner and outer annulus monitoring for all wells within a ¼-mile radius of a Torok injector not
cemented across the Torok Oil Pool (Attachment 7) per AIO 39 Rule 8 Item G.
g) Development Plan and Operation Review (Attachments 8) per CO 725 Rule 8 Item A and AIO 39 Rule 8
Items I and J.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
Page left blank intentionally.
Attachment 1
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of Enhanced Recovery Project
GKA Annual Surveillance Report Torok Oil Pool 111
Reservoir Management Summary
Torok produced 268 thousand barrels (MTSB) of oil, 192 million standard cubic feet (MMSCF) of gas and 1,025
thousand barrels of water (MBW) during 2021. Over the same period, 1,290 MBW, 0 MMSCF of lean gas and 0
MMSCF of MI were injected. Cumulative oil, gas, and water production through year-end 2021 was 1,228 MTSB,
1,792 MMSCF, and 4,558 MBW, respectively. Cumulative water, lean gas, and MI injection through year-end 2021
was 6,112 MBW, 337 MMSCF, and 151 MMSCF, respectively.
Progress of EOR Project
Torok is being evaluated for further development and EOR in association with Nuna development.
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:960 1,601 3,534
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 29 15 91 989 1,615 3,624
2 2021 25 12 77 1,014 1,627 3,702
3 2021 27 16 94 1,041 1,643 3,796
4 2021 25 13 94 1,066 1,656 3,889
5 2021 24 13 101 1,090 1,670 3,990
6 2021 25 15 98 1,115 1,685 4,089
7 2021 25 21 99 1,140 1,706 4,187
8 2021 24 26 102 1,164 1,731 4,289
9 2021 21 21 88 1,185 1,752 4,377
10 2021 11 11 44 1,196 1,763 4,420
11 2021 11 13 42 1,207 1,776 4,462
12 2021 21 17 96 1,228 1,792 4,558
2021 TOTAL 268 192 1,025
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:1,176 886 3,591
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 35 4 91 1,211 890 3,683
2 2021 30 2 78 1,241 892 3,761
3 2021 32 7 95 1,273 899 3,856
4 2021 30 4 95 1,303 903 3,950
5 2021 29 5 102 1,332 908 4,053
6 2021 30 7 99 1,362 914 4,152
7 2021 30 13 100 1,392 928 4,251
8 2021 29 20 103 1,420 948 4,354
9 2021 26 15 89 1,446 963 4,443
10 2021 13 9 44 1,459 971 4,487
11 2021 13 10 42 1,472 982 4,529
12 2021 25 10 97 1,497 992 4,626
2021 TOTAL 321 106 1,035
Produced Fluid Volumes
ATTACHMENT 2
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Torok Oil Pool 112
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:4,823 337 151
WATER GAS MI CUM WATER CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 121 0 0 4,944 337 151
2 2021 109 0 0 5,053 337 151
3 2021 122 0 0 5,175 337 151
4 2021 115 0 0 5,290 337 151
5 2021 109 0 0 5,399 337 151
6 2021 101 0 0 5,500 337 151
7 2021 110 0 0 5,610 337 151
8 2021 106 0 0 5,716 337 151
9 2021 103 0 0 5,819 337 151
10 2021 102 0 0 5,921 337 151
11 2021 94 0 0 6,014 337 151
12 2021 98 0 0 6,112 337 151
2021 TOTAL 1,290 0 0
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:4,899 299 114
WATER GAS MI CUM WATER CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 122 0 0 5,021 299 114
2 2021 110 0 0 5,132 299 114
3 2021 123 0 0 5,255 299 114
4 2021 116 0 0 5,371 299 114
5 2021 110 0 0 5,481 299 114
6 2021 102 0 0 5,583 299 114
7 2021 111 0 0 5,694 299 114
8 2021 107 0 0 5,801 299 114
9 2021 104 0 0 5,905 299 114
10 2021 103 0 0 6,008 299 114
11 2021 95 0 0 6,103 299 114
12 2021 99 0 0 6,202 299 114
2021 TOTAL 1,303 0 0
Injected Fluid Volumes
ATTACHMENT 3
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report Torok Oil Pool 113
CUM LEAN GAS
CUM LEAN GAS
Page left blank intentionally.
