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HomeMy WebLinkAbout2013 Greater Kuparuk Area
Greater Kuparuk Area
2013 Annual Reservoir Surveillance Reports
Kuparuk, Meltwater, Tabasco,
Tarn, & West Sak Oil Pools
Reporting Period
January 1 to December 31, 2013
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2013
GREATER KUPARUK AREA
ANNUAL SURVEILLANCE REPORTS
Table of Contents
KUPARUK RIVER OIL POOL REPORT
SUMMARY OF EOR PROJECT ................................................................... ATTACHMENT 1
Map of EOR Program Status
Plot of Incremental EOR Oil Rate
PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2
INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3
RESERVOIR PRESSURE SURVEYS .......................................................... ATTACHMENT 4
PROPOSED PRESSURE SURVEY PLAN
RESERVOIR PRESSURE SURVEY REPORT
PROPOSED INJECTION PROFILE SURVEY PLAN
INJECTION SURVEY DATA ......................................................................... ATTACHMENT 5
PRODUCTION SURVEY DATA.................................................................... ATTACHMENT 6
MISCIBLE INJECTANT COMPOSITION ...................................................... ATTACHMENT 7
CPF1 MI Composition
CPF2 MI Composition
KUPARUK LSEOR DEVELOPMENT PLAN ................................................. ATTACHMENT 8
MELTWATER OIL POOL REPORT
SUMMARY OF EOR PROJECT & RESERVOIR MANAGEMENT ............... ATTACHMENT 1
PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2
INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3
RESERVOIR PRESSURE SURVEYS .......................................................... ATTACHMENT 4
PROPOSED PRESSURE SURVEY PLAN
RESERVOIR PRESSURE SURVEY REPORT
PRODUCTION & SPECIAL SURVEYS ........................................................ ATTACHMENT 5
WELL ALLOCATION & SHALLOW GAS SPECIAL MONITORING.............. ATTACHMENT 6
Meltwater OA Pressure Survey for 2013
DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7
MAP SHOWING DEVELOPMENT AS OF 12/31/2013 ................................. ATTACHMENT 8
GKA Annual Surveillance Report Table of Contents I
TABASCO OIL POOL REPORT
SUMMARY OF EOR PROJECT ................................................................... ATTACHMENT 1
PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2
INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3
PROPOSED PRESSURE SURVEY PLAN
RESERVOIR PRESSURE SURVEYS .......................................................... ATTACHMENT 4
PRODUCTION LOGS & SPECIAL SURVEYS ............................................. ATTACHMENT 5
WELL ALLOCATION & TEST EVALUATION SUMMARY ............................ ATTACHMENT 6
DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7
TARN OIL POOL REPORT
SUMMARY OF EOR PROJECT ................................................................... ATTACHMENT 1
PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2
INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3
PROPOSED PRESSURE SURVEY PLAN
RESERVOIR PRESSURE SURVEYS .......................................................... ATTACHMENT 4
PRODUCTION LOGS & SPECIAL SURVEYS ............................................. ATTACHMENT 5
PRODUCTION ALLOCATION FACTORS .................................................... ATTACHMENT 6
DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7
MAP SHOWING RECENT DEVELOPMENT WELLS................................... ATTACHMENT 8
WEST SAK OIL POOL REPORT
SUMMARY OF EOR PROJECT ................................................................... ATTACHMENT 1
PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2
INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3
PROPOSED PRESSURE SURVEY PLAN
RESERVOIR PRESSURE SURVEYS .......................................................... ATTACHMENT 4
INJECTION SURVEY DATA ......................................................................... ATTACHMENT 5
PRODUCTION SURVEY DATA.................................................................... ATTACHMENT 6
GEOCHEMICAL OIL PRODUCTION SPLITS .............................................. ATTACHMENT 7
PRODUCTION ALLOCATION FACTORS .................................................... ATTACHMENT 8
DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 9
KUPARUK GAS OFFTAKE
TABLE OF MONTHLY GAS OFFTAKE ........................................................ ATTACHMENT 1
GKA Annual Surveillance Report Table of Contents II
KUPARUK
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ATTACHMENT 1
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Summary of the Enhanced Recovery Project
Enhanced Recovery
Miscible water‐alternating‐gas (MWAG) continues to serve as the main enhanced oil recovery process for the
Kuparuk field. Twenty‐four MWAG/IWAG drill sites service the Kuparuk reservoir which includes 185
available EOR patterns. Some mature patterns generally no longer receive miscible injectant (MI) but are
available for use as lean gas injection wells when plant upsets occur and when the drillsites are converted to
lean gas chase. The field continues to manufacture miscible injectant at two of its Central Processing Facilities
(CPFs). MI manufacture occurs by blending together produced lean gas and natural gas liquids (NGLs). The
NGLs originate from two sources: (1) the Kuparuk field itself (known as indigenous NGLs), and (2) those
NGLs imported from the Prudhoe Bay Field Central Gas Facility. Importation from Prudhoe Bay is utilized
to fill any shortfall between the total NGL requirement and the available indigenous NGL production. From a
flood management perspective, the majority of available lean gas after fuel use is blended with these two
NGL streams to maximize the daily volume of MI generated in the field.
During 2013, the MWAG project operated in full MI production mode for most of the 24 MWAG drillsites.
Twenty ‐ three of the drillsites were on MWAG and one mature drillsite (1A) continued on immiscible water
alternating gas (IWAG). The purpose of this lean gas injection, in the format of IWAG, is to recover NGLs left
behind by the original MWAG process, and collect data to evaluate post‐MWAG options. The observations
from lean gas chase drillsites indicate potential for increasing returning NGL sales. Drillsites 1A, 1Y, and 2X
were converted to lean gas chase mid‐2009, followed by drillsites 1G and 1R later in the same year, after
seeing positive response from drillsites 2U, 2V, and 2W.
During 2013, Kuparuk imported an average of 13,157 barrels per day of Prudhoe NGLs. Import NGLs and
indigenous NGLs blended with available lean gas generated an average of 141 MMSCFD of MI. The annual
average MI injection rate into the Kuparuk Field was 109 MMSCFD. The remainder was utilized for Greater
Kuparuk Area (GKA) satellite fields, including 19 MMSCFD as injection in Tarn and Meltwater, and 4 MMSCFD
as injection at West Sak. The remaining MI supports the incremental requirement for the lift gas at satellite
fields Tarn, Meltwater, and drillsite 3S. The estimated incremental oil sales in the year 2013 from the ongoing
Kuparuk MWAG project are 25.4 MBOPD. As in the past years, due to the lack of the base line water flood
performance data, the incremental oil production from Tarn and Meltwater MWAG is not split from their
total oil.
The priority for gas management at the Kuparuk field during 2013 was to continue to balance solvent
injection between the A‐Sand and C‐Sand. This maximizes total EOR and returned NGL rates while avoiding
excessive gas production rates, which would cause production impacts due to gas handling limitations. Total
GKA annual average gas production rate in 2013 was 203 MMSCFD, down from 204 MMSCFD during 2012.
MWAG
Small Scale EOR (SSEOR and SSEORX)
Drillsite 2Z continued on MI injection; drillsites 1A, 1Y, and 2X no longer receive MI injection. The 2013
average MI injection rate at Drillsite 2Z was 3 MMSCFD.
GKA Annual Surveillance Report Kuparuk Oil Pool 9
Large Scale EOR (LSEOR)
The original LSEOR Drill Sites include: 1F, 1G, 1Q, 1R, 2A, 2B, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X, and
3F. Drill sites 1G, 1R, 2F, 2U, 2V, 2W, and 2X did not receive MI in 2013. The total MI injection rate into the
remaining drill sites averaged 31 MMSCFD in 2013.
EOR Expansions
Expansions to the original LSEOR occurred over multiple phases and now include Drill Sites 1B, 1C, 1D, 1E, 1L,
3B, 3G, 3H, 3O, 3Q, and 3S. During 2013, the average MI injection rate into these expansion drill sites was 75
MMSCFD.
IWAG
During 2013 operations, the Kuparuk EOR project continued to maximize the volume of available MI by
blending a majority of available lean gas with Kuparuk‐sourced and imported NGL. IWAG operations were
continued in drillsite 1A and, as needed, field wide during maintenance events. IWAG at drillsites 1G and 1R was
discontinued in April 2010 after the gas injection line was converted to water injection. IWAG was discontinued
at drillsite 2X in January 2011 after the gas injection line was converted to water injection service, and 2U, 2V,
and 2W in 2014. These drillsites will operate with water injection only for the foreseeable future.
GKA Annual Surveillance Report Kuparuk Oil Pool 10
2013 EOR Program StatusGKA Active EOR Patterns•185 KRU • 12 Tarn • 0 Meltwater• 3 West Sak2L, 2N(Tarn)2P(MW)2G3R3O3N3K3H3J3C1R1H1D3B1Q1G1B3F2W1Y1A1F2T2U2X2Z2V2C2D1L2A2B2F2E2K2M2H3I3A3Q1C3G3M1E3SW SAKSSEOR and SSEORXLSEOR and LSEORXEORX1 Expansion in 2002 – 4 WellsEORX1 Expansion in 2001EORX1 Expansion in 20031C WSak EOR Pilot 20031D EOR Expansion in 2008GKA Satellites 1998-2002GKA Annual Surveillance ReportKuparuk Oil Pool11
050001000015000200002500030000350004000045000Jan-05Apr-05Jul-05Oct-05Jan-06Apr-06Jul-06Oct-06Jan-07Apr-07Jul-07Oct-07Jan-08Apr-08Jul-08Oct-08Jan-09Apr-09Jul-09Oct-09Jan-10Apr-10Jul-10Oct-10Jan-11Apr-11Jul-11Oct-11Jan-12Apr-12Jul-12Oct-12Jan-13Apr-13Jul-13Oct-13BOPD2005-2013 Kuparuk EOR+NGL Sales ProductionDS3SDS3RDS3QDS3ODS3NDS3JDS3HDS3GDS3FDS3CDS3BDS3ADS2ZDS2XDS2WDS2VDS2UDS2TDS2MDS2KDS2HDS2GDS2FDS2DDS2CDS2BDS2ADS1YDS1RDS1QDS1LDS1JDS1HDS1GDS1FDS1EDS1DDS1CDS1BDS1AGKA Annual Surveillance ReportKuparuk Oil Pool12
ATTACHMENT 2
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Produced Fluid Volumes
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31,2012 2,288,106 3,073,321 3,913,021
MO
YR
OIL
MSTB
GAS
MMSCF
WATER
MSTB
CUM OIL
MSTB
CUM GAS
MMSCF
CUM WATER
MSTB
1 2013 2,821 6,063 16,292 2,290,927 3,079,384 3,929,313
2 2013 2,627 5,558 14,485 2,293,554 3,084,941 3,943,798
3 2013 2,734 5,323 15,450 2,296,288 3,090,265 3,959,248
4 2013 2,593 5,203 16,103 2,298,881 3,095,467 3,975,351
5 2013 2,577 5,143 16,176 2,301,458 3,100,610 3,991,527
6 2013 2,304 4,773 14,026 2,303,762 3,105,383 4,005,553
7 2013 2,621 5,019 14,503 2,306,383 3,110,403 4,020,057
8 2013 2,121 4,229 12,282 2,308,504 3,114,632 4,032,338
9 2013 2,616 4,920 16,331 2,311,120 3,119,552 4,048,669
10 2013 2,749 5,382 17,321 2,313,870 3,124,934 4,065,990
11 2013 2,675 5,710 16,824 2,316,545 3,130,645 4,082,814
12 2013 2,832 6,074 17,310 2,319,377 3,136,718 4,100,124
2013 TOTAL 31,271 63,397 187,103
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31,2012 2,823,523 1,755,912 3,987,369
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2013 3,481 4,067 16,618 2,827,004 1,759,979 4,003,987
2 2013 3,242 3,704 14,775 2,830,246 1,763,683 4,018,762
3 2013 3,374 3,447 15,759 2,833,619 1,767,130 4,034,521
4 2013 3,200 3,408 16,425 2,836,819 1,770,539 4,050,946
5 2013 3,180 3,356 16,500 2,839,999 1,773,894 4,067,446
6 2013 2,843 3,153 14,306 2,842,843 1,777,047 4,081,752
7 2013 3,235 3,231 14,793 2,846,077 1,780,278 4,096,545
8 2013 2,617 2,806 12,527 2,848,695 1,783,083 4,109,073
9 2013 3,228 3,160 16,657 2,851,923 1,786,243 4,125,730
10 2013 3,393 3,499 17,667 2,855,316 1,789,743 4,143,397
11 2013 3,301 3,825 17,161 2,858,616 1,793,567 4,160,558
12 2013 3,495 4,072 17,656 2,862,111 1,797,639 4,178,214
2013 TOTAL 38,588 41,727 190,845
GKA Annual Surveillance Report Kuparuk Oil Pool 13
ATTACHMENT 3
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Injected Fluid Volumes
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31,2012 6,280,300 1,181,904 1,250,823
MO
YR
WATER
MSTB
GAS
MMSCF
MI
MMSCF
CUM WATER
MSTB
CUM GAS
MMSCF
CUM MI
MMSCF
1 2013 22,316 274 3,914 6,302,616 1,182,178 1,254,737
2 2013 19,278 217 3,451 6,321,894 1,182,395 1,258,188
3 2013 19,909 328 3,221 6,341,803 1,182,723 1,261,409
4 2013 18,209 0 3,510 6,360,012 1,182,723 1,264,919
5 2013 17,762 0 3,742 6,377,775 1,182,723 1,268,662
6 2013 15,200 16 3,390 6,392,975 1,182,739 1,272,052
7 2013 16,266 1,235 2,483 6,409,241 1,183,974 1,274,534
8 2013 13,729 1,883 1,164 6,422,970 1,185,857 1,275,698
9 2013 17,273 549 3,138 6,440,243 1,186,406 1,278,836
10 2013 17,821 0 3,924 6,458,063 1,186,406 1,282,761
11 2013 17,506 298 3,685 6,475,569 1,186,704 1,286,446
12 2013 18,452 341 3,801 6,494,021 1,187,045 1,290,246
2013 TOTAL 213,721 5,141 39,423
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31,2012 6,399,625 1,044,320 627,856
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR MRVB MRVB MRVB MRVB MRVB MRVB
1 2013 22,763 244 2,963 6,422,388 1,044,564 630,819
2 2013 19,664 193 2,612 6,442,051 1,044,757 633,431
3 2013 20,307 291 2,438 6,462,358 1,045,048 635,870
4 2013 18,573 0 2,657 6,480,932 1,045,048 638,527
5 2013 18,118 0 2,833 6,499,049 1,045,048 641,360
6 2013 15,504 15 2,566 6,514,553 1,045,063 643,926
7 2013 16,592 1,098 1,879 6,531,145 1,046,160 645,805
8 2013 14,003 1,674 881 6,545,148 1,047,834 646,687
9 2013 17,618 488 2,376 6,562,766 1,048,323 649,062
10 2013 18,177 0 2,971 6,580,943 1,048,323 652,033
11 2013 17,856 265 2,789 6,598,799 1,048,587 654,822
12 2013 18,821 303 2,877 6,617,621 1,048,891 657,699
2013 TOTAL 217,996 4,571 29,843
GKA Annual Surveillance Report Kuparuk Oil Pool 14
ATTACHMENT 4
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Kuparuk Oil Pool 15
