Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2020 Milne Point Unit
Milne Point Unit
Waterflood and Reservoir Surveillance Report
for
Kuparuk River Oil Pool
Schrader Bluff Oil Pool
Sag River Oil Pool
January through December, 2020
Issued: May 1st, 2021
Outline
1. Introduction
2. Kuparuk River Oil Pool
a. Project Summary
b. Reservoir Voidage Balance Table
c. Pressure Data
d. Injection Surveys
3. Schrader Bluff Oil Pool
a. Project Summary
b. Reservoir Voidage Balance Table
c. Pressure Data
d. Injection Surveys
4. Sag River Oil Pool
a. Project Summary
b. Reservoir Voidage Balance Table
c. Pressure Data
5. Milne Point Pool Allocation Factors
6. Milne Point 2020 Development Review and 2021 Development Plan
ANNUAL RESERVOIR SURVEILLANCE REPORTS
MILNE POINT UNIT
KUPARUK RIVER OIL POOL
SCHRADER BLUFF OIL POOL
SAG RIVER OIL POOL
JANUARY - DECEMBER 2019
Introduction
As required by Conservation Order 205 for the Kuparuk River Oil Pool, approved October 4,
1984, Conservation Order 477, approved August 23, 2002 for the Schrader Bluff Oil Pool,
Conservation Order 423 for the Sag River Oil Pool, approved May 6, 1998, and Conservation
Order 550.007 for all Milne Point Pools, approved January 6, 2009, and Conservation Order
550.006 for all Milne Point Pools, amended February 14, 2015, this report provides a
consolidated summary of surveillance activities within the Milne Point Unit. The report includes
surveillance data associated with waterflood projects and development activities. The time period
covered is January through December 2019.
Kuparuk River Oil Pool Waterflood
Project Summary
Cumulative water injection since waterflood startup through the end of 2020 is 647 MMSTB and
cumulative gas injection is 116.6 BSCF.
This data shows that the voidage replacement ratio averaged 0.72 RB/RB in 2020 compared to
0.86 RB/RB in 2020.
The Kuparuk River Oil Pool is split up in Hydraulic Units which represent regions of the
reservoir that are believed to be hydraulically isolated due to faulting and/or lithologic controls.
In 2020, 5 static pressure readings were obtained in the Kuparuk River reservoir. Average
pressure from those readings was 2270 psi at a datum depth of 7000’ SSTVD
Milne Point Unit
Kuparuk Pool
Daily Production Rate Averages By Month:Daily Injection Rate Averages By Month:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Prod Rate Prod Rate Prod Rate Voidage Inj Rate Inj Rate Replacement Replacement Balance
12/31/2012 (stb/day)(stb/day)(mscf/day)(rbbl/day)(stb/day)(mscf/day)(rbbl/day)Ratio (rbbl/day)
1/31/2020 9,128 59,264 9,953 77,225 48,973 6,059 54,900 0.71 -22,326
2/29/2020 9,063 56,062 10,376 74,275 49,942 6,315 56,103 0.76 -18,172
3/31/2020 8,503 52,381 11,130 70,662 44,771 6,611 51,109 0.72 -19,553
4/30/2020 9,470 55,439 11,972 75,392 51,713 6,733 58,259 0.77 -17,133
5/31/2020 9,292 52,030 11,361 71,242 51,523 5,821 57,284 0.80 -13,958
6/30/2020 9,731 54,338 12,013 74,554 54,194 7,061 61,058 0.82 -13,495
7/31/2020 9,134 57,051 11,297 76,135 55,721 6,154 61,831 0.81 -14,304
8/31/2020 7,853 52,140 9,562 68,465 56,182 5,185 61,469 0.90 -6,997