Attachment 4
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Torok Oil Pool 115
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: Kuparuk River-Torok Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 6, Conservation Order No. 725, ConocoPhillips Alaska, Inc., operator of the Kuparuk River-
Torok Oil Pool (Torok Oil Pool), is hereby submitting the proposed pressure survey plan for 2022.
There was one pressure survey reported for the Torok Oil Pool to the AOGCC in 2021.
In 2022, we expect to conduct approximately four pressure surveys.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
Page left blank intentionally.
6. Oil Gravity:
0.88 (water = 1.0)
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
ftTVDSS
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)
3S-611 50103207740000 O 490169 A (-5157 - -5157),
(-5160 - -5160),
(-5168 - -5168),
(-5170 - -5170),
(-5178 - -5178),
(-5181 - -5181),
(-5187 - -5187),
(-5190 - -5190),
(-5192 - -5192),
(-5204 - -5204),
(-5216 - -5216)
10/08/21 384 SBHP 133 4944 1704 5000 0.440 1729
Printed Name Carlotta Chernoff Date
I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signature Title Manager, GKA Asset Development
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit Kuparuk River-Torok Oil Pool -5000' SS 0.80
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report Torok Oil Pool 119
March 9, 2022
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Map at Datum
GKA Annual Surveillance Report Torok Oil Pool 120
Attachment 5
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Production Logs and Special Surveys
There were no production logs run in the Torok wells in 2021.
There was one pressure buildup in 2021, Well 3S-611, and zero falloffs.
Mechanical integrity tests (MIT) performed on Torok wells in 2021 are listed below.
Well Date Test Result
3S-611 9/13/2021 SCLD PASS
3S-611 10/5/2021 CMIT, MIT-T PASS
GKA Annual Surveillance Report Torok Oil Pool 121
Attachment 6
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Well Allocation, Test Evaluation, and Special Monitoring
Well Allocation
Production volumes were tracked through an automated production monitoring SCADA system (IP.21) utilizing
meters that transmit data in real-time for monitoring and there were no issues with 2020 measurements. The 2021
Torok allocation factors by month are listed below.
Month Oil Gas Water
Jan-21 0.8827 0.8196 1.0170
Feb-21 0.8921 0.7595 1.0024
Mar-21 0.8915 0.7930 1.0413
Apr-21 0.8770 0.7997 1.0400
May-21 0.8903 0.7824 1.0475
Jun-21 0.8885 0.7843 1.0592
Jul-21 0.8797 0.7936 1.0583
Aug-21 0.8999 0.8335 1.0479
Sep-21 0.8981 0.8294 1.0562
Oct-21 0.9009 0.8407 1.0539
Nov-21 0.8978 0.8943 1.0292
Dec-21 0.9098 0.8744 1.0231
Significant Studies
This section is meant to include the documentation to satisfy Area Injection Order Rule 8 Item E ‘assessment of
fracture propagation into adjacent confining intervals’.
• No new studies on fracture propagation into adjacent confining intervals has been completed that has
not previously been reported to the AOGCC.
GKA Annual Surveillance Report Torok Oil Pool 122
Attachment 7
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Monitoring Inner and Outer Annuli
Summary of results of inner and outer annulus monitoring for all production wells, injection wells, and any wells that
are not cemented across the Torok Oil Pool and are located within ¼-mile radius of a Torok injector. Information
below contains the inner annulus (IA) and outer annulus (OA) pressures for each well, the well head injection pressure
(WHIP) for injection wells, and flowing tubing pressure (FTP) for production wells.