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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1A-02 50029205990000 WAG 490100 AC 6036 - 6075, 5967 - 5976, 5933 - 5959, 5915 - 5931, 5897 - 5915, 5863 - 5890 12/29/13 720 SBHP 135 5924 2333 6200 0.441 2455 1A-03 50029206150000 O 490100 AC 6361 - 6391, 6351 - 6356, 6172 - 6191, 6068 - 6123 06/19/13 300 SBHP 159 6353 2133 6200 0.350 2079 1A-08 50029203130000 O 490100 AC 6117 - 6143, 6101 - 6111, 6018 - 6020, 5957 - 5968, 5934 - 5939, 5925 - 5930, 5885 - 5921 06/16/13 4000 SBHP 155 5744 2560 6200 0.290 2692 1A-10 50029206730000 WAG 490100 A 5961 - 5989, 5946 - 5952, 5771 - 5779 02/10/13 120 SBHP 135 5959 3010 6200 0.324 3088 1A-15 50029207110000 WAG 490100 A 6149 - 6159, 6108 - 6128, 6095 - 6101, 5994 - 6016, 5907 - 5973 06/12/13 144 SBHP 160 6114 4148 6200 0.445 4186 1A-16RD 50029207130100 WAG 490100 A 6120 - 6138, 6106 - 6112, 5993 - 6003, 5916 - 5963 11/02/13 168 SBHP 136 6048 2465 6200 0.440 2532 1A-17 50029221020000 O 490100 AC 6192 - 6203, 6151 - 6172, 5979 - 5992, 5900 - 5947 02/28/13 581 SBHP 156 6053 2389 6200 0.432 2453 1A-17 50029221020000 O 490100 A 6192 - 6203, 6151 - 6172, 5979 - 5992, 5900 - 5947 12/12/13 753 SBHP 140 6094 2610 6200 0.351 2647 1A-17 50029221020000 O 490100 C 6192 - 6203, 6151 - 6172, 5979 - 5992, 5900 - 5947 12/13/13 744 SBHP 154 6046 2453 6200 0.436 2520 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1A-18 50029221030000 O 490100 A 6303 - 6327, 6289 - 6293, 6142 - 6158, 6058 - 6102 10/05/13 879 SBHP 143 6292 3122 6200 0.420 3083 1A-19 50029221110000 O 490100 AC 6181 - 6204, 6168 - 6171, 6008 - 6026, 5910 - 5975 09/13/13 575 SBHP 153 5995 2444 6200 0.431 2532 1A-20 50029221120000 O 490100 A 6440 - 6468, 6425 - 6430, 6244 - 6261, 6207 - 6212, 6178 - 6194, 6150 - 6177 07/05/13 180 SBHP 159 6393 1453 6200 0.351 1385 1A-20 50029221120000 O 490100 A 6440 - 6468, 6425 - 6430, 6244 - 6261, 6207 - 6212, 6178 - 6194, 6150 - 6177 10/13/13 2891 SBHP 161 6393 1865 6200 0.351 1797 1A-23 50029221310000 O 490100 A 6115 - 6138, 6099 - 6103, 5961 - 5973, 5901 - 5920, 5857 - 5901 12/13/13 143 SBHP 155 5841 2311 6200 0.351 2437 1A-28 50029221260000 O 490100 AC 6181 - 6217, 6164 - 6172, 6002 - 6036 06/18/13 15000 SBHP 160 6163 3310 6200 0.429 3326 1B-09 50029206550000 WAG 490100 C 6503 - 6537, 6486 - 6499, 6319 - 6340, 6208 - 6271 06/21/13 1391 SBHP 160 6263 2642 6200 0.440 2614 1B-11 50029206570000 WAG 490100 C 6716 - 6742, 6702 - 6709, 6541 - 6561, 6417 - 6465 12/28/13 216 SBHP 132 6282 3051 6200 0.360 3021 1B-14 50029224520000 O 490100 AC 6504 - 6530, 6294 - 6309, 6175 - 6233 08/14/13 180 SBHP 148 6366 2515 6200 0.355 2456 1B-16 50029224570000 O 490100 AC 6578 - 6610, 6384 - 6391, 6367 - 6374, 6253 - 6309 07/28/13 580 SBHP 155 6430 2530 6200 0.420 2433 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1B-17 50029224610000 O 490100 C 6417 - 6452, 6324 - 6376 08/14/13 160 SBHP 152 6145 2265 6200 0.350 2284 1B-20 50029231640000 O 490100 A 6251 - 6278, 6229 - 6247, 6059 - 6103 04/15/13 542 SBHP 156 6263 1955 6200 0.350 1933 1C-01 50029205260000 O 490100 C 6700 - 6720, 6510 - 6524, 6362 - 6458 08/20/13 117 SBHP 153 6295 2660 6200 0.448 2617 1C-02 50029205320000 O 490100 C 6438 - 6457, 6329 - 6418 04/09/13 2101 SBHP 157 6447 2813 6200 0.546 2678 1C-07A 50029205690100 O 490100 C 6432 - 6414, 6414 - 6375 08/20/13 118 SBHP 157 6377 2882 6200 0.435 2805 1C-08 50029205850000 O 490100 C 6469 - 6489, 6409 - 6418, 6340 - 6405 08/20/13 117 SBHP 155 6165 2842 6200 0.382 2855 1C-10 50029208650000 WAG 490100 C 6403 - 6435, 6376 - 6399 03/04/13 411 SBHP 133 6405 3255 6200 0.453 3162 1C-11 50029227140000 O 490100 C 6415 - 6457 03/30/13 259 SBHP 153 6108 1907 6200 0.065 1913 1C-13 50029228560000 O 490100 C 6504 - 6522, 6347 - 6423 08/19/13 93 SBHP 158 6451 2563 6200 0.426 2456 1C-14A 50029228610100 WAG 490100 C 6454 - 6486 04/06/13 1099 SBHP 134 6085 3750 6200 0.441 3801 1C-16 50029229340000 O 490100 C 6468 - 6489 02/12/13 4556 SBHP 158 6479 3691 6200 0.325 3600 1C-16 50029229340000 O 490100 AC 6468 - 6489 03/23/13 5491 SBHP 159 6479 3717 6200 0.336 3623 1C-21 50029232530000 O 490100 C 6428 - 6429 08/20/13 112 SBHP 152 6348 2059 6200 0.323 2011 1C-23 50029229420000 O 490100 C 6434 - 6455 08/29/13 324 SBHP 156 6444 3081 6200 0.345 2997 1C-24 50029230630000 O 490100 C 6411 - 6419, 6397 - 6391, 6387 - 6382, 6380 - 6377, 6379 - 6405, 6371 - 6373, 6360 - 6366, 6340 - 6354, 6329 - 6339, 6322 - 6326 08/21/13 134 SBHP 154 6267 2302 6200 0.301 2282 1C-25 50029229410000 WAG 490100 C 6450 - 6462, 6370 - 6376, 6343 - 6364 09/27/13 3840 SBHP 137 6313 3133 6200 0.466 3080 1C-27 50029229430000 WAG 490100 C 6287 - 6350 08/13/13 2756 SBHP 139 6275 3611 6200 0.429 3579 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1D-01 50029203930000 O 490100 C 6380 - 6388, 6367 - 6374, 6355 - 6362, 6309 - 6351, 6294 - 6308 03/22/13 5262 SBHP 156 6340 3015 6200 0.359 2965 1D-04A 50029204160100 O 490100 C 6418 - 6356 08/24/13 222 SBHP 144 5907 2947 6200 0.309 3038 1D-06 50029204180000 WAG 490100 C 6547 - 6562, 6314 - 6401 10/25/13 299 SBHP 132 6355 3471 6200 0.499 3394 1D-07 50029204300000 WAG 490100 C 6012 - 6074 09/30/13 130 SBHP 134 6045 2879 6200 0.460 2950 1D-09 50029228750000 WAG 490100 C 6406 - 6411, 6396 - 6401, 6376 - 6384, 6365 - 6371, 6354 - 6362, 6310 - 6330, 6300 - 6304 12/06/13 72 SBHP 133 6344 3533 6200 0.466 3466 1D-28 50029232370000 O 490100 AC 6537 - 6531, 6524 - 6512, 6487 - 6520 03/23/13 234 SBHP 154 6359 3087 6200 0.457 3014 1D-30 50029229650000 O 490100 C 6428 - 6453 08/27/13 292 SBHP 153 6265 3100 6200 0.437 3072 1D-32 50029229820000 WAG 490100 C 6470 - 6488, 6455 - 6460, 6431 - 6436 12/10/13 165 SBHP 134 6403 3955 6200 0.420 3870 1D-34 50029229750000 O 490100 C 6446 - 6466, 6418 - 6430 11/12/13 4439 SBHP 145 6179 3373 6200 0.422 3382 1D-37 50029229920000 O 490100 C 6386 - 6391, 6340 - 6352 08/30/13 360 SBHP 148 5988 3036 6200 0.118 3061 1D-38 50029229610000 WAG 490100 C 6292 - 6312 12/11/13 193 SBHP 125 6301 3629 6200 0.405 3588 1D-40A 50029229690100 WAG 490100 C 6144 - 6165 05/08/13 31703 SBHP 139 6141 2303 6200 0.444 2329 1D-41 50029232880000 O 490100 C 6473 - 6506, 6501 - 6494, 6491 - 6490, 6485 - 6476 08/28/13 50 SBHP 145 6290 2720 6200 0.428 2681 1D-42 50029229790000 O 490100 C 6140 - 6160 08/28/13 313 SBHP 151 6088 2149 6200 0.455 2200 1E-02 50029204720000 O 490100 A 6209 - 6222, 6175 - 6195, 5973 - 6055 08/30/13 357 SBHP 154 6010 2621 6200 0.434 2704 1E-04 50029204780000 WAG 490100 AC 6061 - 6072, 6058 - 6061, 6027 - 6045, 5933 - 5947, 5859 - 5916 09/21/13 881 SBHP 134 5757 2648 6200 0.433 2840 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1E-05A 50029204790100 O 490100 A 6230 - 6291, 6134 - 6255 08/30/13 320 SBHP 148 5915 1447 6200 0.044 1460 1E-07A 50029204950100 O 490100 C 6263 - 6233, 6233 - 6136 08/30/13 332 SBHP 159 6278 2819 6200 0.430 2786 1E-08 50029204960000 WI 490100 A 6308 - 6345, 6287 - 6301, 6088 - 6161, 6342 - 6348, 6293 - 6299, 6265 - 6277 03/07/13 14890 SBHP 132 6157 3286 6200 0.432 3305 1E-08A 50029204960100 WAG 490100 A 6343 - 6349, 6294 - 6300, 6266 - 6278 03/27/13 14899 SBHP 142 6020 3287 6200 0.439 3366 1E-08A 50029204960100 WAG 490100 A 6343 - 6349, 6294 - 6300, 6266 - 6278 09/16/13 712 SBHP 135 6020 3896 6200 0.326 3955 1E-09 50029207200000 WI 490100 AC 6292 - 6298, 6269 - 6289, 6247 - 6255 08/13/13 136 SBHP 152 6280 2876 6200 0.851 2808 1E-12 50029207360000 O 490100 A 6254 - 6259, 6229 - 6248, 6211 - 6218 6167 - 6169 03/29/13 380 SBHP 158 6128 1543 6200 0.424 1574 1E-15 50029207690000 490100 A 6390 - 6332, 6270 - 6288, 6193 - 6209, 6084 - 6143 03/11/13 1101 SBHP 126 6022 3958 6200 0.429 4034 1E-15A 50029207690100 WI 490100 AC 6287 - 6256, 6193 - 6204, 6084 - 6143 03/11/13 1101 SBHP 132 6022 3986 6200 0.436 4064 1E-21 50029208920000 WAG 490100 AC 6205 - 6218, 6180 - 6192, 5961 - 6046 04/22/13 8332 SBHP 152 6191 2730 6200 0.435 2734 1E-22 50029208840000 WAG 490100 A 6130 - 6145, 5943 - 6017 04/25/13 3346 SBHP 156 6075 2972 6200 0.430 3026 1E-22 50029208840000 WAG 490100 C 6130 - 6145, 5943 - 6017 04/30/13 3316 SBHP 126 5975 2693 6200 0.430 2790 1E-22 50029208840000 WAG 490100 A 6130 - 6145, 5943 - 6017 05/01/13 144 SBHP 134 6075 2985 6200 0.350 3029 1E-24B 50029208570200 O 490100 A 6070 - 6223 08/29/13 300 SBHP 146 5748 2398 6200 0.398 2578 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1E-27 50029208370000 WAG 490100 A 6169 - 6172, 6139 - 6161, 6115 - 6124, 6027 - 6029, 5976 - 5983, 5926 - 5967 11/21/13 120 SBHP 127 6005 3818 6200 0.460 3908 1E-28 50029208320000 O 490100 AC 6264 - 6284, 6238 - 6247, 6136 - 6141, 6018 - 6101 05/17/13 140 SBHP 159 6260 2868 6200 0.350 2847 1E-28 50029208320000 O 490100 A 6264 - 6284, 6238 - 6247, 6136 - 6141, 6018 - 6101 09/08/13 925 SBHP 154 6078 3057 6200 0.433 3110 1E-28A 50029208320100 O 490100 A 6155 - 6248, 6136 - 6140, 6019 - 6102 09/08/13 925 SBHP 153 6078 3057 6200 0.433 3110 1E-29 50029208280000 O 490100 C 6151 - 6171, 6131 - 6140, 5939 - 6004 03/14/13 1606 SBHP 155 5967 2712 6200 0.438 2814 1E-29 50029208280000 O 490100 A 6151 - 6171, 6131 - 6140, 5939 - 6004 03/19/13 1720 SBHP 157 6027 3329 6200 0.400 3398 1F-08 50029208360000 WAG 490100 A 6002 - 6005, 5969 - 5994, 5943 - 5955 03/14/13 78000 SBHP 139 5973 3312 6200 0.350 3391 1F-09 50029209830000 O 490100 C 5954 - 5997, 5929 - 5940, 5811 - 5836 08/24/13 96 SBHP 157 5816 2958 6200 0.336 3087 1F-09 50029209830000 O 490100 A 5954 - 5997, 5929 - 5940, 5811 - 5836 08/26/13 144 SBHP 160 5902 2431 6200 0.350 2535 1F-12 50029210120000 O 490100 A 5948 - 5984, 5929 - 5937, 5808 - 5841 08/30/13 144 SBHP 154 5910 2225 6200 0.350 2327 1F-14 50029210220000 O 490100 AC 6186 - 6218, 6160 - 6172, 5999 - 6055 08/29/13 318 SBHP 161 6160 2467 6200 0.439 2485 1F-16A 50029210290100 WAG 490100 AC 5967 - 5988, 5821 - 5837, 5802 - 5818 04/19/13 50000 SBHP 141 5940 2959 6200 0.437 3073 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1F-16A 50029210290100 WAG 490100 A 5967 - 5988, 5821 - 5837, 5802 - 5818 10/02/13 740 SBHP 144 5828 3054 6200 0.433 3215 1F-16A 50029210290100 WAG 490100 A 5967 - 5988, 5821 - 5837, 5802 - 5818 10/20/13 224 SBHP 147 5729 2744 6200 0.350 2909 1F-17 50029226570000 O 490100 AC 6076 - 6103, 6054 - 6062, 5923 - 5946 08/27/13 264 SBHP 154 6090 2286 6200 0.335 2323 1F-18A 50029226540100 O 490100 AC 6012 - 5991, 5989 - 5982, 10/25/13 1824 SBHP 148 5695 2812 6200 0.373 3000 1F-19 50029226600000 O 490100 A 6255 - 6266, 6234 - 6249, 6209 - 6218 07/10/13 141 SBHP 125 4720 2071 6200 0.434 2714 1G-10A 50029210030100 O 490100 C 6514 - 6541, 6297 - 6304, 6285 - 6290, 6255 - 6275 01/26/13 2530 SBHP 153 6239 2629 6200 0.360 2615 1G-10A 50029210030100 O 490100 AC 6514 - 6541, 6297 - 6304, 6285 - 6290, 6255 - 6275 03/01/13 3346 SBHP 160 6414 2724 6200 0.350 2649 1G-10A 50029210030100 O 490100 AC 6514 - 6541, 6297 - 6304, 6285 - 6290, 6255 - 6275 04/09/13 4522 SBHP 156 6370 2974 6200 0.450 2897 1G-10B 50029210030200 O 490100 A 6489 - 6516, 6301 - 6308, 6289 - 6294, 6259 - 6278 08/27/13 264 SBHP 119 5127 1697 6200 0.331 2052 1G-13 50029210160000 O 490100 C 6277 - 6319, 6118 - 6131, 6040 - 6091 08/31/13 363 SBHP 142 5869 1996 6200 0.305 2097 1G-13 50029210160000 O 490100 A 6277 - 6319, 6118 - 6131, 6040 - 6091 09/03/13 459 SBHP 157 6228 2116 6200 0.351 2106 1H-04 50029207700000 WI 490100 C 6502 - 6523, 6491 - 6494, 6330 - 6358, 6236 - 6288 01/18/13 4113 SBHP 143 6379 3262 6200 0.438 3184 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1H-04 50029207700000 WI 490100 AC 6502 - 6523, 6491 - 6494, 6330 - 6358, 6236 - 6288 09/17/13 9913 SBHP 139 6514 2830 6200 0.432 2694 1H-07 50029207550000 WI 490100 C 6643 - 6660, 6629 - 6636, 6450 - 6471, 6357 - 6407 11/03/13 93 SBHP 136 6547 3538 6200 0.438 3386 1H-09 50029223450000 WI 490100 C 6585 - 6606, 6519 - 6533, 6445 - 6459 04/08/13 12548 SBHP 140 6526 3167 6200 0.443 3023 1H-09 50029223450000 WI 490100 C 6585 - 6606, 6519 - 6533, 6445 - 6459 09/17/13 9920 SBHP 137 6526 2970 6200 0.355 2854 1H-12 50029223540000 WI 490100 C 6632 - 6660, 6571 - 6579, 6553 - 6563, 6514 - 6548 04/13/13 53033 SBHP 160 6661 3088 6200 0.288 2955 1H-13 50029223560000 O 490100 C 6625 - 6658, 6561 - 6587, 6504 - 6554 03/19/13 134 SBHP 158 6548 2048 6200 0.136 2001 1H-16 50029223150000 O 490100 AC 6565 - 6586, 6392 - 6409, 6309 - 6359 03/20/13 162 SBHP 156 6446 2026 6200 0.429 1920 1H-18 50029223410000 WI 490100 C 6433 - 6457, 6321 - 6381 06/26/13 18142 SBHP 140 6388 2370 6200 0.441 2287 1H-19A 50029223120100 WI 490100 A 6470 - 6613 03/23/13 2160 SBHP 134 6393 3187 6200 0.350 3120 1J-03 50029230020000 O 490100 C 6491 - 6496, 6363 - 6369 12/08/13 2518 SBHP 145 6330 3261 6200 0.334 3218 1L-02 50029211930000 O 490100 AC 5993 - 5997, 5975 - 5986, 5941 - 5954, 5829 - 5847 08/22/13 145 SBHP 154 5706 2903 6200 0.432 3117 1L-04 50029211790000 O 490100 A 5981 - 6006, 5954 - 5967, 5856 - 5867 05/07/13 1733 SBHP 159 5966 2760 6200 0.335 2839 1L-05 50029211550000 WAG 490100 C 5987 - 6011, 5956 - 5970, 5830 - 5863 04/08/13 2113 SBHP 133 5777 3869 6200 0.377 4028 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1L-06 50029211640000 O 490100 C 6018 - 6021, 5999 - 6002, 5983 - 5990, 5956 - 5967, 5859 - 5870, 5795 - 5854 08/22/13 145 SBHP 153 5824 2488 6200 0.346 2618 1L-07 50029211710000 WAG 490100 C 5965 - 5969, 5927 - 5947, 5787 - 5833 04/18/13 2251 SBHP 119 5728 3174 6200 0.480 3400 1L-07 50029211710000 WAG 490100 A 5965 - 5969, 5927 - 5947, 5787 - 5833 04/20/13 5386 SBHP 129 5877 3344 6200 0.435 3485 1L-10 50029220260000 WAG 490100 AC 6076 - 6082, 6003 - 6028, 5916 - 5922, 5907 - 5912, 5842 - 5900 05/08/13 1306 SBHP 141 6040 2622 6200 0.413 2688 1L-11 50029220340000 O 490100 A 6120 - 6126, 6047 - 6067, 5937 - 5943, 5930 - 5933, 5887 - 5927 08/24/13 168 SBHP 157 5973 2292 6200 0.350 2371 1L-11 50029220340000 O 490100 C 6120 - 6126, 6047 - 6067, 5937 - 5943, 5930 - 5933, 5887 - 5927 08/25/13 196 SBHP 155 5941 2352 6200 0.317 2434 1L-13 50029221500000 O 490100 C 6028 - 6035, 5954 - 5972, 5819 - 5866 10/18/13 9217 SBHP 156 5927 3071 6200 0.425 3187 1L-17 50029221510000 WAG 490100 C 6020 - 6029, 5949 - 5968, 5832 - 5880 07/05/13 2950 SBHP 116 5885 3703 6200 0.445 3843 1L-19 50029220490000 O 490100 AC 6015 - 6030, 5948 - 5967, 5833 - 5840, 5826 - 5829, 5799 - 5823 08/21/13 130 SBHP 154 5964 2349 6200 0.253 2409 1L-20A 50029220270100 O 490100 C 6024 - 6042, 5867 - 5895 08/19/13 78 SBHP 146 5890 2448 6200 0.045 2462 1L-24 50029221700000 O 490100 C 6011 - 6024, 5954 - 5973, 5836 - 5866 08/13/13 1053 SBHP 153 5836 2945 6200 0.296 3053 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1L-28 50029229510000 O 490100 AC 6028 - 6046, 5862 - 5889, 5827 - 5850 08/19/13 78 SBHP 147 5745 2406 6200 0.351 2566 1L-29 50029221570000 O 490100 AC 6103 - 6107, 6040 - 6056, 5907 - 5925 08/23/13 169 SBHP 156 6050 2648 6200 0.475 2719 1Q-03A 50029212490100 O 490100 A 6660 - 6662, 6652 - 6658, 6642 - 6651, 6587 - 6629, 6486 - 6491, 6457 - 6467, 6409 - 6432 04/03/13 493 SBHP 160 6366 1773 6200 0.350 1715 1Q-06 50029212240000 O 490100 A 6223 - 6235, 6131 - 6167, 5996 - 6011, 5947 - 5978 04/27/13 10534 SBHP 154 6103 2703 6200 0.394 2741 1Q-10 50029212150000 O 490100 AC 6209 - 6218, 6155 - 6174, 6128 - 6146, 5993 - 6006, 5893 - 5953 09/02/13 2300 SBHP 150 5850 2557 6200 0.069 2581 1Q-11 50029212160000 WAG 490100 AC 6053 - 6064, 5957 - 6013, 5860 - 5865, 5787 - 5851 07/17/13 185 SBHP 103 5970 2706 6200 0.453 2810 1Q-16 50029213090000 O 490100 C 6147 - 6166, 6128 - 6141, 6067 - 6111, 5946 - 5955, 5893 - 5925 08/30/13 347 SBHP 154 6020 3527 6200 0.594 3634 1Q-20A 50029225890100 O 490100 A 6165 - 6180, 6158 - 6165, 6121 - 6122 04/12/13 476 SBHP 154 6164 2118 6200 0.378 2131 1R-07 50029213320000 O 490100 C 6617 - 6624, 6539 - 6566, 6523 - 6532, 6356 - 6382 01/19/13 6823 SBHP 153 6414 2349 6200 0.343 2276 1R-07 50029213320000 O 490100 A 6617 - 6624, 6539 - 6566, 6523 - 6532, 6356 - 6382 01/20/13 6817 SBHP 157 6562 2084 6200 0.314 1970 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1R-08 50029213330000 WAG 490100 AC 6641 - 6654, 6569 - 6598, 6557 - 6563, 6466 - 6470, 6382 - 6405 11/27/13 5737 SBHP 128 6450 3238 6200 0.440 3128 1R-16 50029213880000 O 490100 AC 6594 - 6609, 6531 - 6556, 6517 - 6523, 6383 - 6404 04/02/13 469 SBHP 154 6379 2129 6200 0.439 2050 1R-22A 50029222060100 O 490100 AC 6647 - 6654, 6631 - 6642, 6618 - 6629, 6461 - 6469 04/02/13 475 SBHP 155 6454 2870 6200 0.338 2784 1R-25 50029221530000 O 490100 C 6792 - 6799, 6614 - 6642 10/11/13 323 SBHP 165 6793 2722 6200 0.434 2465 1R-26 50029221930000 WAG 490100 AC 6682 - 6699, 6662 - 6672, 6495 - 6517 11/25/13 4500 SBHP 139 6677 3196 6200 0.465 2974 1R-29 50029221950000 O 490100 AC 6636 - 6647, 6613 - 6626, 6439 - 6461 01/07/13 1258 SBHP 157 6469 3333 6200 0.454 3211 1R-29 50029221950000 O 490100 A 6636 - 6647, 6613 - 6626, 6439 - 6461 08/26/13 248 SBHP 154 6469 1670 6200 0.360 1573 1R-34 50029225340000 O 490100 A 6618 - 6643 02/17/13 3716 SBHP 159 6560 4474 6200 0.419 4323 1R-34 50029225340000 O 490100 A 6618 - 6643 10/02/13 9156 SBHP 162 6610 4602 6200 0.445 4419 1R-35 50029230500000 