9/30/2020 8,067 54,331 11,017 72,137 53,862 6,667 60,383 0.84 -11,754
10/31/2020 8,634 57,387 11,492 76,176 43,774 5,764 49,371 0.65 -26,805
11/30/2020 9,205 53,325 11,014 72,178 41,808 7,131 48,546 0.67 -23,632
12/31/2020 9,725 55,992 11,211 75,540 42,656 6,443 48,817 0.65 -26,723
Cumulative Production By Month:Cumulative Injection By Month:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Cumulative Cumulative Cumulative Voidage Cumulative Cumulative Replacement Replacement Balance
12/31/2012 (stb)(stb)(mscf)(rbbl)stb mscf (rbbl)Ratio (rbbl)
1/31/2020 282,979 1,837,195 308,556 2,393,988 1,518,155 187,821 1,701,894 0.71 -692,094
2/29/2020 262,815 1,625,786 300,907 2,153,983 1,448,328 183,126 1,626,995 0.76 -526,988
3/31/2020 263,579 1,623,811 345,034 2,190,511 1,387,912 204,938 1,584,366 0.72 -606,145
4/30/2020 284,103 1,663,156 359,173 2,261,769 1,551,400 201,993 1,747,783 0.77 -513,986
5/31/2020 288,052 1,612,923 352,202 2,208,504 1,597,200 180,438 1,775,797 0.80 -432,707
6/30/2020 291,929 1,630,137 360,380 2,236,613 1,625,809 211,842 1,831,749 0.82 -404,864
7/31/2020 283,155 1,768,570 350,213 2,360,198 1,727,359 190,780 1,916,771 0.81 -443,427
8/31/2020 243,440 1,616,335 296,428 2,122,423 1,741,638 160,747 1,905,526 0.90 -216,897
9/30/2020 242,009 1,629,939 330,516 2,164,106 1,615,858 200,001 1,811,501 0.84 -352,605
10/31/2020 267,662 1,779,003 356,243 2,361,458 1,356,995 178,687 1,530,488 0.65 -830,970
11/30/2020 276,164 1,599,747 330,425 2,165,343 1,254,237 213,922 1,456,386 0.67 -708,957
12/31/2020 301,476 1,735,748 347,537 2,341,735 1,322,325 199,725 1,513,328 0.65 -828,407
Average:
2020 8,984 54,978 11,033 73,665 49,593 6,329 1,700,215 0.76 -546,504
Cumulative:stb stb mscf rb stb mscf rb rb
31-Dec-20 3,287,363 20,122,349 4,037,614 26,858,116 18,147,216 2,314,020 22,123,455 0.82 -4,734,660
RESERVOIR VOIDAGE BALANCE
January - December 2020
6. Oil Gravity:
23
8. Well Name
and Number:
9. API Number
50XXXXXXXXXXXX
NO DASHES
10. Type
See
Instruction
s
11. AOGCC
Pool Code
12. Zone 13. Perforated Intervals
Top - Bottom TVDSS
14. Final Test
Date
15. Shut-
In Time,
Hours
16. Press.
Surv. Type
(see
instructions
for codes)
17. B.H.
Temp.
18. Depth
Tool
TVDSS
19. Final
Observed
Pressure
at Tool
Depth
20. Datum
TVDSS
(input)
21. Pressure
Gradient,
psi/ft.
22. Pressure
at Datum
(cal)
C-21 50029224860000 WI 525140
C,B6,
A3,A2,A1 7165'7209',73282'-7391'12/15/2020 LTSI SBHP 107 4950 1830 7000'0.43 2690
MP L-04 50029220290000 O 525140
C,B6,
A3,A2,A1
7151'-7212'',7229-
7240',7244-7263',7274'-
7297'10/11/2020 27 SBHP 180 7080'2611 7000'0.43 2645
MP F-37 50029225480000 O 525140 A1 7257'-7287', 7295'-7349', 1/5/2020 3 SBHP 164 7157 2098 7000'0.43 2165
MP F-79 50029224890100 O 525140 A2,A1
7116'-7128',7138'-
7147',7158'-7176', 7172'-
7156'8/19/2020 120 SBHP 174 6284'1728 7000'0.43 2038
MP F-86 50029230180000 O 525140 A3,A2,A1
7026'-7036',7043'-
7053',7064'-7074',7046'-
7085'8/19/2020 72 SBHP 190 6723'1690 7000'0.43 1809
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:
Daniel Taylor
23. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission.