0
200
400
600
800
1000
1200
1400
1600
1800
2000
Pressure, psi3S-19
3S-19 FTP 3S-19 IA 3S-19 OA
-500
0
500
1000
1500
2000
Pressure, psi3S-611
3S-611 FTP 3S-611 IA 3S-611 OA
GKA Annual Surveillance Report Torok Oil Pool 123
0
500
1000
1500
2000
2500
Pressure, psi3S-612
3S-612 WHIP 3S-612 IA 3S-612 OA
0
500
1000
1500
2000
2500
3000
Pressure, psi3S-613
3S-613 WHIP 3S-613 IA 3S-613 OA
GKA Annual Surveillance Report Torok Oil Pool 124
0
200
400
600
800
1000
1200
1400
1600
1800
2000
Pressure, psi3S-620
3S-620 FTP 3S-620 IA 3S-620 OA
GKA Annual Surveillance Report Torok Oil Pool 125
Attachment 8
Torok Oil Pool
2021 Annual Reservoir Surveillance Report
Development Plans and Operational Review
Development Drilling
• There was no development drilling in 2021.
• A third well pair is planned for 2022.
GKA Annual Surveillance Report Torok Oil Pool 126
WEST SAK
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 West Sak Oil Pool Annual Reservoir Surveillance Report
Dear Commissioner Chmielowski,
In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk
River Unit, is hereby submitting the annual surveillance report on the West Sak Oil Pool. This report documents
information pertinent to field development and enhanced recovery operations from January through December
2021. The following is an outline of the information provided:
a. A summary of the current enhanced oil recovery in the West Sak Oil Pool (Attachment 1).
b. Voidage balance, by month, for produced and injected fluid (Attachments 2 and 3).
c. Analysis of reservoir pressure surveys taken in 2021 and pressure survey plans for 2021 (Attachment 4).
d. Results of injection surveys, production surveys, and any special surv eys, conducted in the West Sak Oil
Pool in 2021 (Attachments 5 through 7).
e. Results of pool production allocation factors (Attachment 8).
f. Future development plans (Attachment 9).
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
Page left blank intentionally.
GKA Annual Surveillance Report West Sak Oil Pool 131
Attachment 1
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Summary of the Enhanced Oil Recovery Project
During 2021, there were 52 active producers and 61 active injectors in the West Sak Oil Pool. Waterflood continues
to be the primary method to improve oil recovery and maintain reservoir pressure at West Sak. Water is sourced from
the Seawater Treatment Plant (STP) and Central Processing Facility 1 (CPF‐1).
Injection and production performance in the West Sak Oil Pool is challenged by matrix bypass events (MBEs) or highly
conductive conduits between an injector and a producer. These conduits effectively short‐circuit the waterflood
resulting in poor pattern sweep without remediation. During 2021, one new MBE developed between 1H-110 and
1H-104.
During 2021, three MBE remediation treatments were attempted in injectors 1J-156, 1J-170, and 1J-164 to reestablish
water injection support and pattern sweep. 1J-156 had a cement job pumped and appears to have successfully
reduced the offset water production. 1J-170 and 1J-164 both had gel jobs pumped to remediate their respective
MBE’s. The status of these treatments remains under evaluation but appear to be losing their effectiveness in the 4th
quarter of 2021, plans for continued diagnostics are in place. In addition to the three MBE remediations, a fourth MBE
was isolated in 1H-110 via mechanical means.
In 2014, the AOGCC approved Viscosity Reducing Water-Alternating Gas (VRWAG) injection as an enhanced oil
recovery process for the West Sak Oil Pool. Injectors 1C-150, 1H-113, 1H-115, and 1H-119 received gas injection
during 2021.