O 490100 C 6657 - 6695, 6506 - 6520 10/16/13 17928 SBHP 156 6654 3859 6200 0.441 3659 1R-35 50029230500000 O 490100 C 6657 - 6695, 6506 - 6520 11/04/13 17928 SBHP 150 6436 2875 6200 0.614 2730 1Y-06A 50029209580100 O 490100 AC 6136 - 6149, 6092 - 6117, 5966 - 5973, 5875 - 5894 08/28/13 288 SBHP 152 5873 2281 6200 0.410 2415 1Y-07 50029209500000 WAG 490100 AC 6067 - 6078, 6029 - 6054, 6017 - 6021, 5925 - 5938, 5830 - 5911 11/23/13 306 SBHP 140 6020 2673 6200 0.446 2753 1Y-10 50029209340000 WAG 490100 AC 5934 - 5955, 5903 - 5921, 5890 - 5893, 5678 - 5760 06/13/13 215 SBHP 117 4365 1920 6200 0.439 2726 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1Y-18 50029223900000 O 490100 AC 6216 - 6245, 6195 - 6211, 6053 - 6065, 5952 - 6023 09/13/13 6159 SBHP 156 6219 2699 6200 0.426 2691 1Y-25 50029218500000 O 490100 A 6031 - 6055, 6001 - 6020, 5989 - 5993, 5820 - 5900 08/10/13 7852 SBHP 156 6018 2200 6200 0.350 2264 1Y-32 50029218540000 O 490100 AC 6061 - 6103, 6034 - 6050, 6021 - 6028 08/29/13 319 SBHP 155 6006 2755 6200 0.350 2823 1Y-34 50029223820000 O 490100 A 6027 - 6044, 6022 - 6027, 6006 - 6013 11/27/13 2860 SBHP 147 5998 1709 6200 0.350 1780 2A-03 50103200250000 WAG 490100 AC 5944 - 5975, 5921 - 5934, 5899 - 5901, 5810 - 5855 03/19/13 17331 SBHP 12 5739 2412 6200 0.382 2588 2A-08 50103200490000 WAG 490100 C 5806 - 5828, 5722 - 5770 04/01/13 144 SBHP 131 5763 2245 6200 0.351 2399 2A-08 50103200490000 WAG 490100 A 5806 - 5828, 5722 - 5770 04/02/13 144 SBHP 125 5786 3441 6200 0.351 3586 2A-11 50103200570000 O 490100 AC 5863 - 5884, 5844 - 5852, 5769 - 5794 09/07/13 185 SBHP 147 5436 1934 6200 0.433 2265 2A-23 50103201940000 WAG 490100 A 5778 - 5793, 5768 - 5778, 5735 - 5743 03/15/13 408 SBHP 130 5665 3392 6200 0.433 3624 2A-27A 50103206040100 WAG 490100 A 5859 - 5867, 5841 - 5851, 5830 - 5835, 5777 - 5804 02/21/13 1501 SBHP 155 5875 2814 6200 0.576 3001 2A-27A 50103206040100 WAG 490100 C 5859 - 5867, 5841 - 5851, 5830 - 5835, 5777 - 5804 02/27/13 1645 SBHP 153 5777 2581 6200 0.463 2777 2B-10 50029210840000 WAG 490100 AC 5883 - 5900, 5843 - 5862, 5828 - 5833, 5744 - 5775 02/02/13 15524 SBHP 125 5866 2962 6200 0.441 3109 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2B-10 50029210840000 WAG 490100 AC 5883 - 5900, 5843 - 5862, 5828 - 5833, 5744 - 5775 12/19/13 2976 SBHP 131 5866 2958 6200 0.440 3105 2B-11 50029210890000 WAG 490100 AC 5857 - 5876, 5824 - 5843, 5723 - 5743 12/30/13 3240 SBHP 121 5767 2940 6200 0.450 3135 2B-14 50029211430000 O 490100 AC 5843 - 5864, 5806 - 5828, 5792 - 5797, 5699 - 5725 12/25/13 120 SBHP 154 5606 2051 6200 0.280 2217 2B-15 50029211450000 O 490100 A 5812 - 5839, 5796 - 5802 12/27/13 168 SBHP 153 5648 2074 6200 0.420 2306 2C-01 50029209620000 WAG 490100 A 5820 - 5845, 5802 - 5809 07/31/13 5250 SBHP 134 5822 3777 6200 0.450 3947 2C-02 50029209720000 WAG 490100 A 5874 - 5881, 5830 - 5850, 5815 - 5819, 5711 - 5729 08/10/13 5490 SBHP 124 5787 3618 6200 0.480 3816 2C-04 50029209730000 WAG 490100 AC 5795 - 5819, 5755 - 5756, 5706 - 5712, 5696 - 5701, 5649 - 5675, 5633 - 5648, 5574 - 5576 08/10/13 8000 SBHP 132 5810 3011 6200 0.440 3183 2C-06 50029209790000 WAG 490100 AC 5874 - 5881, 5831 - 5851, 5813 - 5822, 5708 - 5729 08/02/13 4224 SBHP 119 5847 3162 6200 0.500 3339 2C-07 50029209750000 WAG 490100 A 5829 - 5857, 5812 - 5819, 5728 - 5743 07/30/13 7320 EXRT1 120 -123 1023 6200 0.419 3672 2C-12 50029212220000 O 490100 AC 5891 - 5899, 5816 - 5846, 5796 - 5805, 5738 - 5748 04/13/13 120 SBHP 160 5850 2443 6200 0.433 2594 2C-12 50029212220000 O 490100 AC 5891 - 5899, 5816 - 5846, 5796 - 5805, 5738 - 5748 10/02/13 120 SBHP 159 5850 2283 6200 0.420 2430 2D-01 50029211940000 O 490100 A 5879 - 5913, 5855 - 5867 07/10/13 760 SBHP 160 5854 3788 6200 0.190 3854 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2D-01 50029211940000 O 490100 A 5879 - 5913, 5855 - 5867 12/21/13 4632 SBHP 160 5854 4299 6200 0.447 4454 2D-08 50029211580000 O 490100 AC 5981 - 6012, 5954 - 5967, 5844 - 5866 09/05/13 2100 SBHP 162 5955 3113 6200 0.453 3224 2E-05 50029224230000 WI 490100 A 5973 - 5987, 5869 - 5894 06/16/13 367 SBHP 121 5976 4596 6200 0.423 4691 2E-07 50029223890000 O 490100 AC 5984 - 6002, 5886 - 5918 06/17/13 50000 SBHP 156 5962 3365 6200 0.380 3455 2E-08 50029224280000 O 490100 AC 5940 - 5961, 5867 - 5883 06/18/13 4290 SBHP 154 5953 1747 6200 0.351 1834 2E-09 50029212560000 O 490100 A 6082 - 6089, 6047 - 6063, 6007 - 6023, 4279 - 4280, 2579 - 2580 12/22/13 99999 SBHP 162 6067 3443 6200 0.441 3501 2E-12 50029212270000 WI 490100 A 5958 - 5964, 5921 - 5947, 5888 - 5903 06/18/13 408 SBHP 124 5917 4158 6200 0.403 4272 2E-14 50029212140000 WI 490100 A 5954 - 5963, 5925 - 5946, 5898 - 5915 06/17/13 396 SBHP 128 5923 4065 6200 0.451 4190 2F-17 50029227310000 O 490100 AC 5943 - 5956, 5913 - 5921, 5847 - 5854 01/10/13 5041 SBHP 143 5819 4194 6200 0.433 4359 2F-17 50029227310000 O 490100 AC 5943 - 5956, 5913 - 5921, 5847 - 5854 04/14/13 7304 SBHP 137 5819 3968 6200 0.438 4135 2F-17 50029227310000 O 490100 A 5943 - 5956, 5913 - 5921, 5847 - 5854 06/25/13 9000 SBHP 141 5855 3859 6200 0.439 4010 2F-18 50029227200000 O 490100 A 5927 - 5949, 5897 - 5906 02/09/13 16962 SBHP 159 5948 4227 6200 0.351 4315 2F-18 50029227200000 O 490100 A 5927 - 5949, 5897 - 5906 03/30/13 18133 SBHP 159 5948 4140 6200 0.430 4248 2F-18 50029227200000 O 490100 A 5927 - 5949, 5897 - 5906 04/18/13 18584 SBHP 158 5948 4149 6200 0.430 4257 2F-18 50029227200000 O 490100 A 5927 - 5949, 5897 - 5906 05/26/13 21000 SBHP 146 5627 3866 6200 0.351 4067 2F-19A 50029227280100 O 490100 A 5957 - 5999, 5976 - 5980, 5913 - 5943 12/18/13 81 SBHP 150 5795 1696 6200 0.350 1838 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2G-11 50029211490000 O 490100 AC 6034 - 6055, 6005 - 6019, 5930 - 5931, 5920 - 5926 04/11/13 16656 SBHP 158 5984 3529 6200 0.420 3620 2G-11 50029211490000 O 490100 AC 6034 - 6055, 6005 - 6019, 5930 - 5931, 5920 - 5926 06/27/13 18504 SBHP 157 5984 3504 6200 0.400 3590 2G-11A 50029211490100 O 490100 A 6005 - 6068 10/30/13 20504 SBHP 146 5754 3357 6200 0.450 3558 2G-12 50029211590000 O 490100 A 6008 - 6040, 5980 - 5995 06/18/13 234 EXRT1 155 -108 1150 6200 0.401 3680 2G-12 50029211590000 O 490100 A 6008 - 6040, 5980 - 5995 10/30/13 528 SBHP 112 6003 3197 6200 0.390 3274 2G-13 50029211600000 O 490100 A 6021 - 6041, 5996 - 6007 06/21/13 65000 SBHP 151 5851 3982 6200 0.351 4105 2G-13 50029211600000 O 490100 A 6021 - 6041, 5996 - 6007 08/31/13 66440 SBHP 150 5802 3831 6200 0.342 3967 2G-13 50029211600000 O 490100 A 6021 - 6041, 5996 - 6007 09/24/13 67280 SBHP 153 5892 3813 6200 0.355 3922 2G-13 50029211600000 O 490100 A 6021 - 6041, 5996 - 6007 10/25/13 68024 EXRT1 155 -99 1620 6200 0.355 3856 2G-13 50029211600000 O 490100 A 6021 - 6041, 5996 - 6007 12/12/13 69176 SBHP 155 6016 3973 6200 0.650 4092 2G-14 50029211610000 WAG 490100 A 5969 - 6000, 5942 - 5955 04/04/13 4512 SBHP 132 5987 4232 6200 0.470 4332 2G-17 50029231340000 O 490100 C 5984 - 5991 04/18/13 88032 SBHP 154 5988 3330 6200 0.340 3402 2H-01 50103200330000 WAG 490100 AC 5959 - 5986, 5942 - 5950, 5892 - 5909 04/27/13 4300 SBHP 119 5964 3819 6200 0.440 3923 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 05/11/13 322 EXRT1 160 -94 1730 6200 0.354 3958 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 05/29/13 754 EXRT1 155 -94 1725 6200 0.354 3953 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 06/04/13 898 EXRT1 155 -129 1725 6200 0.391 4200 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 07/29/13 6630 EXRT1 155 -94 1668 6200 0.392 4135 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 08/06/13 6798 EXRT1 155 -94 1675 6200 0.398 4180 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 09/20/13 7922 EXRT1 155 -94 1590 6200 0.398 4095 2H-01 50103200330000 WAG 490100 A 5959 - 5986, 5942 - 5950, 5892 - 5909 10/13/13 8500 SBHP 118 5964 3754 6200 0.360 3839 2H-01 50103200330000 WAG 490100 C 5959 - 5986, 5942 - 5950, 5892 - 5909 10/14/13 8450 SBHP 132 5830 3371 6200 0.320 3489 2H-01 50103200330000 WAG 490100 C 5959 - 5986, 5942 - 5950, 5892 - 5909 10/15/13 8531 EXRT1 155 -94 1240 6200 0.357 3487 2H-01 50103200330000 WAG 490100 C 5959 - 5986, 5942 - 5950, 5892 - 5909 11/13/13 9227 SBHP 135 5830 3338 6200 0.300 3449 2H-01 50103200330000 WAG 490100 C 5959 - 5986, 5942 - 5950, 5892 - 5909 11/20/13 9258 EXRT1 155 -94 1240 6200 0.360 3506 2H-03 50103200310000 WAG 490100 AC 5955 - 5975, 5923 - 5941, 5909 - 5913, 5853 - 5867 11/01/13 96 SBHP 127 5943 2871 6200 0.430 2981 2H-04 50103200270000 WAG 490100 A 6004 - 6012, 5994 - 6000, 5947 - 5974, 5932 - 5938, 5880 - 5890 05/03/13 11917 SBHP 160 5960 3900 6200 0.464 4011 2H-08 50103200460000 O 490100 A 5995 - 6000, 5981 - 5988 11/06/13 168 SBHP 157 5989 2959 6200 0.340 3031 2H-10 50103200510000 O 490100 A 6020 - 6035, 5971 - 5996, 5951 - 5962 02/11/13 29 SBHP 158 6006 2456 6200 0.420 2537 2H-10 50103200510000 O 490100 A 6020 - 6035, 5971 - 5996, 5951 - 5962 05/17/13 120 SBHP 159 5980 2406 6200 0.420 2498 2H-10 50103200510000 O 490100 A 6020 - 6035, 5971 - 5996, 5951 - 5962 06/16/13 840 SBHP 137 5973 3058 6200 0.430 3156 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2H-10 50103200510000 O 490100 A 6020 - 6035, 5971 - 5996, 5951 - 5962 10/19/13 3800 SBHP 156 5923 3375 6200 0.340 3469 2H-10 50103200510000 O 490100 A 6020 - 6035, 5971 - 5996, 5951 - 5962 11/15/13 4112 SBHP 151 5881 3560 6200 0.370 3678 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 05/29/13 332 EXRT1 155 -125 2265 6200 0.421 4928 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 06/04/13 481 EXRT1 155 -90 2219 6200 0.423 4880 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 08/06/13 1992 EXRT1 155 -90 1960 6200 0.386 4388 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 08/16/13 2256 EXRT1 155 -90 1910 6200 0.386 4338 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 09/24/13 3188 EXRT1 155 -90 1760 6200 0.391 4219 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 09/25/13 3215 SBHP 130 5994 4014 6200 0.410 4098 2H-13 50103200370000 WAG 490100 AC 6023 - 6044, 5989 - 6010, 5975 - 5979, 5941 - 5942, 5940 - 5940 10/16/13 3695 EXRT1 155 -90 1840 6200 0.376 4205 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2H-17 50103203290000 WAG 490100 AC 5988 - 6009, 5958 - 5977, 5945 - 5950, 5896 - 5913 06/22/13 900 SBHP 115 5952 3630 6200 0.440 3739 2K-03 50103201000000 WAG 490100 A 5994 - 6019 04/10/13 4018 SBHP 123 5995 3948 6200 0.438 4038 2K-03 50103201000000 WAG 490100 A 5994 - 6019 10/25/13 8735 EXRT1 155 -114 1520 6200 0.377 3900 2K-03 50103201000000 WAG 490100 A 5994 - 6019 11/25/13 9456 EXRT1 155 -114 1700 6200 0.362 3986 2K-03 50103201000000 WAG 490100 A 5994 - 6019 12/16/13 9984 EXRT1 155 -114 1536 6200 0.359 3803 2K-04 50103200990000 O 490100 AC 5976 - 5992, 5942 - 5951 09/15/13 312 SBHP 160 5976 2874 6200 0.400 2964 2K-05 50103200980000 O 490100 AC 5984 - 6014, 5963 - 5969, 5918 - 5923 06/06/13 3912 SBHP 126 5890 3884 6200 0.500 4039 2K-05 50103200980000 O 490100 AC 5984 - 6014, 5963 - 5969, 5918 - 5923 10/19/13 7152 SBHP 133 5991 3686 6200 0.450 3780 2K-05 50103200980000 O 490100 AC 5984 - 6014, 5963 - 5969, 5918 - 5923 10/25/13 7296 EXRT1 155 -123 1625 6200 0.328 3699 2K-05 50103200980000 O 490100 AC 5984 - 6014, 5963 - 5969, 5918 - 5923 11/25/13 8040 EXRT1 155 -123 1800 6200 0.356 4051 2K-05 50103200980000 O 490100 AC 5984 - 6014, 5963 - 5969, 5918 - 5923 12/16/13 8568 EXRT1 155 -123 1450 6200 0.356 3701 2K-06 50103201100000 WAG 490100 AC 6027 - 6056, 5978 - 5993 10/11/13 2900 SBHP 135 6003 3931 6200 0.330 3996 2K-06 50103201100000 WAG 490100 AC 6027 - 6056, 5978 - 5993 10/25/13 3243 EXRT1 155 -123 2255 6200 0.269 3956 2K-06 50103201100000 WAG 490100 AC 6027 - 6056, 5978 - 5993 11/23/13 3939 EXRT1 155 -123 2242 6200 0.228 3684 2K-09 50103201080000 O 490100 A 6038 - 6062 12/19/13 144 SBHP 160 6051 2342 6200 0.450 2409 2K-10 50103201060000 WAG 490100 A 6019 - 6054, 5997 - 6007 12/14/13 5112 EXRT1 155 -114 1719 6200 0.423 4390 2K-13A 50103201160100 WI 490100 A 6095 - 6094, 6094 - 6080 10/11/13 3576 SBHP 140 5936 3933 6200 0.440 4049 2K-13A 50103201160100 WI 490100 A 6095 - 6094, 6094 - 6080 10/25/13 3912 EXRT1 155 -123 1260 6200 0.427 3960 2K-13A 50103201160100 WI 490100 A 6095 - 6094, 6094 - 6080 11/23/13 4608 EXRT1 155 -123 1230 6200 0.427 3930 2K-13A 50103201160100 WI 490100 A 6095 - 6094, 6094 - 6080 12/12/13 5112 EXRT1 155 -123 1298 6200 0.427 3998 2K-14A 50103201120100 O 490100 A 6124 - 6129 02/04/13 336 SBHP 161 6034 2778 6200 0.390 2843 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2K-20 50103201200000 WAG 490100 A 6146 - 6168, 6119 - 6125 08/01/13 1872 SBHP 160 6125 3875 6200 0.450 3909 2K-23 50103201250000 WAG 490100 A 6095 - 6116, 6063 - 6083 10/25/13 3912 EXRT1 155 -123 1530 6200 0.422 4198 2K-23 50103201250000 WAG 490100 A 6095 - 6116, 6063 - 6083 11/22/13 4584 EXRT1 155 -123 1550 6200 0.422 4218 2K-23 50103201250000 WAG 490100 A 6095 - 6116, 6063 - 6083 12/12/13 5064 EXRT1 155 -123 1546 6200 0.422 4214 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 03/27/13 180 SBHP 157 5991 2039 6200 0.370 2116 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 05/06/13 1093 SBHP 1660 5991 2566 6200 0.300 2629 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 10/17/13 1530 SBHP 155 5991 2335 6200 0.360 2410 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 11/01/13 880 EXRT1 155 -114 1500 6200 0.076 1980 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 11/19/13 1312 EXRT1 155 -114 1490 6200 0.088 2046 2K-26 50103201260000 O 490100 A 6045 - 6066, 6014 - 6026, 5959 - 5963 12/12/13 1864 EXRT1 155 -114 1549 6200 0.096 2155 2M-05 50103201680000 WAG 490100 AC 5890 - 5910, 5860 - 5881 07/30/13 12552 SBHP 128 5863 4241 6200 0.470 4399 2M-14 50103201730000 WAG 490100 AC 6032 - 6057, 5994 - 6013, 5974 - 5985 10/12/13 12816 SBHP 135 6017 4352 6200 0.300 4407 2M-14 50103201730000 WAG 490100 AC 6032 - 6057, 5994 - 6013, 5974 - 5985 10/25/13 13128 EXRT1 155 -105 2140 6200 0.356 4385 2M-14 50103201730000 WAG 490100 AC 6032 - 6057, 5994 - 6013, 5974 - 5985 11/22/13 13800 EXRT1 155 -105 2190 6200 0.356 4435 2M-14 50103201730000 WAG 490100 AC 6032 - 6057, 5994 - 6013, 5974 - 5985 12/12/13 14280 EXRT1 155 -105 2206 6200 0.356 4451 2M-29 50103201830000 O 490100 AC 5999 - 6002, 5972 - 5997 10/06/13 6900 SBHP 158 5885 4269 6200 0.160 4319 2T-03A 50103200730100 O 490100 A 5680 - 5736 05/05/13 840 SBHP 151 5576 3060 6200 0.360 3285 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2T-06 50103200680000 O 490100 A 5754 - 5757, 5699 - 5723, 5693 - 5697, 5687 - 5690 07/06/13 192 SBHP 156 5670 1985 6200 0.350 2171 2T-08 50103200700000 O 490100 A 5703 - 5718, 5698 - 5702, 5688 - 5691 03/12/13 9792 SBHP 155 5689 3036 6200 0.360 3220 2T-20 50103202150000 O 490100 A 5729 - 5747, 5679 - 5708 02/03/13 220 SBHP 156 5657 2621 6200 0.430 2854 2T-23 50103202160000 O 490100 A 5733 - 5743, 5707 - 5718, 05/01/13 780 SBHP 160 5703 3789 6200 0.350 3963 2T-26 50103202230000 WAG 490100 A 5738 - 5744, 5719 - 5734, 5676 - 5706 11/22/13 192 SBHP 115 5691 3961 6200 0.340 4134 2T-30 50103202190000 O 490100 AC 5748 - 5761, 5711 - 5726, 5674 - 5680 05/19/13 316 SBHP 156 5675 3096 6200 0.350 3280 2T-32 50103202180000 WAG 490100 A 5683 - 5707 11/30/13 144 SBHP 125 5696 4565 6200 0.320 4726 2T-32 50103202180000 WAG 490100 A 5683 - 5707 12/22/13 672 SBHP 136 5696 4240 6200 0.330 4406 2T-37 50103202270000 O 490100 A 5718 - 5731 05/17/13 120 SBHP 156 5692 2679 6200 0.350 2857 2T-40 50103205280000 O 490100 A 5747 - 5755, 5733 - 5741 08/10/13 280 SBHP 155 5734 1727 6200 0.350 1890 2T-40 50103205280000 O 490100 A 5747 - 5755, 5733 - 5741 09/12/13 1770 SBHP 136 5722 2044 6200 0.350 2211 2T-40 50103205280000 O 490100 A 5747 - 5755, 5733 - 5741 10/28/13 1800 SBHP 156 5722 2190 6200 0.125 2250 2T-41 50103206750000 O 490100 A 5778 - 5821, 5690 - 5719 12/28/13 9999 SBHP 156 5808 3004 6200 0.350 3141 2U-01 50029212670000 O 490100 A 5938 - 5943, 5845 - 5892, 5740 - 5744, 5683 - 5738 09/27/13 72 SBHP 160 5867 2713 6200 0.465 2868 2U-03 50029212690000 WAG 490100 AC 5811 - 5844, 5802 - 5808, 5683 - 5721 10/02/13 150 SBHP 125 5735 3804 6200 0.350 3967 2U-07A 50029212830100 WAG 490100 A 5832 - 5835, 5815 - 5817, 5807 - 5810, 5797 - 5800, 5792 - 5795, 5731 - 5774 07/20/13 3288 SBHP 139 5720 3189 6200 0.350 3357 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2U-07A 50029212830100 WAG 490100 A 5832 - 5835, 5815 - 5817, 5807 - 5810, 5797 - 5800, 5792 - 5795, 5731 - 5774 08/25/13 4250 SBHP 135 5727 3226 6200 0.573 3497 2U-08 50029212840000 O 490100 C 5805 - 5838, 5797 - 5802, 5690 - 5715 09/17/13 140 SBHP 156 5700 2372 6200 0.350 2547 2U-08 50029212840000 O 490100 A 5805 - 5838, 5797 - 5802, 5690 - 5715 09/18/13 280 SBHP 159 5767 2865 6200 0.357 3020 2U-09 50029213010000 WAG 490100 A 5756 - 5783, 5708 - 5744 07/21/13 110 SBHP 158 5733 2350 6200 0.400 2537 2U-13 50029212610000 O 490100 A 5994 - 5998, 5968 - 5972, 5900 - 5935, 5890 - 5894, 5667 - 5738 11/01/13 360 SBHP 156 5799 2170 6200 0.367 2317 2U-14 50029212620000 WAG 490100 AC 5819 - 5852, 5673 - 5731 10/25/13 5620 SBHP 129 5750 2783 6200 0.245 2893 2V-04 50029210410000 WAG 490100 AC 5792 - 5818, 5777 - 5784, 5655 - 5700 04/27/13 5995 SBHP 129 5709 2807 6200 0.312 2960 2V-09 50029213000000 O 490100 AC 5828 - 5855, 5808 - 5818, 5735 - 5738, 5724 - 5729, 5666 - 5713 07/31/13 3210 SBHP 161 5816 2684 6200 0.423 2846 2V-09 50029213000000 O 490100 C 5828 - 5855, 5808 - 5818, 5735 - 5738, 5724 - 5729, 5666 - 5713 08/01/13 3 SBHP 154 5495 2320 6200 0.436 2627 2W-12 50029212400000 O 490100 AC 6037 - 6041, 6010 - 6017, 6000 - 6003, 5943 - 5984, 5793 - 5817 05/13/13 2160 SBHP 154 5899 3291 6200 0.540 3453 2X-06 50029209880000 WAG 490100 AC 5814 - 5840, 5790 - 5802, 5642 - 5686 06/19/13 29900 SBHP 129 5782 2335 6200 0.410 2506 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 2X-06 50029209880000 WAG 490100 C 5814 - 5840, 5790 - 5802, 5642 - 5686 06/20/13 30000 SBHP 135 5631 2317 6200 0.420 2556 2X-07 50029209910000 WAG 490100 AC 5906 - 5932, 5886 - 5895, 5699 - 5770 12/12/13 564 SBHP 130 5901 2895 6200 0.369 3005 2X-08 50029209920000 WAG 490100 A 5933 - 5986, 5777 - 5795, 5714 - 5768 11/02/13 395 SBHP 126 5959 3980 6200 0.440 4086 2Z-02 50029209600000 WAG 490100 A 5935 - 5967, 5920 - 5930, 5764 - 5804 07/30/13 24000 EXRT1 120 515 1543 6200 0.441 4050 2Z-13A 50029213600100 O 490100 C 6000 - 5993, 5967 - 5996, 5920 - 5925 01/11/13 35866 SBHP 154 5756 3041 6200 0.654 3331 2Z-13A 50029213600100 O 490100 A 6000 - 5993, 5967 - 5996, 5920 - 5925 04/01/13 10000 SBHP 160 5904 3122 6200 0.350 3226 3A-01 50029214120000 O 490100 AC 5991 - 6028, 5959 - 5980, 5856 - 5867 07/07/13 264 EXRT1 153 5796 3354 6200 0.350 3495 3A-03B 50029214320200 O 490100 A 6103 - 6121, 6064 - 6103 11/07/13 24456 SBHP 157 6092 3278 6200 0.350 3316 3A-14 50029214900000 WI 490100 A 6143 - 6148, 6084 - 6119, 6058 - 6074 04/20/13 15144 SBHP 97 6093 3410 6200 0.395 3452 3A-16 50029214920000 O 490100 A 6151 - 6191, 6123 - 6141, 6032 - 6043 07/01/13 72 SBHP 152 5891 2089 6200 0.350 2197 3A-17 50029226910000 O 490100 AC 6012 - 6036, 5964 - 5968, 5913 - 5924 07/09/13 504 SBHP 152 5871 4055 6200 0.350 4170 3B-10 50029213680000 WAG 490100 C 6168 - 6172, 6137 - 6153, 6097 - 6132, 6003 - 6009, 5965 - 5974, 5908 - 5945 12/10/13 4128 SBHP 126 6009 3673 6200 0.430 3755 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 3B-10 50029213680000 WAG 490100 A 6168 - 6172, 6137 - 6153, 6097 - 6132, 6003 - 6009, 5965 - 5974, 5908 - 5945 12/11/13 4128 SBHP 121 6118 3491 6200 0.350 3520 3C-07 50029213910000 WI 490100 AC 6446 - 6473, 6404 - 6430, 6294 - 6312 12/17/13 12162 SBHP 109 6436 3877 6200 0.391 3785 3C-08 50029213900000 O 490100 A 6589 - 6607, 6564 - 6574, 6541 - 6552 04/25/13 144 SBHP 161 6588 2654 6200 0.430 2487 3C-09 50029213550000 WI 490100 C 6484 - 6500, 6435 - 6469, 6356 - 6364, 6311 - 6322 03/04/13 304 SBHP 117 6282 3829 6200 0.440 3793 3C-09 50029213550000 WI 490100 A 6484 - 6500, 6435 - 6469, 6356 - 6364, 6311 - 6322 03/07/13 5011 PBU 113 6402 3939 6200 0.430 3852 3C-10 50029213560000 O 490100 AC 6501 - 6520, 6452 - 6485, 6338 - 6346 04/16/13 8092 SBHP 152 6259 3170 6200 0.399 3147 3C-11A 50029213570100 O 490100 A 6407 - 6429, 6371 - 6372, 6335 - 6344, 6320 - 6323 02/21/13 3090 SBHP 154 6372 3438 6200 0.461 3359 3F-15 50029215010000 WAG 490100 A 5871 - 5876, 5801 - 5844, 5768 - 5787, 5668 - 5675 12/31/13 336 SBHP 124 5822 4481 6200 0.440 4647 3G-07A 50103201270100 O 490100 A 5852 - 5868, 5823 - 5839, 5730 - 5777 05/19/13 4632 SBHP 157 5841 3312 6200 0.350 3437 3G-13 50103201370000 WAG 490100 A 5801 - 5826, 5751 - 5790 12/18/13 72 SBHP 135 5805 3761 6200 0.350 3899 3G-21A 50103201480100 O 490100 A 5769 - 5778, 5744 - 5751 10/05/13 96 SBHP 151 5464 2563 6200 0.350 2821 3G-24 50103201450000 WAG 490100 A 5748 - 5777 07/13/13 5736 SBHP 117 5765 3573 6200 0.350 3725 3G-24 50103201450000 WAG 490100 A 5748 - 5777 10/22/13 8040 SBHP 120 5765 3518 6200 0.350 3670 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 3H-05 50103200770000 O 490100 AC 5903 - 5919, 5882 - 5899, 5858 - 5874, 5794 - 5851 10/21/13 50952 SBHP 65 2791 2310 6200 0.350 3503 3H-06 50103200780000 WAG 490100 AC 5928 - 5944, 5894 - 5909, 5834 - 5884, 5822 - 5827 10/27/13 20784 SBHP 94 5882 3517 6200 0.350 3628 3H-12A 50103200880100 WAG 490100 A 5165 - 5169, 5983 - 5980 11/29/13 4224 SBHP 128 5974 3779 6200 0.350 3858 3H-22 50103200970000 WI 490100 A 6011 - 6023, 5988 - 6000, 5972 - 5984 05/25/13 21528 SBHP 106 5996 4043 6200 0.350 4115 3H-26 50103202080000 O 490100 AC 5884 - 5913, 5831 - 5859 07/10/13 336 SBHP 152 5795 3312 6200 0.350 3454 3H-26 50103202080000 O 490100 AC 5884 - 5913, 5831 - 5859 08/28/13 1512 SBHP 154 5871 3446 6200 0.350 3561 3H-28A 50103202360100 O 490100 AC 5846 - 5869 08/13/13 1320 SBHP 156 5758 3285 6200 0.350 3440 3H-33A 50103205780100 O 490100 A 6006 - 6068 06/11/13 744 SBHP 152 5924 2957 6200 0.350 3054 3H-33A 50103205780100 O 490100 A 6006 - 6068 09/28/13 733 SBHP 150 5924 3579 6200 0.350 3676 3H-34 50103206430000 O 490100 A 5983 - 6080 07/18/13 240 SBHP 146 5987 3080 6200 0.470 3180 3H-34 50103206430000 O 490100 A 5983 - 6080 09/29/13 72 SBHP 146 5679 2656 6200 0.350 2838 3I-11A 50029219320100 O 490100 A 6142 - 6176 02/04/13 4824 SBHP 150 5932 4363 6200 0.350 4457 3I-11A 50029219320100 O 490100 A 6142 - 6176 06/09/13 6936 SBHP 149 5932 4359 6200 0.350 4453 3J-02 50029213980000 WI 490100 AC 6200 - 6211, 6186 - 6198, 6158 - 6173, 6151 - 6153, 6036 - 6040, 6026 - 6033 12/10/13 816 SBHP 121 6081 4494 6200 0.440 4546 3J-04 50029214000000 WI 490100 AC 6186 - 6216, 6142 - 6172, 6064 - 6067, 6017 - 6042, 5986 - 5998 04/17/13 9285 SBHP 125 6101 3474 6200 0.375 3511 3K-09B 50029216560200 O 490100 A 6659 - 6659, 6658 - 6578 08/20/13 960 PBU 155 6321 3867 6200 0.350 3825 3K-23 50029227710000 O 490100 A 6501 - 6603 03/21/13 4351 SBHP 157 6409 4122 6200 0.421 4034 3K-26 50029227640000 WI 490100 A 6675 - 6694, 6644 - 6662 12/08/13 5856 SBHP 128 6667 4937 6200 0.450 4727 3K-34 50029228790000 WI 490100 A 6622 - 6646, 6583 - 6606 03/06/13 1608 SBHP 127 6633 4256 6200 0.470 4053 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 3K-34 50029228790000 WI 490100 A 6622 - 6646, 6583 - 6606 12/06/13 1608 SBHP 127 6633 4256 6200 0.470 4053 3M-06 50029217070000 WI 490100 A 6185 - 6188, 6160 - 6180, 6141 - 6150 06/10/13 13992 SBHP 92 6164 4775 6200 0.350 4787 3M-09 50029217100000 O 490100 A 6278 - 6308, 6244 - 6276, 6227 - 6238, 6173 - 6198 10/10/13 288 SBHP 157 6188 2422 6200 0.330 2426 3M-14 50029217260000 O 490100 A 6190 - 6207 07/25/13 748 SBHP 150 6177 4546 6200 0.610 4560 3M-21 50029217390000 WI 490100 AC 6234 - 6257, 6214 - 6231, 6201 - 6211, 6146 - 6167 04/16/13 5541 SBHP 119 6225 4027 6200 0.440 4016 3M-22 50029217400000 O 490100 AC 6198 - 6223, 6174 - 6187, 6159 - 6171, 6128 - 6140 08/07/13 7368 SBHP 156 6176 4139 6200 0.440 4150 3M-23 50029224260000 O 490100 AC 6129 - 6149, 6112 - 6123, 6092 - 6107 05/31/13 2277 SBHP 156 6088 3837 6200 0.440 3886 3N-01 50029215190000 O 490100 A 6278 - 6305, 6259 - 6271 09/15/13 16200 SBHP 155 6281 3639 6200 0.420 3605 3N-02A 50029215270100 O 490100 AC 6373 - 6398, 6349 - 6365, 6256 - 6265 10/27/13 13680 SBHP 138 5703 3697 6200 0.350 3871 3N-06 50029215380000 O 490100 A 6372 - 6391, 6352 - 6359, 6270 - 6284 08/26/13 53280 SBHP 158 6371 4277 6200 0.440 4202 3N-08A 50029215400100 WI 490100 AC 6348 - 6353, 6313 - 6338, 6292 - 6311, 6227 - 6236 07/01/13 15313 SBHP 106 6624 3718 6200 0.350 3570 3N-13 50029215840000 WI 490100 AC 6407 - 6432, 6375 - 6393, 6358 - 6369, 6303 - 6318 04/16/13 16504 SBHP 100 6367 3026 6200 0.440 2952 3N-14A 50029215890100 O 490100 A 6342 - 6359, 6314 - 6326 04/16/13 330 SBHP 156 6313 2479 6200 0.420 2432 3N-14A 50029215890100 O 490100 A 6342 - 6359, 6314 - 6326 11/12/13 5376 SBHP 155 6211 3532 6200 0.350 3528 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: Kuparuk River Oil Pool 5. Datum Reference: -6200' SS 6. Oil Gravity: 0.91 (water = 1.0)7. Gas Gravity: 0.71 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 3N-15 50029215920000 O 490100 A 6462 - 6472, 6444 - 6460, 6423 - 6436 06/29/13 984 SBHP 158 6400 3357 6200 0.440 3269 3N-19 50029230560000 O 490100 A 6402 - 6385, 6318 - 6322 09/07/13 96 SBHP 156 6279 1613 6200 0.350 1585 3O-02A 50029218370100 O 490100 A 6533 - 6516, 6517 - 6488, 6513 - 6533 05/31/13 288 SBHP 160 6070 3421 6200 0.350 3467 3O-04 50029218260000 O 490100 A 6499 - 6514 08/24/13 37752 SBHP 161 6508 4119 6200 0.480 3971 3O-05 50029218390000 WAG 490100 A 6644 - 6659, 6615 - 6632, 6600 - 6610 10/03/13 192 SBHP 113 6628 5218 6200 0.350 5068 3O-06 50029218240000 WAG 490100 A 6553 - 6569, 6527 - 6547, 6513 - 6521 10/12/13 3432 SBHP 118 6529 4203 6200 0.250 4121 3O-08 50029218280000 O 490100 A 6645 - 6661, 6616 - 6634, 6598 - 6611 08/06/13 144 SBHP 166 6617 3178 6200 0.440 2994 3O-11 50029218050000 O 490100 A 6525 - 6542, 6495 - 6513, 6479 - 6488 05/28/13 192 SBHP 163 6534 3230 6200 0.460 3076 3O-12 50029218040000 WAG 490100 A 6607 - 6627, 6571 - 6595, 6557 - 6567, 6507 - 6517 12/17/13 120 SBHP 120 6496 5167 6200 0.420 5043 3O-13 50029218030000 O 490100 A 6618 - 6635, 6583 - 6608 05/29/13 216 SBHP 161 6556 2746 6200 0.320 2632 3O-15 50029217970000 O 490100 A 6417 - 6431, 6388 - 6403, 6375 - 6384 05/31/13 288 SBHP 154 6186 2864 6200 0.430 2870 3O-16A 50029217960100 WAG 490100 AC 6478 - 6495, 6446 - 6463, 6431 - 6439, 6421 - 6429, 6385 - 6393 03/19/13 8834 SBHP 112 6439 4009 6200 0.438 3904 3O-18 50029217930000 O 490100 A 6610 - 6626, 6567 - 6599, 6536 - 6559, 6493 - 6523, 6467 - 6485 05/29/13 216 SBHP 159 6531 2759 6200 0.220 2686 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
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ATTACHMENT 5
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Injectivity Profiles
GKA Annual Surveillance Report Kuparuk Oil Pool 47
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ATTACHMENT 5 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2013 ANNUAL SUBMITTAL WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD 1B-05 0292023700 - 00 10/31/94 09/26/13 SPINNER A/C SPLITS Triple AC 6160 A 840 1E-23 0292085800 - 00 5/31/83 02/11/13 SPINNER A/C SPLITS Single AC 5150 A 258 1F-02 0292088100 - 00 10/31/85 03/02/13 SPINNER A/C SPLITS Single Selective AC 3200 A 2142 1G-05 0292090800 - 00 12/31/87 03/27/13 SPINNER A/C SPLITS Triple AC 3400 A 0 1Q-12 0292121000 - 00 10/31/85 10/10/13 SPINNER A/C SPLITS Single Selective AC 1906 A 602 2A-27A 1032060401 - 00 3/31/13 09/03/13 SPINNER A/C SPLITS Single AC 2954 A 1000 2H-16 1032003500 - 00 2/28/86 11/08/13 SPINNER A/C SPLITS Single Selective AC 4070 A 1261 2M-34 1032024200 - 00 10/31/96 05/28/13 SPINNER A/C SPLITS Single AC 2160 A 1123 2U-11 0292130300 - 00 4/30/86 11/03/13 SPINNER A/C SPLITS Single Selective AC 4000 A 3000 2X-07 0292099100 - 00 11/30/85 09/30/13 SPINNER A/C SPLITS Single Selective AC 8939 A 983 2Z-08 0292092400 - 00 11/30/85 01/18/13 SPINNER FOLLOW-UP Single Selective AC 1500 A 204 2Z-09 0292137700 - 00 11/30/85 01/20/13 SPINNER FOLLOW-UP Single Selective AC 5520 A 480 12 >>Total IPROF Count for 2013 GKA Annual Surveillance ReportKuparuk Oil Pool51
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ATTACHMENT 6
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Productivity Profiles
GKA Annual Surveillance Report Kuparuk Oil Pool 53
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WELL APIDATE OF DATE OF DATA TYPEREASON FORWELLZONESPRODUCTIONNUMBER NUMBERINITIALPROFILE/ PROFILE/PROFILE/COMPLETION PROD- OIL WATER GAS50-PRODUCTION SURVEY SURVEYSURVEYTYPEUCING BOPD BWPD MSCFD1E-29 0292298400 - 00 10/31/8210/15/13 SPINNER A/C SPLITSSingle SelectiveAC75 1484 218A0246291F-17 0292247500 - 00 7/31/9611/05/13 SPINNER A/C SPLITSSingleAC233 356 240A226 336 2161G-07 0292047700 - 00 1/31/8312/13/13 SPINNER A/C SPLITSSingle SelectiveAC228 1925 64A0001G-12 0292130900 - 00 12/31/8312/17/13 SPINNER A/C SPLITSSingle SelectiveAC200 2000 95A0001R-02 0292138800 - 00 11/30/8510/25/13 SPINNER A/C SPLITSSingle SelectiveAC87320 195A434421R-05 0292237900 - 00 7/31/8501/07/13 SPINNER A/C SPLITSSingle SelectiveAC239 2723 222A5042G-11A 0292185100 - 00 12/31/1310/31/13 SZTCLOSE C SANDSSingleA601 399 4132K-07 1032019300 - 00 12/31/8901/26/13 SPINNER A/C SPLITSSingleAC195 31966A5151172M-12 0292113800 - 00 2/28/9305/27/13 SPINNER A/C SPLITSSingleAC226 3094 422A189 1082 712U-10 1032005000 - 00 5/31/8512/22/13 SPINNER A/C SPLITSSingle SelectiveAC375 4523 567A400 690 9352U-12 1032005300 - 00 5/31/8510/27/13 SPINNER A/C SPLITSSingle SelectiveAC325 3000 240A200 630503B-04 1032017100 - 00 6/30/8510/28/13 SPINNER A/C SPLITSSingle SelectiveAC556 1915 754A229 527 274ATTACMENT 6ANNUAL 2013 SUBMITTALRULE 9 - PRODUCTIVITY PROFILESCONSERVATION ORDER 432KUPARUK RIVER OIL POOLKUPARUK RIVER UNITGKA Annual Surveillance ReportKuparuk Oil Pool55
WELL APIDATE OF DATE OF DATA TYPEREASON FORWELLZONESPRODUCTIONNUMBER NUMBERINITIALPROFILE/ PROFILE/PROFILE/COMPLETION PROD- OIL WATER GAS50-PRODUCTION SURVEY SURVEYSURVEYTYPEUCING BOPD BWPD MSCFDATTACMENT 6ANNUAL 2013 SUBMITTALRULE 9 - PRODUCTIVITY PROFILESCONSERVATION ORDER 432KUPARUK RIVER OIL POOLKUPARUK RIVER UNIT3F-10 1032006000 - 00 2/28/8611/06/13 SPINNER A/C SPLITSSingle SelectiveAC161 4872 463A0003F-19A0292121100 - 00 4/30/0404/11/13 SPINNER A/C SPLITSSingleAC101 4060 359A643723914>> Total PPROF Count for 2013GKA Annual Surveillance ReportKuparuk Oil Pool56
Attachment 7
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Miscible Injectant Composition
Miscible Injectant (MI) is manufactured at CPF‐1 and CPF‐2. The compositions of both the lean gas, enriching
fluids (NGLs) and the resulting MI are measured periodically throughout the year to ensure that the MI meets
the design Minimum Miscible Pressure (MMP). The detailed compositional analysis of the MI from each CPF is
provided in tabular form on the following pages, together with the Minimum Miscible Pressures (MMP). The
target MMP is 3300 psia. A lower MMP means higher NGL content in MI.