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:112,160 66,727 52,722
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB
1 2021 621 254 619 112,781 66,981 53,341
2 2021 586 286 581 113,367 67,267 53,922
3 2021 637 297 662 114,004 67,565 54,584
4 2021 593 260 629 114,597 67,825 55,213
5 2021 612 278 658 115,209 68,102 55,871
6 2021 632 268 601 115,841 68,370 56,472
7 2021 636 262 655 116,477 68,632 57,127
8 2021 666 291 666 117,143 68,923 57,793
9 2021 636 320 837 117,779 69,243 58,630
10 2021 621 281 978 118,399 69,525 59,608
11 2021 602 277 890 119,002 69,802 60,498
12 2021 594 272 965 119,596 70,074 61,463
2021 TOTAL 7,436 3,348 8,742
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2020:118,937 46,977 53,237
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 664 99 619 119,601 47,076 53,857
2 2021 626 128 581 120,226 47,204 54,437
3 2021 681 129 662 120,907 47,333 55,099
4 2021 633 108 629 121,540 47,441 55,729
5 2021 654 118 658 122,194 47,559 56,387
6 2021 675 107 601 122,869 47,666 56,988
7 2021 679 103 655 123,548 47,768 57,643
8 2021 711 120 666 124,260 47,888 58,309
9 2021 679 146 837 124,938 48,034 59,145
10 2021 663 119 978 125,601 48,154 60,124
11 2021 643 119 890 126,245 48,273 61,014
12 2021 635 116 965 126,879 48,389 61,979
2021 TOTAL 7,942 1,412 8,742
Produced Fluid Volumes
ATTACHMENT 2
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report West Sak Oil Pool 132
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:168,953 1,841 9,957
WATER GAS MI CUM WATER CUM MI
MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF
1 2021 1,512 0 0 170,465 1,841 9,957
2 2021 1,420 0 0 171,884 1,841 9,957
3 2021 1,656 0 4 173,540 1,841 9,961
4 2021 1,497 0 32 175,037 1,841 9,993
5 2021 1,477 0 39 176,514 1,841 10,032
6 2021 1,252 0 2 177,766 1,841 10,034
7 2021 1,354 0 0 179,120 1,841 10,034
8 2021 1,427 0 0 180,546 1,841 10,034
9 2021 1,437 0 0 181,984 1,841 10,034
10 2021 1,476 0 0 183,460 1,841 10,034
11 2021 1,424 0 0 184,884 1,841 10,034
12 2021 1,457 0 0 186,341 1,841 10,034
2021 TOTAL 17,388 0 78
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM LEAN GAS CUM MI
Cumulatives at Dec 31, 2020:169,281 2,482 7,321
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2021 1,512 0 0 170,793 2,482 7,321
2 2021 1,420 0 0 172,212 2,482 7,321
3 2021 1,656 0 3 173,868 2,482 7,324
4 2021 1,497 0 20 175,365 2,482 7,344
5 2021 1,477 0 24 176,842 2,482 7,368
6 2021 1,252 0 1 178,094 2,482 7,369
7 2021 1,354 0 0 179,448 2,482 7,369
8 2021 1,427 0 0 180,874 2,482 7,369
9 2021 1,437 0 0 182,312 2,482 7,369
10 2021 1,476 0 0 183,788 2,482 7,369
11 2021 1,424 0 0 185,212 2,482 7,369
12 2021 1,457 0 0 186,669 2,482 7,369
2021 TOTAL 17,388 0 48
Injected Fluid Volumes
ATTACHMENT 3
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
GKA Annual Surveillance Report West Sak Oil Pool 133
CUM LEAN GAS
Page left blank intentionally.
Attachment 4
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report West Sak Oil Pool 135
Page left blank intentionally.
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: West Sak Oil Pool – Proposed Pressure Survey Plan for 2022
Dear Commissioner Chmielowski,
In compliance with Rule 8, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the West Sak Oil
Pool, is hereby submitting the proposed pressure survey plan for 2022.
There were 15 pressure surveys reported for the West Sak Oil Pool to the AOGCC in 2021.
In 2022, we expect to conduct approximately 5-10 pressure surveys, including initial surveys for new wells prior to
initial sustained production or injection.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
Page left blank intentionally.