GKA Annual Surveillance Report Kuparuk Oil Pool 57
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KUPARUK RIVER UNIT MI COMPOSITION : CPF-1Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+MMP (Calc), psia1/11/2013 CPF-1 1.117 0.324 69.061 6.691 4.947 3.108 7.598 2.350 1.949 2.140 1.197 0.959 3,098 2/1/2013 CPF-1 1.048 0.315 69.447 6.438 4.647 2.855 7.573 2.436 2.003 2.263 1.286 1.052 3,090 3/5/2013 CPF-1 1.149 0.306 68.783 6.583 4.970 3.136 7.764 2.481 2.067 2.173 1.169 0.874 3,052 3/19/2013 CPF-1 1.047 0.279 61.752 6.302 5.375 3.849 10.637 3.395 2.834 2.984 1.626 1.245 1,848 3/28/2013 CPF-1 1.210 0.318 70.102 6.765 5.107 3.103 7.458 2.119 1.808 1.765 0.953 0.821 3,332 4/20/2013 CPF-1 1.912 0.550 66.572 7.034 5.900 3.393 8.364 2.524 2.168 2.131 1.106 0.810 2,754 5/12/2013 CPF-1 1.236 0.291 66.484 6.798 5.728 3.414 8.401 2.547 2.152 2.291 1.252 0.931 2,737 5/24/2013 CPF-1 1.181 0.299 66.989 6.569 5.423 3.334 8.243 2.553 2.132 2.292 1.304 1.161 2,747 6/10/2013 CPF-1 1.290 0.341 71.720 6.767 5.063 2.911 6.575 1.902 1.596 1.674 0.986 0.807 3,573 6/22/2013 CPF-1 1.173 0.285 63.507 6.587 5.985 3.631 9.513 2.974 2.520 2.596 1.473 1.214 2,203 7/22/2013 CPF-1 1.053 0.246 55.393 5.639 4.990 4.008 11.626 4.438 3.549 4.639 2.952 2.766 366 9/20/2013 CPF-1 1.049 0.291 59.101 6.142 5.459 4.109 11.040 3.697 2.989 3.596 2.118 1.750 1,288 10/4/2013 CPF-1 0.987 0.245 57.440 5.986 5.382 4.894 11.608 3.994 3.198 4.376 2.267 0.854 1,083 11/2/2013 CPF-1 1.225 0.399 71.086 6.823 5.602 2.932 6.877 1.989 1.745 1.636 0.736 0.573 3,561 11/12/2013 CPF-1 1.097 0.264 60.593 6.370 6.008 3.820 9.752 3.431 2.883 3.472 1.824 1.847 1,572 12/13/2013 CPF-1 1.174 0.287 66.316 6.739 6.086 3.347 8.322 2.446 2.301 2.386 1.112 0.946 2,729 **AverageMMP Target2,440 3,300 KUPARUK RIVER UNIT MI COMPOSITION : CPF-2Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+ MMP (Calc), psia1/11/2013 CPF-2 0.906 0.237 68.900 7.593 5.012 2.954 7.284 2.235 1.766 2.026 1.197 1.034 3,176 1/22/2013 CPF-2 0.954 0.234 69.060 7.624 5.008 2.824 7.146 2.214 1.744 2.044 1.234 1.101 3,184 2/3/2013 CPF-2 0.889 0.223 68.655 7.404 4.691 2.856 7.372 2.442 1.911 2.257 1.322 1.091 3,067 3/22/2013 CPF-2 0.978 0.250 69.730 7.399 4.736 2.695 7.262 2.256 1.780 2.053 1.177 0.911 3,275 3/28/2013 CPF-2 0.999 0.263 69.276 7.725 5.157 2.828 7.229 2.128 1.689 1.894 1.120 0.955 3,270 4/20/2013 CPF-2 1.059 0.252 67.750 7.623 5.079 2.962 7.656 2.404 1.894 2.192 1.315 1.127 2,958 5/12/2013 CPF-2 1.025 0.245 68.460 7.094 4.592 3.222 7.646 2.401 1.864 2.288 1.356 1.077 3,002 5/23/2013 CPF-2 1.084 0.243 71.839 8.151 6.296 2.407 5.988 1.693 1.411 1.291 0.602 0.321 3,905 6/10/2013 CPF-2 0.966 0.232 66.226 7.146 4.890 3.307 8.666 2.608 2.052 2.414 1.467 1.225 2,650 6/22/2013 CPF-2 0.980 0.232 67.534 7.405 5.041 2.825 7.864 2.433 1.910 2.263 1.429 1.298 2,873 7/20/2013 CPF-2 1.026 0.250 70.201 7.233 4.792 2.534 6.878 2.180 1.728 2.043 1.266 1.145 3,291 9/20/2013 CPF-2 0.989 0.322 69.977 7.348 5.019 2.747 7.124 2.091 1.654 1.877 1.142 1.021 3,325 10/4/2013 CPF-2 0.973 0.250 70.737 7.287 4.848 2.900 6.849 2.068 1.625 2.103 1.124 0.459 3,491 11/2/2013 CPF-2 0.989 0.305 69.211 7.219 4.867 3.110 7.431 2.217 1.761 2.007 1.102 1.074 3,184 11/19/2013 CPF-2 1.035 0.255 70.041 7.447 5.080 2.802 6.820 2.103 1.668 1.993 1.078 0.969 3,348 12/18/2013 CPF-2 1.007 0.234 70.307 7.570 5.116 2.886 7.008 1.818 1.610 1.813 0.956 0.916 3,443 AverageMMP Target3,215 3,300 GKA Annual Surveillance ReportKuparuk Oil Pool59** MMP at CPF-1 is low due to facility turnaround and equipment constraints.
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Attachment 8
Kuparuk River Unit Kuparuk
River Oil Pool
2013 Annual Reservoir Surveillance Report LSEOR
Development Plan
During 2013, the Greater Kuparuk Area (GKA) averaged 13,157 BPD of PBU NGL imports and 7,490 BPD of
indigenous NGLs for an annual average of 141 MMSCFD of Miscible Injectant (MI) manufactured. Of the total
MI production in 2013, 109 MMSCFD was injected into the Kuparuk Field. Within the main Kuparuk Field, the
109 MMSCFD was allocated as: 3 MMSCFD for the SSEOR and SSEORX drillsites, 31 MMSCFD to the LSEOR
drillsites and 75 MMSCFD to the LSEOR expansion drillsites. LSEOR expansion drillsites include drillsites: 1B, 1C,
1D, 1E, 1L, 3B, 3G, 3H, 3O, 3Q, and 3S.
Further drilling activity in the Kuparuk River Oil Pool potentially provides new opportunities to maximize field
recovery while preventing physical waste. Drilling opportunities, along with their associated miscible gas EOR
potential, are under constant evaluation as the field matures, geologic and reservoir performance
information is assimilated, and as technology improves. Although drillsite 1D is the only recent drillsite‐level
expansion project, the Kuparuk EOR project may be expanded to include any new wells.
GKA Annual Surveillance Report Kuparuk Oil Pool 61
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MELTWATER
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ATTACHMENT 1
Meltwater Oil
Pool
2013 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.
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 uses Kuparuk spec MI which is injected above the
minimum miscibility pressure. In 2009 the water injection line to Meltwater was proactively shut in due to
internal corrosion and the field is currently on MI flood only. For compositional analysis of the Kuparuk spec MI,
refer to Attachment 7 of the Kuparuk section of the annual surveillance report.
The Meltwater field currently has 19 total wells (13 producers and 6 injectors). See Attachment 8 for well
locations.
Progress of EOR Project
Development activities in 2013 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 2013:
1. Water injection ceased in the Meltwater Field on October 15, 2009. On this date the water
injection line to the Meltwater field was declared unsuitable for continued operation due to internal
corrosion. Miscible gas injection continues to maintain voidage replacement for production in the field.
At this time there are no near‐term plans to restore water injection service to Meltwater.
ConocoPhillips does not anticipate any recovery impacts as little pressure support has been
observed to date from water injection. Studies are ongoing to determine the future development
options for the highly compartmentalized Meltwater reservoir in light of the de‐rated water injection
pipeline.
2. Due to the high reservoir pressure and lack of clear interactions with offset producers, injection well 2P‐
434 was shut in August 2007. In June of 2008, two additional injection wells, 2P‐419 and 2P‐432, were
shut in. In order to facilitate pressure reductions that would allow wells to potentially be safely
sidetracked in this area of the reservoir, it was decided to flowback injector 2P‐432 through the surface
header facilities of the long term shut‐in producer 2P‐438. The initial goal of the project was to reduce
pressure in the area to less than 3,300 psi. Well 2P‐432, with a bottom hole pressure of 4,366 psi began
flowback in February 2009. Shut‐in bottom hole pressure for this well was 3,021 psi as of September
2010. The flowback of 2P‐432 was discontinued in May 2011 after meeting the stated project objectives.
In December 2012 well 2P‐432 was brought back online to increase throughput in the 2P produced oil
(PO) line and is expected to remain online through the winter months of 2014. This flowback at 2P‐432
contributes to higher fluid velocities in the produced oil line helping to minimize corrosion in this
valuable pipeline and higher temperatures will reduce backpressure at the drillsite thereby minimizing
GKA Annual Surveillance Report Meltwater Oil Pool 67
production impacts. Oil production from 2P‐432 is currently at 350 bopd but the well is expected to be
shut in by the spring of 2014 to optimize the Meltwater MI flood due to a direct connection between 2P‐
432 and its offset injectors 2P‐434 and 2P‐429. The 2P‐432 well test gas oil ratios (GOR) are currently
relatively low. As the GOR increases the well will be shut in.
3. A total of five wells, including two producers, are currently shut‐in. Well 2P‐415A was brought online in
December of 2013 following the completion of a project to convert the well to MI lift. Well 2P‐451 is
currently online, but is only produced during the winter months to provide additional rate to the 2P
produced oil line. Well 2P‐451 is only able to be produced intermittently due to insufficient pressure
support (reservoir compartmentalization). Well 2P‐438 suffered early water breakthrough in 2007 and
has been shut in since. Well 2P‐443 is currently online to test the reservoir connectivity, but was shut in
during 2013 due to a historically high GOR and indications of rapid response from the injector 2P‐420.
Well 2P‐443 has a history of severe paraffin deposition and freezing problems and it will be an
intermittent producer for the foreseeable future. Well 2P‐449 was shut in November of 2013 due to a
lack of reservoir pressure support and significant gas breakout. The adjacent injectors, 2P‐419 and 2P‐
447, have been shut in since 2012 due to a lack of injectivity. Similar to well 2P‐451, well 2P‐448A is an
intermittent producer that was shut in during the summer months, but was brought online in November
to add additional rate to the 2P produced oil line. Well 2P‐448A is only able to be produced
intermittently due to insufficient pressure support (reservoir compartmentalization).
Significant Studies in Progress
1. Work is ongoing to rebuild the Meltwater subsurface model. Much of the work involves analyzing the
new seismic data obtained during winter 2007‐2008. The analysis of this 4D seismic data should provide
a better interpretation of the reservoir architecture and communication between producers and
injectors. Preliminary studies of certain 4D effects, such as changes in amplitudes and velocities, show
clear trends of anomalies that match the location of active injectors and trend in a NNW‐SSE direction.
The hydraulic significance of these trends cannot be fully understood from seismic analysis and an
extensive pressure monitoring and well interaction analysis was implemented in 2013 to understand
their significance to development planning.
The direction of the anomalies observed in the new seismic data coincides with the direction of
preferential flow from injectors to producers that has been identified at the Tarn and Meltwater fields
by means of production surveillance and well interaction analyses. Producers aligned on this trend
with injectors are susceptible to early water breakthrough.
2. As mentioned earlier in this document, a flowback from the injection well 2P‐432 was started in
February 2009 in an attempt to decrease reservoir pressures to levels at which sidetracks could be
drilled. Well 2P‐432 initially flowed at approximately 3,000 bpd with 100% water showing only traces of
oil and gas. Pressure surveys early in 2009 indicated no change in reservoir pressure. In addition, the
three injection wells (2P‐429, 2P‐432, and 2P‐434) along the central anomaly showed nearly identical
reservoir pressures suggesting they were hydraulically connected. When injection water supply to
Meltwater ceased on October 15, 2009, the injection well 2P‐429 that was still injecting water at that
time was shut in. After an initial spike in oil production, watercut stabilized at ~90% while gas‐oil ratio
increased. This confirmed the hydraulic connection and these three wells effectively act as one line‐drive
injector when on water injection service.
The last pressure survey (July 13, 2013) showed that the pressure has decreased to approximately
2,542psi after water injection in well 2P‐429 was discontinued. The flowback at 2P‐432 contributes to
higher fluid velocities in the produced oil line helping to minimize corrosion in this valuable pipeline and
GKA Annual Surveillance Report Meltwater Oil Pool 68
higher temperatures will reduce backpressure at the drillsite thereby minimizing production impacts.
During 2013, a pressure transient analysis was planned and will be executed in 2014.
3.A new Meltwater reservoir management plan was put in place. This reservoir strategy included imposing
a well head injection pressure limit on Meltwater injectors. The sand face injection pressure limit of
3400 psi imposed on Meltwater injectors is predicated upon FIT/LOT (Formation Integrity Test / Leak‐off
Test) data obtained from Meltwater wells wherein production casing was set at the top of the Bermuda
interval. Upon implementing the reservoir management strategy changes, production and reservoir data
continued to be collected and shared with AOGCC.
Seven of the ten wells with historically high OA pressures were bled during the CPF2 shutdown in
June and July 2012. Of these ten wells, three were not bled. Wells 2P‐406 and 2P‐447 have cemented
outer annuli and well 2P‐434 was not bled as the OA pressure was not significant. The duration of
these bleeds were limited to four hours, or, if the pressure of the outer annulus dropped below 50
psi, the bleed was discontinued. The volumes of gas bled were less than 80 MSCF in a four hour
period and the recharge rates of the pressures in these outer annuli were slow.
Six of the seven wells bled showed a significant step change decrease in their outer annuli pressures.
The one anomaly, well 2P‐448A, initially indicated a step change decrease in its OA pressure; however,
the well was returned to service at the end of August, and a rise in OA pressure was noted that coincides
exactly with the timing of the well being returned to service.
The results of this bleed campaign are significant. Historically, bleeds performed on the outer annuli of
Meltwater wells were never able to initiate and maintain a step change decrease in the outer annulus
pressures. During 2013 four hour bleeds of all Meltwater outer annuli that had gas at surface were
performed semi‐annually as a method to monitor the change in recharge rate over time. General trends
of decreasing outer annulus pressures and recharge rates have been identified.
Another indicator that the changes in reservoir management strategy are having a positive effect is the
change in composition of the outer annulus gas. Currently, OA gas is now less similar to MI and more
similar to native gas from shallow intervals. Native gas is primarily characterized by methane as well
as a small presence of C2’s and C3’s. MI on the other hand has measurable amounts of C4’s through
C7’s that are not typical of native gas. During 2013 outer annulus gas samples from all Meltwater
outer annuli that had gas at surface were collected semi‐annually as a method to monitor the change in
composition over time. A general trend of decreasing similarity to MI has been identified.
4.CPAI has initiated studies to better describe the geologic components of the overburden.
Reservoir Management Summary
Meltwater came on‐line in November of 2001 and has cumulatively produced 17.8 MMBO, 3.5 MMBW, and
46.0 BCF of gas by year‐end 2013. Miscible gas injection began in 2002 with water injection beginning in
2003 (MWAG cycles). Cumulative injection through year‐end 2013 at Meltwater has been 25.1 MMBW and
60.6 BCF of gas (54.4 BCF of MI gas and 6.2 BCF of lean gas). Water injection ceased on October 15, 2009
when the water injection line had to be taken out of service due to operational constraints caused by areas
of excessive under‐deposit corrosion pitting.
When phase II injection wells were drilled in 2004, cumulative injection/withdrawal (I/W) for the field was
approximately 0.75. I/W rates for subsequent years were approximately 1.5 to restore adequate voidage
replacement. In late 2004, cumulative I/W reached 1.0 and climbed to a peak of 1.3 by 2009.
Despite three injectors being taken off‐line in 2008, instantaneous I/W remained above 2.0 for much of
2008. A minimum amount of both gas and water had to be transported to Meltwater to maintain line
velocities in order to minimize corrosion in the water line and freezing in the gas line.
Despite these efforts, the water injection line to Meltwater had to be taken out of service on October 15,
2009 based on results obtained from a “smart pig” run and additional follow‐up surveys completed during
2009. Currently, the plan is to remain on MI injection and reduce the reservoir pressure to near original
pressure. The cumulative year‐end 2013 I/W ratio is 1.15 from year‐end 2012 of 1.19 due to
implementation of a lower wellheader injection pressure (WHIP) limit since July 2012.
GKA Annual Surveillance Report Meltwater Oil Pool 69
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Attachment 2
Meltwater Oil Pool
2013 Annual Reservoir Surveillance Report
Produced Fluid Volumes
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2012 17,075,411 42,970,419 3,236,061
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR STB MSCF STB STB MSCF STB
1 2013 63,896 371,580 26,928 17,139,307 43,341,999 3,262,989
2 2013 74,550 340,539 25,296 17,213,857 43,682,538 3,288,285
3 2013 74,681 409,391 36,474 17,288,538 44,091,929 3,324,759
4 2013 56,633 213,128 29,780 17,345,171 44,305,057 3,354,539
5 2013 79,565 288,802 31,134 17,424,736 44,593,859 3,385,673
6 2013 66,408 258,064 14,524 17,491,144 44,851,923 3,400,197
7 2013 56,485 211,463 5,713 17,547,629 45,063,386 3,405,910
8 2013 50,864 212,469 1,454 17,598,493 45,275,855 3,407,364
9 2013 47,720 167,705 3,137 17,646,213 45,443,560 3,410,501
10 2013 46,758 147,947 3,105 17,692,971 45,591,507 3,413,606
11 2013 41,369 163,187 6,474 17,734,340 45,754,694 3,420,080
12 2013 60,417 233,166 30,325 17,794,757 45,987,860 3,450,405
2013 TOTAL 719,346 3,017,441 214,344
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2012 22,795,672 35,954,222 3,281,366
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR RVB RVB RVB RVB RVB RVB
1 2013 85,365 273,644 27,305 22,881,037 36,227,866 3,308,671
2 2013 99,599 242,641 25,650 22,980,636 36,470,507 3,334,321
3 2013 99,774 299,308 36,985 23,080,410 36,769,815 3,371,306
4 2013 75,662 146,778 30,197 23,156,071 36,916,593 3,401,503
5 2013 106,299 197,456 31,570 23,262,370 37,114,049 3,433,073
6 2013 88,721 178,828 14,727 23,351,091 37,292,877 3,447,800
7 2013 75,464 145,482 5,793 23,426,555 37,438,358 3,453,593
8 2013 67,954 149,173 1,474 23,494,510 37,587,531 3,455,067
9 2013 63,754 113,888 3,181 23,558,263 37,701,420 3,458,248
10 2013 62,469 98,098 3,148 23,620,732 37,799,517 3,461,397
11 2013 55,269 113,400 6,565 23,676,001 37,912,917 3,467,961
12 2013 80,717 161,363 30,750 23,756,718 38,074,279 3,498,711
2013 TOTAL 961,046 2,120,057 217,345
GKA Annual Surveillance Report Meltwater Oil Pool 71
Attachment 3
Meltwater Oil Pool
2013 Annual Reservoir Surveillance Report
Injected Fluid Volumes
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 25,136,450 6,000,745 52,370,692
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR STB MSCF MSCF STB MSCF MSCF
1 2013 0 19,803 255,173 25,136,450 6,020,548 52,625,865
2 2013 0 104,411 158,596 25,136,450 6,124,959 52,784,461
3 2013 0 141,423 63,659 25,136,450 6,266,382 52,848,120
4 2013 0 0 173,797 25,136,450 6,266,382 53,021,917
5 2013 0 0 158,700 25,136,450 6,266,382 53,180,617
6 2013 0 0 132,123 25,136,450 6,266,382 53,312,740
7 2013 0 0 92,362 25,136,450 6,266,382 53,405,102
8 2013 0 0 27,410 25,136,450 6,266,382 53,432,512
9 2013 0 0 95,532 25,136,450 6,266,382 53,528,044
10 2013 0 0 222,490 25,136,450 6,266,382 53,750,534
11 2013 0 0 281,914 25,136,450 6,266,382 54,032,448
12 2013 0 0 253,886 25,136,450 6,266,382 54,286,334
2013 TOTAL 0 265,637 1,915,642
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 25,488,360 5,107,090 39,644,615
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR RVB RVB RVB RVB RVB RVB
1 2013 0 22,833 210,263 25,488,360 5,129,923 39,854,878
2 2013 0 120,386 130,683 25,488,360 5,250,309 39,985,561
3 2013 0 163,061 52,455 25,488,360 5,413,369 40,038,016
4 2013 0 0 143,209 25,488,360 5,413,369 40,181,224
5 2013 0 0 130,769 25,488,360 5,413,369 40,311,993
6 2013 0 0 108,869 25,488,360 5,413,369 40,420,863
7 2013 0 0 76,106 25,488,360 5,413,369 40,496,969
8 2013 0 0 22,586 25,488,360 5,413,369 40,519,555
9 2013 0 0 78,718 25,488,360 5,413,369 40,598,273
10 2013 0 0 183,332 25,488,360 5,413,369 40,781,605
11 2013 0 0 232,297 25,488,360 5,413,369 41,013,902
12 2013 0 0 209,202 25,488,360 5,413,369 41,223,104
2013 TOTAL 0 306,279 1,578,489
GKA Annual Surveillance Report Meltwater Oil Pool 72
ATTACHMENT 4
Meltwater Oil Pool
2013 Annual Reservoir Surveillance Report
Reservoir Pressure Surveys
GKA Annual Surveillance Report Meltwater Oil Pool 73
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ATTACHMENT 5
Meltwater Oil Pool
2013 Annual Reservoir Surveillance Report
Production Logs and Special Surveys
No production logs or special surveys were completed in 2013. However, in 2013 planning for Spectra‐Flow
logging on Meltwater injectors was completed and is planned to be executed during the first half of 2014.
GKA Annual Surveillance Report Meltwater Oil Pool 79
ATTACHMENT 6
Meltwater Oil Pool
2013 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. A minimum of two well tests
per month were taken on production wells. 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 is used for injection and gas lift at drillsite 2P. For the wells that were on MI lift during a well test,
the metered liquid rates were adjusted for NGLs associated with MI lift. Production volumes were tracked
through an automated production monitoring SCADA system (Setcim). The 2013 Meltwater allocation factors
by month are listed below.
Month Oil Gas Water
Jan‐2013 0.9182 0.8920 1.0020
Feb‐2013 0.9631 0.9955 1.0276
Mar‐2013 0.9422 0.9809 1.0466
Apr‐2013 0.9443 0.9714 1.0604
May‐2013 0.9381 0.9960 1.0554
Jun‐2013 0.9226 1.0103 1.0765
Jul‐2013 0.9482 0.9944 1.0657
Aug‐2013 0.9377 0.9891 1.0518
Sep‐2013 0.9605 0.8763 1.0832
Oct‐2013 0.9506 0.8634 1.0878
Nov‐2013 0.9494 0.9346 1.0870
Dec‐2013 0.9542 0.9326 1.0684
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 historically
experienced at some point in time during their well lives elevated outer annulus (OA) pressures that may rebuild
pressure after bleeding. The surface pressures are monitored continuously via Setcim (wells have pressure
transducers that transmit real‐time OA pressures) and fluid levels are surveyed approximately semi‐annually via
echometer measurements. Upon implementation of the reservoir management strategy to reduce the reservoir
pressure as well as the sand face injection pressure, a significant decrease in the average outer annulus pressures
of the wells with historically high outer annulus pressures has been realized.
GKA Annual Surveillance Report Meltwater Oil Pool 80
ATTACHMENT 7
Meltwater Oil Pool
2013 Annual Reservoir Surveillance Report
Meltwater Development Plan and Operational Review
Following are summaries of key activities that are planned for 2014 and subsequent years.
Development Drilling
No future development drilling or well conversions are planned at this time. 2P‐432 injector flowback continues
seasonally to maintain sufficient flow through the pipeline. Development opportunities are being analyzed taking
into account seismic and surveillance findings.
Pipeline Operations
Due to low flow rates through the water injection line, there was awareness of the increased risk for
microbial‐induced under‐deposit corrosion and increased diagnostic work was being conducted. Frequent
pigging of the production and water injection lines was conducted to minimize effects of under‐deposit
corrosion. Despite these efforts, the water injection line had to be taken out of service on October 15, 2009, due
to operational constraints caused by areas of excessive under‐deposit corrosion pitting. A proactive maintenance
pigging and inspection operation continues on the produced oil pipeline from the Meltwater drillsite.
Exploration/Delineation
No further exploration work is currently planned for the Bermuda interval.
GKA Annual Surveillance Report Meltwater Oil Pool 81
ATTACHMENT 8
Meltwater Oil Pool
2013 Annual Surveillance Report
Map showing Development as of December 31, 2013
GKA Annual Surveillance Report Meltwater Oil Pool 82
TABASCO
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ATTACHMENT 1
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report
Summary of the Enhanced Recovery Project
Tabasco produced 624 MBO of crude, 117 MMSCF of gas, and 6,197 MBW during 2013. Water injection was
6,072 MBW over the same period. Cumulative oil, gas, water production, and water injection through year‐end
2013 were 17.97 MMBO, 2.98 BCF, 80.32 MMBW, and 91.51 MMBWI, respectively. The cumulative year‐end
2013 I/W ratio, based on current formation volume factors, is estimated at 0.92 for Tabasco.
Year‐end 2013 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was:
Producers: 9 completed 5 on‐line
Injectors: 3 completed 2 on‐line
The pool average water oil ratio (WOR) was 11.10 at the end of 2013 compared to 8.36 at the end of 2012.
Water breakthrough has occurred at all producers. 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.
GKA Annual Surveillance Report Tabasco Oil Pool 87
Attachment 2
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report
Produced Fluid Volumes
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31,2012 17,345,178 2,866,842 74,120,689
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR STB MSCF STB STB MSCF STB
1 2013 61,698 9,286 467,833 17,406,876 2,876,128 74,588,522
2 2013 56,224 9,235 440,344 17,463,100 2,885,363 75,028,866
3 2013 58,284 9,554 475,583 17,521,384 2,894,917 75,504,449
4 2013 64,642 11,397 599,615 17,586,026 2,906,314 76,104,064
5 2013 49,291 11,334 652,325 17,635,317 2,917,648 76,756,389
6 2013 43,557 10,109 573,642 17,678,874 2,927,757 77,330,031
7 2013 46,269 10,119 496,483 17,725,143 2,937,876 77,826,514
8 2013 48,516 10,419 491,582 17,773,659 2,948,295 78,318,096
9 2013 53,303 9,057 485,697 17,826,962 2,957,352 78,803,793
10 2013 48,826 8,446 515,563 17,875,788 2,965,798 79,319,356
11 2013 47,666 9,007 486,285 17,923,454 2,974,805 79,805,641
12 2013 46,141 8,994 511,919 17,969,595 2,983,799 80,317,560
2013 TOTAL 624,417 116,957 6,196,871
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31,2012 18,359,583 78,741 74,120,689
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR RVB RVB RVB RVB RVB RVB
1 2013 65,832 4 467,833 18,425,415 78,745 74,588,522
2 2013 59,991 109 440,344 18,485,406 78,854 75,028,866
3 2013 62,189 110 475,583 18,547,595 78,965 75,504,449
4 2013 68,973 231 599,615 18,616,568 79,196 76,104,064
5 2013 52,593 536 652,325 18,669,161 79,732 76,756,389
6 2013 46,475 486 573,642 18,715,637 80,218 77,330,031
7 2013 49,369 432 496,483 18,765,006 80,650 77,826,514
8 2013 51,767 427 491,582 18,816,772 81,078 78,318,096
9 2013 56,874 144 485,697 18,873,647 81,222 78,803,793
10 2013 52,097 153 515,563 18,925,744 81,375 79,319,356
11 2013 50,860 253 486,285 18,976,603 81,627 79,805,641
12 2013 49,232 282 511,919 19,025,836 81,909 80,317,560
2013 TOTAL 666,253 3,168 6,196,871
GKA Annual Surveillance Report Tabasco Oil Pool 88
Attachment 3
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report
Injected Fluid Volumes
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31,2012 85,435,182 0 0
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR STB MSCF MSCF STB MSCF MSCF
1 2013 454,408 0 0 85,889,590 0 0
2 2013 452,043 0 0 86,341,633 0 0
3 2013 451,320 0 0 86,792,953 0 0
4 2013 553,531 0 0 87,346,484 0 0
5 2013 597,593 0 0 87,944,077 0 0
6 2013 602,749 0 0 88,546,826 0 0
7 2013 569,809 0 0 89,116,635 0 0
8 2013 565,515 0 0 89,682,150 0 0
9 2013 379,041 0 0 90,061,191 0 0
10 2013 497,575 0 0 90,558,766 0 0
11 2013 387,981 0 0 90,946,747 0 0
12 2013 560,592 0 0 91,507,339 0 0
2013 TOTAL 6,072,157 0 0
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31,2012 85,435,189 0 0
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR RVB RVB RVB RVB RVB RVB
1 2013 454,408 0 0 85,889,597 0 0
2 2013 452,043 0 0 86,341,640 0 0
3 2013 451,320 0 0 86,792,960 0 0
4 2013 553,531 0 0 87,346,491 0 0
5 2013 597,593 0 0 87,944,084 0 0
6 2013 602,749 0 0 88,546,833 0 0
7 2013 569,809 0 0 89,116,642 0 0
8 2013 565,515 0 0 89,682,157 0 0
9 2013 379,041 0 0 90,061,198 0 0
10 2013 497,575 0 0 90,558,773 0 0
11 2013 387,981 0 0 90,946,754 0 0
12 2013 560,592 0 0 91,507,346 0 0
2013 TOTAL 6,072,157 0 0
GKA Annual Surveillance Report Tabasco Oil Pool 89
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ATTACHMENT 4
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report Reservoir
Pressure Surveys
GKA Annual Surveillance Report Tabasco Oil Pool 91
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ATTACHMENT 5
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report
Production Logs and Special Surveys
In November of 2013, while drilling the 2T‐41 Kuparuk grass roots producer, the Tabasco interval was logged with
sonic, gamma ray, and resistivity. The information gathered from this initiative is planned to be used to evaluate
potential development opportunities at Tabasco.
In 2012 it was determined that well 2T‐209 was not an economically viable producer to keep in active service due
to a high water cut. However, a second barrier to the formation needed to be installed as part of an initiative by
ConocoPhillips Alaska to add a second barrier to all single casing wells in the Greater Kuparuk Area. During the
2T‐209 rig workover, a new ESP completion was not installed and instead a packer with plug was put in place to
allow for future surveillance opportunities as well as future sidetrack development opportunities. In 2013 plans
were completed to perform temperature surveys under various field production scenarios in an attempt to
identify potential high perm streaks and/or water slumping effects. These temperature surveys are planned to be
completed in 2014.
GKA Annual Surveillance Report Tabasco Oil Pool 97
ATTACHMENT 6
Tabasco Oil Pool
2013 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 the Setcim production monitoring SCADA system. In 2002, Tabasco
switched from an allocation factor of 1.0 to floating production allocation factors. Tabasco 2013 production
allocation factors were as follows:
Month Oil Gas Water
Jan‐13 0.9510 0.9216 1.0324
Feb‐13 0.9631 0.9956 1.0276
Mar‐13 0.8811 0.9161 0.9792
Apr‐13 0.9443 0.9713 1.0604
May‐13 0.9381 0.9960 1.0554
Jun‐13 0.9226 1.0102 1.0768
Jul‐13 0.9481 0.9948 1.0661
Aug‐13 0.9377 0.9892 1.0530
Sep‐13 0.9605 0.8763 1.0755
Oct‐13 0.9505 0.8632 1.0876
Nov‐13 0.9493 0.9344 1.0871
Dec‐13 0.9542 0.9326 1.0685
GKA Annual Surveillance Report Tabasco Oil Pool 98
ATTACHMENT 7
Tabasco Oil Pool
2013 Annual Reservoir Surveillance Report
Development Plans and Operational Review
Tabasco Injection/Withdrawal Ratios (I/W Ratio) are monitored to maintain an instantaneous value of
approximately 1.0. Adjustments to injection and/or production rates are made to achieve this in order to maintain
pressure support for the Tabasco Reservoir and keep gas in solution. The 2014 injection strategy is to continue to
replace voidage by splitting water injection between 2T‐201 and 2T‐217A.
In 2012, a rig workover (RWO) was completed on well 2T‐202 to install a production packer as a second barrier in
the well. The packer that was installed on well 2T‐202 was identified as having a two‐way leak. The well remained
shut‐in for the duration of 2013. In 2013, planning was finalized and procedures completed to repair the packer
leak on producer 2T‐202. This work included placing a polymer agent in the inner annulus on top of the packer to
seal the slow leak that has been identified and thus allow for this well to be returned to production. Well 2T‐202 is
planned to be returned to production service in 2014.
In 2012 the decision was made to plug and abandon well 2T‐204 as it had no future utility. Development planning
is currently underway. In January of 2013 a team was assembled to evaluate the Tabasco formation for future
development opportunities. The goals of this group were to:
Redevelop the Tabasco Full Field reservoir model
Complete water conformance modeling and an investigation into polymer flooding options
Evaluate rotary sidetrack options to develop the top of the Tabasco formation and areas that
may be isolated from efficient injection support.
Significant progress was made on each of these initiatives and future development opportunities are planned to
be analyzed in further detail in 2014.