6. Oil Gravity:
0.94 (water = 1.0)
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 ftTVDSS
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)
1D-102 50029229600000 O 490150 BD (-3651 - -3621)01/03/21 36478 SBHP 63 3135 1366 3500 0.390 1508
1D-127 50029228900000 O 490150 ABD (-3576 - -3604), (-3546 -
-3555)
01/03/21 22569 SBHP 72 3516 1344 3500 0.440 1337
1D-131 50029228910000 O 490150 ABD (-3603 - -3638)01/04/21 32935 SBHP 72 3343 1552 3500 0.391 1613
1G-103 50029208240100 WI 490150 B (-5601 - -6437),(-6990 -
-11871)
01/04/21 92 SBHP 75 3259 1999 3500 0.404 2096
1G-103 50029208240100 WI 490150 B (-5601 - -6437),(-6990 -
-11871)
01/21/21 499 SBHP 75 3259 1875 3500 0.440 1981
1J-103 50029233180000 O 490150 ABD (-3670 - -3665), (-3681 -
-3680), (-3682 - -3677)
01/21/21 10542 SBHP 72 3498 1525 3500 0.350 1526
1J-166 50029232910000 O 490150 ABD (-3541 - -3547), (-3543 -
-3607), (-3552 - -3603),
(-3569 - -3559)
03/12/21 2809 SBHP 67 3385 1297 3500 0.352 1337
1D-107 50029229830000 WI 490150 ABD (-3715 - -3751), (-3846 -
-3880), (-3913 - -3924)
04/04/21 215 SBHP 75 3724 1377 3500 0.451 1276
1C-104 50029230760000 O 490150 BD (-3644 - -3601)04/19/21 8640 PBU 70 3276 1285 3500 0.393 1373
1J-135 50029233490000 O 490150 BD (-3461 - -3391), (-3483 -
-3461)
04/20/21 5460 PBU 74 3382 1800 3500 0.393 1846
3R-105 50029236510000 O 490150 D (-3658 - -3788), (-3667 -
-3811)
05/10/21 109 SBHP 73 3639 1260 3500 0.370 1209
1R-104 50029214070100 WI 490150 B (-5601 - -6437)05/16/21 282 SBHP 73 3223 1840 3500 0.420 1956
1R-126 50029221930100 WI 490150 B (-3404 - -3404),(-3313 -
-3404)
05/16/21 258 SBHP 67 3289 1965 3500 0.440 2058
3R-112 50029236370000 WI 490150 D (-3593 - -3454)05/28/21 720 SBHP 68 3586 1536 3500 0.442 1498
3R-111 50029236430000 O 490150 D (-3487 - -3586), (-3509 -
-3591)
07/24/21 84 SBHP 74 3343 955 3500 0.370 1013
ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:7. Gas Gravity:
Kuparuk River Unit West Sak Oil Pool -3500' SS 0.57
Printed Name Carlotta Chernoff Date
23. All tests reported herein were made in accordance with 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.
Signature Title Manager, GKA Asset Development
Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
GKA Annual Surveillance Report West Sak Oil Pool 139
March 9, 2022
WEST SAK UNIT
WEST SAK OIL POOL
CONSERVATION ORDER 406A
RULE 11 - INJECTIVITY PROFILES
2021 ANNUAL SUBMITTAL
WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION
NUMBER NUMBER INITIAL PROFILE/PROFILE/PROFILE/COMPLETION TAKING BWPD /
50-INJECTION SURVEY SURVEY SURVEY TYPE INJECTION MSCFD
1J-170 0292331000 - 00 10/02/06 01/30/21 SPINNER FOLLOW-UP SINGLE AD 1437
395
1J-127 0292330600 - 01 10/01/06 02/02/21 SPINNER FOLLOW-UP SINGLE ABD 1490
267
1J-122 0292335900 - 02 12/11/07 02/06/21 SPINNER FOLLOW-UP SINGLE ABD 850
115
1H-113 0292358800 - 03 02/18/18 05/22/21 SPINNER FOLLOW-UP SINGLE ABD 2102
1777
1H-114 0292358400 - 04 12/09/17 06/23/21 SPINNER FOLLOW-UP SINGLE ABD 1500
774
5 >>Total IPROF Count for 2021
Attachment 5
GKA Annual Surveillance Report West Sak Oil Pool 140
Attachment 6
West Sak Oil Pool
2021 Annual Surveillance Report
Production Survey Data
During 2021, no production profile surveys were attempted for the West Sak Oil Pool.