GKA Annual Surveillance Report Tabasco Oil Pool 99
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TARN
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ATTACHMENT 1
Tarn Oil Pool
2013 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 21st and July 20th, 1998 respectively. The
Unit Expansion and Participating area were approved effective July 1, 1998.
Construction of the Tarn road, pads, powerlines, and pipelines took place in the 1998/1999 winter construction
season. Tarn development drilling commenced in April of 1998. Tarn production began on July 8, 1998. 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 strictly an MI flood to an 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.
The Tarn MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. For
compositional analysis of the Kuparuk spec MI, refer to the Kuparuk section of the annual surveillance report.
Reservoir Management Summary
In 2013, Tarn produced 2.06 MMBO, 6.78 MMBW, and 4.59 BSCF gas. The injection totals for 2012 were 1.59
BSCF Lean Gas, 5.23 BSCF of MI and 10.34 MMBW. At the end of 2013, the cumulative I/W ratio was 1.07 for Drill
Site 2N, and 1.27 for Drill Site 2L. Plans are to continue maintaining reservoir pressure by balancing monthly
injection and production rates.
GKA Annual Surveillance Report Tarn Oil Pool 105
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2012 107,413,756 168,627,270 62,680,154
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR STB MSCF STB STB MSCF STB
1 2013 177,117 264,035 555,652 107,590,873 168,891,305 63,235,806
2 2013 152,494 311,266 526,648 107,743,367 169,202,571 63,762,454
3 2013 171,962 410,135 641,378 107,915,329 169,612,706 64,403,832
4 2013 148,867 349,649 646,231 108,064,196 169,962,355 65,050,063
5 2013 157,195 352,789 672,192 108,221,391 170,315,144 65,722,255
6 2013 158,481 391,618 624,922 108,379,872 170,706,762 66,347,177
7 2013 174,464 392,276 549,450 108,554,336 171,099,038 66,896,627
8 2013 194,059 438,485 689,936 108,748,395 171,537,523 67,586,563
9 2013 183,234 403,677 497,978 108,931,629 171,941,200 68,084,541
10 2013 183,770 451,693 468,087 109,115,399 172,392,893 68,552,628
11 2013 179,463 439,757 455,094 109,294,862 172,832,650 69,007,722
12 2013 176,706 381,041 452,110 109,471,568 173,213,691 69,459,832
2013 TOTAL 2,057,812 4,586,421 6,779,678
Produced Fluid Volumes (Reservoir Units)
CUM OIL CUM GAS CUM WATER
Cumulatives at Dec 31, 2012 144,038,793 116,262,242 63,557,676
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR RVB RVB RVB RVB RVB RVB
1 2013 239,186 167,966 563,431 144,277,979 116,430,208 64,121,107
2 2013 205,803 237,505 534,021 144,483,781 116,667,713 64,655,128
3 2013 232,271 333,869 650,357 144,716,052 117,001,582 65,305,485
4 2013 200,493 287,503 655,278 144,916,545 117,289,085 65,960,764
5 2013 211,881 285,861 681,603 145,128,427 117,574,947 66,642,366
6 2013 213,429 329,256 633,671 145,341,856 117,904,202 67,276,037
7 2013 235,357 315,085 557,142 145,577,213 118,219,288 67,833,180
8 2013 262,238 349,238 699,595 145,839,450 118,568,526 68,532,775
9 2013 247,048 323,946 504,950 146,086,498 118,892,472 69,037,724
10 2013 247,566 378,925 474,640 146,334,064 119,271,397 69,512,365
11 2013 241,731 368,478 461,465 146,575,795 119,639,876 69,973,830
12 2013 237,946 305,749 458,440 146,813,741 119,945,624 70,432,269
2013 TOTAL 2,774,948 3,683,382 6,874,593
ATTACHMENT 2
Tarn River Oil Pool
2013 Annual Reservoir Surveillance Report
Produced Fluid Volumes
GKA Annual Surveillance Report Tarn Oil Pool 106
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 174,815,963 16,149,606 181,202,691
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR STB MSCF MSCF STB MSCF MSCF
1 2013 902,267 45,587 578,825 175,718,230 16,195,193 181,781,516
2 2013 857,974 382,244 374,779 176,576,204 16,577,437 182,156,295
3 2013 646,923 526,123 150,158 177,223,127 17,103,560 182,306,453
4 2013 662,997 0 494,666 177,886,124 17,103,560 182,801,119
5 2013 620,208 0 554,438 178,506,332 17,103,560 183,355,557
6 2013 796,548 0 684,962 179,302,880 17,103,560 184,040,519
7 2013 1,042,215 140,200 346,244 180,345,095 17,243,760 184,386,763
8 2013 996,399 394,171 180,075 181,341,494 17,637,931 184,566,838
9 2013 872,202 99,807 639,494 182,213,696 17,737,738 185,206,332
10 2013 1,010,303 0 489,298 183,223,999 17,737,738 185,695,630
11 2013 1,018,397 0 319,265 184,242,396 17,737,738 186,014,895
12 2013 916,905 0 426,505 185,159,301 17,737,738 186,441,400
2013 TOTAL 10,343,338 1,588,132 5,238,709
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 177,263,386 18,327,125 148,088,924
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR RVB RVB RVB RVB RVB RVB
1 2013 914,899 51,592 466,882 178,178,285 18,378,717 148,555,806
2 2013 869,986 427,333 300,245 179,048,270 18,806,051 148,856,050
3 2013 655,980 586,312 120,455 179,704,250 19,392,363 148,976,506
4 2013 672,279 0 401,534 180,376,529 19,392,363 149,378,039
5 2013 628,891 0 448,767 181,005,420 19,392,363 149,826,807
6 2013 807,700 0 544,616 181,813,120 19,392,363 150,371,423
7 2013 1,056,806 150,570 271,696 182,869,926 19,542,933 150,643,119
8 2013 1,010,349 429,069 141,995 183,880,274 19,972,002 150,785,114
9 2013 884,413 109,255 506,240 184,764,687 20,081,257 151,291,354
10 2013 1,024,447 0 383,787 185,789,135 20,081,257 151,675,141
11 2013 1,032,655 0 246,231 186,821,789 20,081,257 151,921,371
12 2013 929,742 0 326,151 187,751,531 20,081,257 152,247,522
2013 TOTAL 10,488,145 1,754,132 4,158,598
ATTACHMENT 3
Tarn River Oil Pool
2013 Annual Reservoir Surveillance Report
Injected Fluid Volumes
GKA Annual Surveillance Report Tarn Oil Pool 107
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ATTACHMENT 4
Tarn Oil Pool
2013 Annual Reservoir Surveillance Report Reservoir
Pressure Surveys
GKA Annual Surveillance Report Tarn Oil Pool 109
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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1.Operator:ConocoPhillips Alaska Inc. 2. Address:P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name:Kuparuk River Unit 4. Field and Pool:Tarn Oil Pool 5. Datum Reference:-5200' SS 6. Oil Gravity:0.83 (water = 1.0)7. Gas Gravity:0.74 8. Well Name andNumber: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final TestDate15. Shut-In Time, Hours 16. Press.Surv. Type (see instructions for codes) 17. B.H.Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure atDatum (cal) 2L-30450103206130000O490165 A 5341 - 5352 06/20/13 122 SBHP 139 5313 118552000.30011512L-30550103202790000 WAG 490165 A 5275 - 5280, 5264 - 5269, 5243 - 5263, 5211 - 5220, 5192 - 5196, 5180 - 5184 11/04/13 144 SBHP 137 5187 384652000.39038512L-31050103206160000 WAG 490166 A 5292 - 5302 01/29/13 407 PBU134 5134 1534 52010.320 1555 2L-31150103204690000O490165 A 5343 - 5349, 5302 - 5314 06/19/13 108 SBHP 139 5305 174552000.32017122L-31250103206260000O490165 A 5271 - 5284 06/27/13 126 SBHP 138 5175 92952000.2909362L-317A 50103203360100 WAG 490165 A 5386 - 5398, 5374 - 5386, 5363 - 5374, 5351 - 5363, 5348 - 5351 01/17/13 604 PFO 123 5192 430252000.32043052L-31950103205520000 WAG 490165 A 5328 - 5343 05/20/13 3900 SBHP 131 5336 3187 52000.32031442L-32050103206270000O490165 A 5378 - 5384, 5389 - 5394 06/27/13 112 SBHP 141 5322 109752000.02010952L-32150103202860000O490165 A 5343 - 5365 02/12/13 240 SBHP 135 5135 213652000.31421562L-329A 50103202720100 WAG 490166 A 5041 - 5065 07/11/13 18970 SBHP 129 5048 3232 52000.29032762N-302 50103203800000 WAG 490165 A 5259 - 5273, 5249 - 5259 02/02/13 312 SBHP 125 5234 390552000.32038942N-302 50103203800000 WAG 490165 A 5259 - 5273, 5249 - 5259 12/31/13 341 PFO 135 5026 379052000.44038672N-303 50103203520000O490165 A 5210 - 5221 09/11/13 29000 SBHP 133 4971 1829 52000.35019092N-304 50103203820000O490165 A 5353 - 5360 09/18/13 18600 SBHP 142 5357 2203 52000.45021322N-305A 50103203490100 O 490165 A 5176 - 5183 06/22/13 180 SBHP 138 5137 198852000.43020152N-308 50103202880000O490165 A 5082 - 5096, 5073 - 5082 12/19/13 4008 SBHP 137 5075 3300 52000.45033562N-309 50103202930000 WAG 490166 A 5148 - 5172, 5121 - 5145 05/29/13 692 SBHP 45 5145 330352000.51033312N-323 50103202580000O490165 A 4980 - 5008, 4933 - 4946 10/12/13 850 SBHP 135 5002 272752000.50028262N-325 50103202690000 WAG 490165 A 5112 - 5121, 5097 - 5102, 5088 - 5092, 5063 - 5084, 5052 - 5060, 5038 - 5048, 5013 - 5019, 4987 - 4993 05/29/13 64 SBHP 119 5080 3394 52000.445 3448 2N-332 50103203400000O490165 A 4855 - 4871 05/21/13 62000 SBHP 128 4864 3152 52000.3203260Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
ATTACHMENT 5
Tarn Oil Pool
2013 Annual Reservoir Surveillance Report Production
Logs and Special Surveys
Well Date Comment
2L‐319 9/2/2013 Temperature log
2N‐308 7/31/2013 Leak detection (acoustic) log
2N‐325 6/26/2013 Add perforation from 7,603’to 7,613’
2L‐304 5/20/2013 Leak detection (acoustic) log
GKA Annual Surveillance Report Tarn Oil Pool 115
ATTACHMENT 6
Tarn Oil Pool
2013 Annual Reservoir Surveillance Report
Allocation Factors
Month
01/31/13
Oil
0.9508
Gas
0.9217
Water
1.0324
02/28/13 0.9630 0.9955 1.0276
03/31/13 0.9422 0.9808 1.0465
04/30/13 0.9442 0.9713 1.0604
05/31/13 0.9381 0.9960 1.0554
06/30/13 0.9227 1.0102 1.0768
07/31/13 0.9483 0.9944 1.0661
08/31/13 0.9377 0.9891 1.0530
09/30/13 0.9605 0.8763 1.0755
10/31/13 0.9505 0.8634 1.0875
11/30/13 0.9494 0.9346 1.0872
12/31/13 0.9542 0.9326 1.0685
GKA Annual Surveillance Report Tarn Oil Pool 116
ATTACHMENT 7
Tarn Oil Pool
2013 Annual Reservoir Surveillance Report Tarn
Development Plan and Operational Review
Development Drilling
No Tarn development drilling occurred in 2013; however, development well opportunities are scheduled to be
drilled in 2014/2015. Nabors 9ES rig mobilized to Tarn during January 2014 to drill development wells for infill
and periphery pattern realignment purposes.
Producer to Injector Conversions
Well 2L‐310 was converted into a MWAG injector in June 2013. The full impact of converting this well remains
to be seen although some limited benefit has been shown by offset wells. Well 2N‐308 was converted to a
MWAG injector at the beginning of 2014 due to high water production and will be placed on injection as soon
as possible.
Artificial Lift
Tarn was originally designed to use miscible gas injection (MI) as a means of gas lifting the production wells.
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 have been 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. Each of these wells was in jet pump service when the failure occurred. These wells will likely remain
secured and shut in until a rotary sidetrack targeting a more prolific reservoir is executed.
In 2011, well 2N‐304 failed a mechanical integrity test and was secured until workover was done in December
2013. 2N‐304 has to be artificially lifted with jet pump again after the workover due to small tubing size. It will
be placed on production as soon as possible. As of the end of 2013, there are only three remaining wells at Tarn
on jet pump: 2L‐311, 2N‐342, and 2N‐304.
After water breakthrough occurs in producing wells, paraffin deposition is less likely due to increased well
flowing temperatures (the heat capacity of water is greater than that of oil). Consequently, completion designs
and alternatives to jet pumps are being considered for new and existing wells.
GKA Annual Surveillance Report Tarn Oil Pool 117
ATTACHMENT 8
Tarn Oil Pool
2013 Annual Surveillance Report
Map showing Development as of December 31, 2013
GKA Annual Surveillance Report Tarn Oil Pool 118
WEST SAK
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ATTACHMENT 1
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report Summary
of the Enhanced Oil Recovery Project
A dual‐lateral producer, well 3K‐105 was placed in service in the West Sak Oil Pool in 2013.
At the end of 2013 there were 54 active water injectors and 53 active producers in the West Sak Oil Pool. This
represents an increase of five active producers and an increase of two active injectors in West Sak from January
2013 to December 2013.
Waterflooding the reservoir for pressure maintenance and improved sweep continues to be the main enhanced
oil recovery (EOR) mechanism in the West Sak oil pool. Drill Sites 1B, 1C, 1D and 1J inject CPF‐1 produced water
while Drill Site 3K injects seawater. The injectors on Drill Site 1E were on seawater service for ~78% of 2013 with
the remaining time on produced water injection. Waterflood performance was good in the majority of the West
Sak patterns. During 2013 the West Sak oil pool experienced no new confirmed rapid water breakthrough
event, termed matrix bypass event (MBE), resulting in highly conductive pathways between an injector and a
producer.
Analysis and review of the matrix bypass events is an ongoing activity. Measures to mitigate future MBEs were
implemented in 2005 and 2007 resulting in reduced frequency of occurrence. In addition, remediation repairs
were implemented in 2009 and 2010 that successfully isolated four MBEs. A new technology to isolate MBEs has
been implemented in eight wells since 2011, with sustained success in six of these wells.
During 2003, ConocoPhillips Alaska, Inc. received approval to commence a West Sak Small Scale EOR (SSEOR)
Pilot Project using Kuparuk MI in a water‐alternating gas (WAG) pilot. In 2009, a West Sak Viscosity Reducing
Water Alternating Gas (VRWAG) pilot project was approved for four West Sak injectors at drill sites 1E
and 1J. Initial VRWAG gas injection began in November 2009 in two injectors, 1E‐102 and 1E‐117. Two additional
injectors, 1J‐170 and 1J‐122, began gas injection in April 2010. Well 1E‐102 was shut‐in following a MBE with
1E‐121. Well 1E‐102 has been removed from the VRWAG pilot project. No breakthroughs have been detected in
the three (3) remaining patterns.
The final report for the 3‐year VRWAG pilot project, including surveillance data, was submitted in 2013.
Additionally, permission was granted to continue VRWAG injection to the end of 2013. The gas injection volumes
in 2013 were ~ 730 mmscf for well 1E‐117, ~ 232 mmscf for well 1J‐122, and ~ 345 mmscf for well 1J‐170. The
VRWAG cycles and data analysis for these three patterns are ongoing and surveillance efforts will continue to
evaluate the impact of the viscosity reducing gas injection. An amendment to the area injection order
allowing for long‐term VRWAG injection will be pursued in 2014.
GKA Annual Surveillance Report West Sak Oil Pool 123
ATTACHMENT 2
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Produced Fluid Volumes
CUM OIL* CUM GAS* CUM WATER*
Cumulatives at Dec 31, 2012 61,823,451 31,155,073 17,382,074
MO YR
OIL
STB
GAS
MSCF
WATER
STB
CUM OIL
STB
CUM GAS
MSCF
CUM WATER
STB
1 2013 479,794 257,718 197,786 62,303,245 31,412,791 17,579,860
2 2013 436,676 243,046 167,191 62,739,921 31,655,837 17,747,051
3 2013 482,974 255,976 197,032 63,222,895 31,911,813 17,944,083
4 2013 528,016 265,340 224,035 63,750,911 32,177,153 18,168,118
5 2013 505,461 279,051 211,033 64,256,372 32,456,204 18,379,151
6 2013 483,893 279,404 208,796 64,740,265 32,735,608 18,587,947
7 2013 544,344 308,380 237,541 65,284,609 33,043,988 18,825,488
8 2013 307,672 152,872 126,141 65,592,281 33,196,860 18,951,629
9 2013 453,310 220,697 194,396 66,045,591 33,417,557 19,146,025
10 2013 512,913 254,685 246,158 66,558,504 33,672,242 19,392,183
11 2013 509,899 297,985 223,021 67,068,403 33,970,227 19,615,204
12 2013 509,662 289,921 219,983 67,578,065 34,260,148 19,835,187
2013 TOTAL 5,754,614 3,105,075 2,453,113
Produced Fluid Volumes (Reservoir Units)
CUM OIL* CUM GAS* CUM WATER*
Cumulatives at Dec 31, 2012 64,601,320 28,970,077 17,485,760
OIL GAS WATER CUM OIL CUM GAS CUM WATER
MO YR RVB RVB RVB RVB RVB RVB
1 2013 512,420 220,088 197,786 65,113,740 29,190,165 17,683,546
2 2013 466,370 211,059 167,191 65,580,110 29,401,224 17,850,737
3 2013 515,816 218,271 197,032 66,095,926 29,619,495 18,047,769
4 2013 563,921 222,459 224,035 66,659,847 29,841,954 18,271,804
5 2013 539,832 246,339 211,033 67,199,680 30,088,293 18,482,837
6 2013 516,798 252,912 208,796 67,716,477 30,341,205 18,691,633
7 2013 581,359 271,264 237,541 68,297,837 30,612,469 18,929,174
8 2013 328,594 125,574 126,141 68,626,430 30,738,043 19,055,315
9 2013 484,135 173,586 194,396 69,110,566 30,911,629 19,249,711
10 2013 547,791 201,515 246,158 69,658,357 31,113,144 19,495,869
11 2013 544,572 259,990 223,021 70,202,929 31,373,133 19,718,890
12 2013 544,319 251,154 219,983 70,747,248 31,624,287 19,938,873
2013 TOTAL 6,145,928 2,654,210 2,453,113
*2012 Cums include corrections made after 2012 Surveillance Report was issued.
GKA Annual Surveillance Report West Sak Oil Pool 124
ATTACHMENT 3
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Injected Fluid Volumes
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 84,429,002 21,732 3,632,082
MO YR
WATER
STB
GAS
MSCF
MI
MSCF
CUM WATER
STB
CUM GAS
MSCF
CUM MI
MSCF
1 2013 587,735 0 0 85,016,737 21,732 3,632,082
2 2013 533,972 0 0 85,550,709 21,732 3,632,082
3 2013 579,870 0 30,286 86,130,579 21,732 3,662,368
4 2013 585,789 0 157,558 86,716,368 21,732 3,819,926
5 2013 618,535 0 111,022 87,334,903 21,732 3,930,948
6 2013 626,458 0 0 87,961,361 21,732 3,930,948
7 2013 627,317 0 0 88,588,678 21,732 3,930,948
8 2013 321,583 0 0 88,910,261 21,732 3,930,948
9 2013 608,199 0 0 89,518,460 21,732 3,930,948
10 2013 665,437 0 203,932 90,183,897 21,732 4,134,880
11 2013 593,880 0 394,290 90,777,777 21,732 4,529,170
12 2013 650,638 0 410,098 91,428,415 21,732 4,939,268
2013 TOTAL 6,999,413 0 1,307,186
Injected Fluid Volumes (Reservoir Units)
CUM WATER CUM GAS CUM MI
Cumulatives at Dec 31, 2012 84,804,454 34,916 2,720,429
WATER GAS MI CUM WATER CUM GAS CUM MI
MO YR RVB RVB RVB RVB RVB RVB
1 2013 587,735 0 0 85,392,189 34,916 2,720,429
2 2013 533,972 0 0 85,926,161 34,916 2,720,429
3 2013 579,870 0 22,533 86,506,031 34,916 2,742,962
4 2013 585,789 0 117,223 87,091,820 34,916 2,860,185
5 2013 618,535 0 82,600 87,710,355 34,916 2,942,785
6 2013 626,458 0 0 88,336,813 34,916 2,942,785
7 2013 627,317 0 0 88,964,130 34,916 2,942,785
8 2013 321,583 0 0 89,285,713 34,916 2,942,785
9 2013 608,199 0 0 89,893,912 34,916 2,942,785
10 2013 665,437 0 151,725 90,559,349 34,916 3,094,511
11 2013 593,880 0 293,352 91,153,229 34,916 3,387,862
12 2013 650,638 0 305,113 91,803,867 34,916 3,692,975
2013 TOTAL 6,999,413 0 972,546
GKA Annual Surveillance Report West Sak Oil Pool 125
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ATTACHMENT 4
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report Reservoir
Pressure Surveys
GKA Annual Surveillance Report West Sak Oil Pool 127
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STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhillips Alaska Inc. 2. Address: P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: Kuparuk River Unit 4. Field and Pool: West Sak Oil Pool 5. Datum Reference: -3500' SS 6. Oil Gravity: 0.94 (water = 1.0)7. Gas Gravity: 0.57 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth ToolTVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1B-101 50029231730000 O 490150 D 3646 - 3625 10/04/13 1176 SBHP 73 3332 671 3500 0.380 735 1C-102 50029230370000 O 490150 BD 3699 - 3650 03/14/13 360 SBHP 84 3555 805 3500 0.400 783 1C-109 50029230470000 O 490150 BD 3706 - 3691 09/11/13 3912 SBHP 76 3597 1171 3500 0.380 1134 1C-127 50029230240000 WI 490150 A 3836 - 3858, 3774 - 3795, 3749 - 3764, 3663 - 3730, 3599 - 3636 03/01/13 9002 SBHP 75 3765 1646 3500 0.546 1501 1C-131 50029230410000 WI 490150 BD 3724 - 3759, 3662 - 3700 04/25/13 3797 SBHP 83 3655 1761 3500 0.457 1690 1C-135 50029230530000 O 490150 D 3674 - 3662 02/13/13 13247 SBHP 72 3656 1494 3500 0.342 1441 1D-102 50029229600000 O 490150 BD 3651 - 3619 10/27/13 4824 SBHP 67 3158 1610 3500 0.390 1743 1D-108 50029229210000 O 490150 ABD 3805 - 3837, 3751 - 3768, 3695 - 3723, 3633 - 3661, 3571 - 3599 03/06/13 240 SBHP 78 3428 1480 3500 0.374 1507 1D-112 50029229190000 O 490150 ABD 3750 - 3769, 3699 - 3713, 3634 - 3648, 3597 - 3611, 3536 - 3554 07/30/13 384 SBHP 77 3446 1535 3500 0.374 1555 1D-113 50029229170000 O 490150 ABD 3702 - 3717, 3640 - 3658, 3591 - 3609, 3543 - 3561, 3478 - 3505 05/07/13 936 SBHP 75 3358 1435 3500 0.374 1488 1D-115 50029228400000 O 490150 ABD 3740 - 3780, 3688 - 3718, 3590 - 3650, 3524 - 3554 03/19/13 288 SBHP 75 3337 1580 3500 0.374 1641 1D-121 50029228140000 O 490150 ABD 3771 - 3801, 3693 - 3723, 3601 - 3631, 3541 - 3571 12/10/13 408 SBHP 77 3416 1761 3500 0.374 1793 1D-123 50029229140000 O 490150 ABD 3629 - 3678, 3591 - 3610, 3563 - 3582, 3509 - 3539, 3476 - 3508, 3416 - 3446 09/02/13 192 SBHP 80 3261 1224 3500 0.374 1313 Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1.Operator:ConocoPhillips Alaska Inc. 2. Address:P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name:Kuparuk River Unit 4. Field and Pool:West Sak Oil Pool 5. Datum Reference:-3500' SS 6. Oil Gravity:0.94 (water = 1.0)7. Gas Gravity:0.57 8.Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top -Bottom TVDSS 14. Final TestDate15. Shut-In Time, Hours 16. Press.Surv. Type (see instructions for codes) 17. B.H.Temp. 18. Depth ToolTVDSS19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure atDatum (cal) 1D-129 50029228300000O490150 ABD 3712 - 3742, 3643 - 3653, 3616 - 3626, 3576 - 3593, 3530 - 3550, 3470 - 3498 12/29/13 10896 SBHP 73 3296 1633 35000.38017111D-131 50029228910000O490150 ABD 3603 - 3638, 3495 - 3533, 3452 - 3471, 3392 - 3419 03/13/13 3048 SBHP 76 3377 1484 35000.38015311D-134 50029228920000O490150 ABD 3703 - 3738, 3683 - 3686, 3664 - 3670, 3650 - 3656, 3631 - 3639, 3546 - 3561, 3475 - 3499 12/29/13 10752 SBHP 74 3408 1666 35000.38017011J-13550029233490000O490150 BD 3483 - 3462, 3462 - 3391 07/05/13 1000 SBHP 74 3382 1600 35000.37416443K-103 50029233920000 WI490150B 3569 - 3569, 3523 - 3523, 3515 - 3516, 3512 - 3512, 3510 - 3510, 3508 - 3509, 3505 - 3506, 3500 - 3501, 3493 - 3494, 3484 - 3484, 3482 - 3483 02/17/13 1518 SBHP 75 -75 1365 35000.35035613K-103 50029233920000 WI490150D 3569 - 3569, 3523 - 3523, 3515 - 3516, 3512 - 3512, 3510 - 3510, 3508 - 3509, 3505 - 3506, 3500 - 3501, 3493 - 3494, 3484 - 3484, 3482 - 3483 02/18/13 1518 SBHP 75 -75 1353 35000.3503549Form 10-412 Rev. 04/2009 INSTRUCTIONS ON REVERSE SIDE
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ATTACHMENT 5
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Injectivity Profiles
GKA Annual Surveillance Report West Sak Oil Pool 135
ATTACHMENT 5 KUPARUK RIVER UNIT WEST SAK OIL POOL CONSERVATION ORDER 406B 2013 ANNUAL SUBMITTAL WELL NUMBER APIDATE OFDATE OF DATA TYPE REASON FOR WELLZONESINJECTION NUMBER INITIALPROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD /50-INJECTION SURVEYSURVEYSURVEYINJECTIONMSCFD1C-121 1C-125 1C-127 0292301500 - 00 12/31/01 05/28/13 SPINNER A/C SPLITS Single ABD7100292304400 - 00 12/31/01 06/25/13 SPINNER A/C SPLITS Single ABD13570292302400 - 00 12/31/02 04/25/13 SPINNER A/C SPLITS Single ABD9383 >>Total IPROF Count for 2013 GKA Annual Surveillance ReportWest Sak Oil Pool136
ATTACHMENT 6
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Production Survey Data
During 2013, no production profile surveys were attempted for the West Sak Oil Pool.
GKA Annual Surveillance Report West Sak Oil Pool 137
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ATTACHMENT 7
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Special Survey Date
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1B‐101 03/24/13 0%62%39%
1B‐101 05/23/13 0%47%53%
1C‐102 01/07/13 0%34%66%
1C‐102 04/21/13 0%7%93%
1C‐109 01/07/13 0%40%61%
1C‐121 05/28/13 100%0%0%
1C‐125 06/25/13 100%0%0%
1C‐127 04/25/13 100%0%0%
1C‐127 10/11/13 100%0%0%
1C‐135 10/07/13 0%0%100%
1C‐170 04/21/13 0%0%100%
1C‐170 11/06/13 0%0%100%
1C‐172A 01/07/13 100%0%0%
1C‐172A 04/21/13 100%0%0%
1C‐172A 11/06/13 100%0%0%
1C‐178 01/07/13 0%46%54%
1C‐178 11/03/13 0%31%69%
1C‐184 01/07/13 0%0%100%
1C‐184 04/21/13 0%0%100%
1C‐184 11/03/13 0%0%100%
1D‐102 03/25/13 0%50%51%
1D‐105A 03/23/13 0%0%100%
1D‐105A 05/23/13 0%0%100%
1D‐105A 11/06/13 0%0%100%
1D‐108 03/23/13 23%42%35%
1D‐108 11/06/13 32%25%43%
1D‐112 11/04/13 37%40%23%
1D‐113 03/23/13 33%19%48%
1D‐113 05/23/13 30%28%42%
1D‐113 11/04/13 33%36%31%
1D‐115 03/23/13 29%30%41%
1D‐115 05/23/13 35%36%30%
1D‐115 11/04/13 34%38%28%
1D‐116 03/23/13 22%30%49%
1D‐116 05/23/13 26%29%45%
1D‐116 11/04/13 39%38%23%
1D‐123 03/23/13 60%21%18%
1D‐123 05/23/13 54%32%15%
1D‐123 10/06/13 55%27%18%
1D‐124 03/23/13 36%42%22%
1D‐124 05/23/13 29%49%22%
1D‐124 10/06/13 30%31%38%
1D‐127 03/23/13 27%47%26%
1D‐127 05/23/13 40%35%26%
1D‐131 11/04/13 47%53%0%
1D‐133 03/23/13 59%13%28%
1D‐133 05/23/13 60%18%22%
1D‐133 11/04/13 55%23%22%
1D‐135 03/23/13 5%23%72%
1D‐135 05/23/13 6%27%67%
1D‐135 11/04/13 1%32%67%
1D‐141A 03/23/13 0%0%100%
GKA Annual Surveillance Report West Sak Oil Pool 139
ATTACHMENT 7
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Special Survey Date
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1D‐141A 04/08/13 0%0%100%
1D‐141A 05/04/13 0%0%100%
1D‐141A 06/01/13 0%0%100%
1D‐141A 07/11/13 0%0%100%
1D‐141A 08/07/13 0%0%100%
1D‐141A 09/08/13 0%0%100%
1D‐141A 10/06/13 0%0%100%
1D‐141A 11/06/13 0%0%100%
1D‐141A 12/06/13 0%0%100%
1E‐121 03/24/13 0%65%35%
1E‐121 04/08/13 0%78%22%
1E‐121 05/03/13 0%63%37%
1E‐121 06/01/13 0%59%41%
1E‐121 07/11/13 0%84%17%
1E‐121 08/11/13 0%82%18%
1E‐121 09/12/13 0%46%54%
1E‐121 10/06/13 0%46%54%
1E‐121 11/08/13 0%36%65%
1E‐121 12/05/13 0%66%34%
1E‐123 01/07/13 0%31%69%
1E‐123 04/22/13 0%44%56%
1E‐123 07/11/13 0%47%53%
1E‐123 10/06/13 0%20%80%
1E‐123 10/29/13 0%33%67%
1E‐123 11/06/13 0%33%67%
1E‐123 12/05/13 0%41%60%
1E‐126 03/24/13 10%57%33%
1E‐126 04/05/13 8%43%49%
1E‐126 05/04/13 23%25%52%
1E‐126 06/01/13 28%28%44%
1E‐126 07/11/13 43%21%36%
1E‐126 08/09/13 45%21%34%
1E‐126 09/12/13 44%15%41%
1E‐126 10/06/13 35%0%65%
1E‐126 11/08/13 9%25%66%
1E‐126 12/05/13 57%3%40%
1E‐166 03/24/13 7%24%69%
1E‐166 04/05/13 7%17%76%
1E‐166 05/04/13 2%39%59%
1E‐166 06/04/13 9%34%57%
1E‐166 07/11/13 13%30%58%
1E‐166 08/09/13 1%9%90%
1E‐166 09/12/13 9%37%54%
1E‐166 10/07/13 0%39%61%
1E‐166 11/08/13 8%51%41%
1E‐166 11/10/13 17%25%58%
1E‐168 03/24/13 14%0%86%
1E‐168 04/08/13 27%0%73%
1E‐168 05/04/13 13%0%87%
1E‐168 06/04/13 17%0%83%
1E‐168 07/11/13 0%0%100%
1E‐168 08/09/13 77%0%23%
GKA Annual Surveillance Report West Sak Oil Pool 140
ATTACHMENT 7
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Special Survey Date
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1E‐168 09/12/13 19%0%81%
1E‐168 10/23/13 0%0%100%
1E‐168 11/06/13 0%0%100%
1E‐168 11/10/13 0%0%100%
1E‐170 03/24/13 0%67%33%
1E‐170 04/08/13 0%69%31%
1E‐170 05/04/13 0%66%34%
1E‐170 06/04/13 0%50%50%
1E‐170 07/04/13 0%62%38%
1E‐170 08/09/13 0%42%58%
1E‐170 09/12/13 0%46%54%
1E‐170 10/07/13 0%80%20%
1E‐170 11/08/13 0%36%64%
1J‐101 03/05/13 32%30%38%
1J‐101 05/22/13 30%30%40%
1J‐101 10/30/13 25%34%41%
1J‐103 02/02/13 8%44%48%
1J‐103 04/05/13 19%26%55%
1J‐103 05/04/13 13%27%61%
1J‐103 06/01/13 25%24%51%
1J‐103 07/11/13 27%26%47%
1J‐103 08/07/13 28%27%45%
1J‐103 09/11/13 7%26%66%
1J‐103 10/07/13 7%32%61%
1J‐103 11/06/13 4%18%78%
1J‐103 12/06/13 5%14%81%
1J‐107 03/05/13 0%0%100%
1J‐107 04/21/13 0%0%100%
1J‐107 10/30/13 0%0%100%
1J‐115 03/05/13 18%28%54%
1J‐115 05/04/13 17%23%60%
1J‐115 05/22/13 27%31%42%
1J‐115 10/30/13 12%26%63%
1J‐120 03/24/13 0%47%53%
1J‐120 04/05/13 7%10%83%
1J‐120 05/04/13 4%11%85%
1J‐120 06/01/13 11%11%78%
1J‐120 07/11/13 11%10%79%
1J‐120 08/07/13 10%10%80%
1J‐120 09/11/13 9%11%80%
1J‐120 10/07/13 8%11%80%
1J‐120 11/06/13 10%12%79%
1J‐120 12/06/13 6%14%80%
1J‐135 07/11/13 0%39%61%
1J‐135 10/30/13 0%22%78%
1J‐137 03/05/13 0%61%39%
1J‐137 10/30/13 0%35%65%
1J‐152 03/05/13 35%29%36%
1J‐152 04/22/13 31%27%41%
1J‐152 10/30/13 7%69%25%
1J‐158 03/24/13 0%75%25%
1J‐158 05/22/13 0%80%20%
GKA Annual Surveillance Report West Sak Oil Pool 141
ATTACHMENT 7
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Special Survey Date
Geochemical Oil Production Splits
Well Name Sample Date A Sand B Sand D Sand
1J‐158 11/03/13 0%75%25%
1J‐159 06/07/13 10%70%20%
1J‐159 11/03/13 59%18%24%
1J‐162 03/24/13 0%90%10%
1J‐166 01/29/13 20%27%53%
1J‐166 03/07/13 18%9%73%
1J‐166 03/24/13 15%5%80%
1J‐166 04/08/13 17%9%73%
1J‐166 05/04/13 17%20%64%
1J‐166 06/01/13 24%9%67%
1J‐166 07/11/13 33%4%63%
1J‐166 08/07/13 33%25%42%
1J‐166 09/11/13 16%20%63%
1J‐166 11/10/13 12%14%74%
1J‐166 12/06/13 16%41%43%
1J‐168 01/29/13 44%49%7%
1J‐168 04/08/13 52%25%23%
1J‐168 05/04/13 44%33%24%
1J‐168 06/01/13 66%8%25%
1J‐168 07/11/13 67%7%26%
1J‐168 08/07/13 2%44%53%
1J‐168 09/11/13 24%64%12%
1J‐168 10/07/13 27%62%12%
1J‐168 11/03/13 28%58%14%
1J‐168 11/10/13 26%59%16%
1J‐168 12/13/13 33%50%17%
1J‐174 03/24/13 0%52%48%
1J‐174 04/22/13 0%55%45%
1J‐174 11/03/13 0%46%54%
1J‐178 03/24/13 0%63%37%
1J‐178 11/04/13 0%53%47%
1J‐182 03/24/13 0%77%23%
1J‐182 04/22/13 0%69%31%
1J‐182 11/04/13 0%100%0%
3K‐102 10/05/13 0%62%38%
3K‐105 04/13/13 0%14%87%
3K‐105 04/24/13 0%50%50%
3K‐105 05/03/13 0%25%75%
3K‐105 07/04/13 0%33%67%
3K‐105 08/09/13 0%41%60%
3K‐105 08/18/13 0%44%56%
3K‐105 09/04/13 0%43%57%
3K‐105 10/05/13 0%46%54%
3K‐105 11/09/13 0%46%54%
3K‐105 12/09/13 0%43%57%
GKA Annual Surveillance Report West Sak Oil Pool 142
ATTACHMENT 8
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Allocation Factors
Month
01/31/13
Oil
0.9509
Gas
0.9216
Water
1.0324
02/28/13 0.9630 0.9956 1.0276
03/31/13 0.9422 0.9808 1.0466
04/30/13 0.9442 0.9713 1.0604
05/31/13 0.9381 0.9960 1.0554
06/30/13 0.9227 1.0102 1.0768
07/31/13 0.9482 0.9944 1.0661
08/31/13 0.9376 0.9891 1.0529
09/30/13 0.9606 0.8763 1.0756
10/31/13 0.9505 0.8634 1.0876
11/30/13 0.9494 0.9346 1.0872
12/31/13 0.9542 0.9327 1.0685
GKA Annual Surveillance Report West Sak Oil Pool 143
Attachment 9
Kuparuk River Unit
West Sak Oil Pool
2013 Annual Reservoir Surveillance Report
Development Plans and Operational Review
•WEST SAK DEVELOPMENT
Three West Sak wells were drilled in 2013.
Well 3K‐105 producer started up in March 2013 at average 800 bopd over the subsequent 10 month period.
Well 1C‐150 injector was completed in November 2013 with first water injection expected in 1Q 2014. Well
1C‐151 producer was completed in December 2013 with first oil production expected in 1Q 2014.
Performance monitoring of these D‐sand horizontal wells may lead to additional drillsite 1C development.
•EASTERN NORTH EAST WEST SAK (ENEWS) DEVELOPMENT
The Kuparuk River Unit filed a permit application to advance a viscous oil development program within
ENEWS. The development will be an extension of the existing drillsite 1H with 19 new wells, and will be
called 1H NEWS (Northeast West Sak).
•NORTHWEST WEST SAK (3R)
The Kuparuk River Unit working interest owners are working geologic and geophysical elements to better
understand the structural complexities of the West Sak in the area of drillsite 3R. Upon completion of that
work, detailed planning of a well or well pair to assess D‐sand oil quality and the viability of the N‐sand in
the area will commence.
GKA Annual Surveillance Report West Sak Oil Pool 144
GAS OFFTAKE
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Attachment 1
Kuparuk River Oil Pool
2013 Annual Reservoir Surveillance Report
Gas Offtake Data
MSCFD SCFD RB/D
January 485 485129 428
February 525 524586 463
March 391 391452 346
April 423 422933 373
May 421 421065 372
June 348 348267 308
July 343 342742 303
August 371 370516 327
September 386 385933 341
October 335 335355 296
November 330 329567 291
December 454 454419 401
Average 401 400,997 354
2013 Monthly Gas Offtake
GKA Annual Surveillance Report Kuparuk Oil Pool Gas Offtake 149
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