GKA Annual Surveillance Report West Sak Oil Pool 141
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Attachment 7
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Special Survey Data
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1B-101 01/12/21 0%88%12%
1B-101 09/30/21 0%80%20%
1C-102 01/14/21 0%18%82%
1C-102 05/04/21 0%48%52%
1C-109 05/04/21 0%46%54%
1C-109 01/06/21 0%10%90%
1C-153 09/03/21 0%0%100%
1C-155 09/03/21 0%0%100%
1C-170 09/03/21 0%0%100%
1C-178 01/06/21 0%22%78%
1C-178 09/03/21 0%32%68%
1D-108 09/30/21 32%6%62%
1D-108 06/22/21 30%27%43%
1D-113 09/30/21 27%49%24%
1D-113 01/15/21 26%50%24%
1D-113 06/25/21 36%35%29%
1D-115 06/22/21 54%22%24%
1D-116 09/30/21 46%40%14%
1D-116 06/22/21 0%0%100%
1D-116 01/19/21 42%37%21%
1D-123 09/30/21 59%20%21%
1D-123 06/22/21 64%0%36%
1D-123 01/19/21 60%18%22%
1D-124 06/25/21 48%34%18%
1D-124 01/19/21 33%47%20%
1D-135 09/30/21 4%37%60%
1D-143 06/22/21 12%0%88%
1D-143 01/07/21 6%0%94%
1D-145 09/30/21 0%100%0%
1H-101 09/03/21 27%52%21%
1H-101 01/05/21 30%43%27%
1H-101 02/05/21 26%47%27%
1H-101 03/03/21 40%32%28%
1H-101 04/02/21 39%46%15%
1H-101 06/13/21 37%27%35%
1H-101 07/20/21 34%31%36%
1H-101 08/02/21 53%40%7%
1H-101 10/01/21 21%54%25%
1H-102 01/05/21 45%35%19%
GKA Annual Surveillance Report West Sak Oil Pool 143
Attachment 7
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Special Survey Data
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1H-102 02/05/21 27%58%15%
1H-102 04/02/21 36%47%17%
1H-102 07/20/21 32%45%23%
1H-102 08/02/21 33%32%35%
1H-102 10/01/21 35%40%25%
1H-102 03/07/21 42%40%17%
1H-102 03/13/21 27%52%21%
1H-102 05/03/21 31%45%24%
1H-102 08/29/21 35%43%22%
1H-102 09/01/21 34%46%21%
1H-103 01/05/21 25%63%13%
1H-103 02/05/21 12%75%13%
1H-103 03/03/21 17%72%11%
1H-103 04/02/21 14%75%11%
1H-103 06/13/21 13%75%12%
1H-103 07/20/21 18%72%10%
1H-103 08/02/21 12%77%11%
1H-103 10/01/21 0%75%25%
1H-103 05/03/21 17%73%10%
1H-103 08/29/21 20%66%14%
1H-104 01/05/21 0%49%51%
1H-104 02/05/21 0%50%50%
1H-104 03/03/21 0%65%35%
1H-104 04/02/21 0%69%31%
1H-104 06/13/21 0%56%44%
1H-104 07/20/21 0%62%38%
1H-104 08/02/21 0%55%45%
1H-104 10/01/21 0%61%39%
1H-104 05/03/21 0%58%42%
1J-101 01/14/21 35%43%22%
1J-101 09/03/21 12%60%28%
1J-101 07/29/21 20%56%24%
1J-101 03/07/21 38%32%30%
1J-101 05/12/21 39%31%30%
1J-115 09/03/21 6%44%50%
1J-115 06/09/21 22%55%23%
1J-120 01/19/21 6%24%70%
1J-120 07/29/21 5%17%78%
1J-120 03/07/21 11%18%71%
GKA Annual Surveillance Report West Sak Oil Pool 144
Attachment 7
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Special Survey Data
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1J-120 10/03/21 3%29%68%
1J-137 09/03/21 0%66%34%
1J-137 06/09/21 0%80%20%
1J-152 10/03/21 1%64%36%
1J-159 01/14/21 20%30%50%
1J-159 09/03/21 0%11%90%
1J-159 08/02/21 14%10%76%
1J-159 06/09/21 23%17%60%
1J-159 09/15/21 5%9%85%
1J-166 09/03/21 89%8%3%
1J-166 08/02/21 78%7%15%
1J-174 09/03/21 0%52%48%
1J-174 01/19/21 0%31%69%
1J-174 06/09/21 0%48%52%
1J-178 01/14/21 0%59%41%
1J-178 09/03/21 0%78%22%
1J-178 06/09/21 0%71%29%
3K-102 10/01/21 0%25%75%
3K-102 01/11/21 0%58%42%
3K-102 05/05/21 0%67%33%
3K-105 10/01/21 0%0%100%
3K-105 01/11/21 0%0%100%
3K-105 05/05/21 0%0%100%
1D-141A 09/03/21 0%0%100%
1E-126 10/04/21 10%65%25%
1E-168 07/29/21 30%0%70%
1E-168 10/06/21 6%0%94%
1E-170 09/30/21 0%67%33%
1E-170 01/07/21 0%57%44%
1E-170 07/29/21 0%55%45%
1E-170 03/02/21 0%60%41%
1E-170 05/10/21 0%0%100%
GKA Annual Surveillance Report West Sak Oil Pool 145
Attachment 8
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Results of Well Allocation
Production volumes were tracked through an automated production monitoring SCADA system (IP.21) utilizing
meters that transmit data in real-time for monitoring and there were no issues with 2021 measurements. The 2021
West Sak allocation factors by month are listed below.
Month Oil Gas Water
Jan-21 0.8822 0.8193 1.0170
Feb-21 0.8919 0.7531 1.0021
Mar-21 0.8914 0.7909 1.0408
Apr-21 0.8772 0.7993 1.0398
May-21 0.8901 0.7822 1.0473
Jun-21 0.8886 0.7841 1.0590
Jul-21 0.8786 0.7926 1.0583
Aug-21 0.8998 0.8337 1.0479
Sep-21 0.8968 0.8277 1.0540
Oct-21 0.9008 0.8363 1.0541
Nov-21 0.8977 0.8943 1.0293
Dec-21 0.9128 0.8782 1.0222
GKA Annual Surveillance Report West Sak Oil Pool 146
Attachment 9
West Sak Oil Pool
2021 Annual Reservoir Surveillance Report
Development Plans and Operational Review
WEST SAK ‘CORE AREA’ DEVELOPMENT
No development wells were drilled in 2021. Two development wells (1C-158, 1C-157) are planned to be drilled
in late 2022 as single-laterals in the D sand.
EASTERN NORTH-EAST WEST SAK (EASTERN NEWS) DEVELOPMENT
No development wells were drilled in 2021 and no development wells are planned for 2022.
WESTERN NORTH-EAST WEST SAK (WESTERN NEWS) DEVELOPMENT
No development wells were drilled in 2021 and no development wells are planned for 2022.
NORTHWEST WEST SAK (3R)
No development wells were drilled in 2021 and no development wells are planned for 2022.
GKA Annual Surveillance Report West Sak Oil Pool 147
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GAS OFFTAKE
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Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
ConocoPhillips Alaska, Inc.
ATO-1376
PO Box 100360
Anchorage AK 99510-0360
Phone (907) 263-4692
Ms. Jessie Chmielowski, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Ave. Suite 100
Anchorage, Alaska 99501
Re: 2021 Allowable Gas Offtake from Kuparuk River Oil Pool
Dear Commissioner Chmielowski,
In compliance with Rule 13, Conservation Order No. 432D, ConocoPhillips Alaska, Inc., operator of the Kuparuk River
Oil Pool, is hereby submitting the gas offtake volume information for 2020 (Attachment 1).
During 2021, the annualized average gas offtake was 2,089 MSCFD, considerably less than the maximum allowable
annual average gas offtake rate of 5,000 MSCFD as stated in Rule 13 for Kuparuk River Oil Pool.
The low annualized average gas offtake was driven by Oooguru k’s gas production, which exceeds their injection and
fuel consumption, resulting in taking only their return gas and no makeup for fuel.
If you have any questions concerning this data, please contact Jerissa Hampton at (907) 263-3701.
Sincerely,
Carlotta Chernoff
Manager, GKA Asset Development
Greater Kuparuk Area
March 9, 2022
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Attachment 1
Kuparuk River Oil Pool
2021 Annual Reservoir Surveillance Report
Gas Offtake Data
GKA Annual Surveillance Report Kuparuk Gas Offtake 153
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