I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signature
7. Gas Gravity:
Milne Point Kuparuk River Oil Pool
Printed Name
Title
Date
Reservoir Enginner
March 29, 2021
7000' SS 0.65
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Hilcorp Alaska , LLC.3800 Centerpoint Dr. Anchorage, AK, 99516
Kuparuk 2020 PLT Surveys
Well Name Reservoir Well Type Rec Date Log Type Field Analysis Final Determination
F-49 KUP WINJ 8/11/2020 STP/IPROF Inj. 1650 bwpd at 850psi at 60
deg F.C 15%, A 85%
E-07 KUP WINJ 6/25/2020 STP/IPROF Inj. 1700bwpd C 68%, B 32%
E-23 KUP WINJ 8/16/2020 STP/IPROF Inj. 2400 bwpd at 110 deg F.B 100%
C-28 KUP WINJ 8/17/2020 STP/IPROF Inj. 2410 bwpd at 100 deg F.C 6%, B 7%, A 87%
L-16 KUP WINJ 8/26/2020 STP/IPROF Inj. 3000 bwpd at 58 deg F.C 5%, B 5%, A 90%.
L-05 KUP WINJ 9/11/2020 STP/IPROF Inj. 2000 bwpd at 55 deg F.C 27%, B 27%, A 46%
C-19 KUP WINJ 9/27/2020 STP/IPROF Inj. 2348 bwpd at 119 deg F.C 30%, A 70%
F-84 KUP WINJ 9/28/2020 STP/IPROF Inj. 2520 bwpd at 58 deg F.A 100%
Schrader Bluff Oil Pool Waterflood
Project Summary
The Schrader Bluff Oil Pool cumulative voidage replacement for the calendar year 2020 was 0.9 (target 1.0) with a cumulative voidage replacement
for the life of the project is 0.86.
New developments in the Schrader continue to utilize source water primarily from the shallower prince creek formation. All new developments since
Hilcorp’s purchase of the asset in 2014 have utilized clean source water for injection. Utilizing produced water for injection at Milne Point has
shown to be detrimental to injectivity due to solids and produced crude carry over accumulating in the injection wells. All future developments in the
Schrader Bluff will plan to use clean source water.
Hilcorp continued the Schrader Nb sand polymer injection pilots at J and L pads that were started in 2018. Results have been very encouraging with
observed decreased water cuts and delayed water breakthrough. Polymer injection facilities were installed and injection initiated in the Schrader Oa
sand developments at F and Moose Pad in May and July of 2020, respectively. A Polymer injection facility was installed and injection initiated
November 2020 in the recently drilled I Pad redevelopment which targeted mature waterflood Schrader sands in an previously developed fault block.
An additional polymer injection unit was recently installed and initiated injection into E Pad Schrader development wells that were drilled and
completed in 2019. Current total polymer injection rate into the Schrader Bluff is approximately 25,000 bwpd.
Average pressure throughout the field is 1504 psi at reference depth of 4000’ SSTVD based on 2020 surveys taken. Original pressure at reference
depth was 1730 psi.
Milne Point Unit
Schrader Bluff Pool
Production Rate Averages:Injection Rate Averages:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Prod Rate Prod Rate Prod Rate Voidage Inj Rate Inj Rate Replacement Replacement Balance
12/31/2012 (stb/day)(stb/day)(mscf/day)(rbbl/day)(stb/day)(mscf/day)(rbbl/day)Ratio (rbbl/day)
1/31/2020 22,030 20,269 6,892 48,097 41,152 0 41,564 0.86 -6,533
2/29/2020 22,346 19,981 7,525 49,021 44,580 0 45,025 0.92 -3,996
3/31/2020 21,499 17,459 6,425 44,130 43,868 0 44,307 1.00 177
4/30/2020 22,586 18,829 5,624 45,125 45,311 0 45,764 1.01 639
5/31/2020 22,472 15,564 4,904 40,634 41,860 0 42,278 1.04 1,644
6/30/2020 22,289 16,898 5,604 42,914 34,596 0 34,942 0.81 -7,972
7/31/2020 22,558 19,095 5,076 44,531 36,089 0 36,450 0.82 -8,080
8/31/2020 24,391 19,706 5,628 47,414 38,618 0 39,004 0.82 -8,410
9/30/2020 24,241 19,384 6,081 47,666 42,412 0 42,837 0.90 -4,830
10/31/2020 25,999 21,532 5,757 50,700 42,577 0 43,002 0.85 -7,698
11/30/2020 26,374 24,546 7,236 56,305 45,042 0 45,492 0.81 -10,813
12/31/2020 25,640 22,998 7,272 54,228 44,272 0 44,715 0.82 -9,513
Cumulative Production:Cumulative Injection:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Cumulative Cumulative Cumulative Voidage Cumulative Cumulative Replacement Replacement Balance
12/31/2012 (stb)(stb)(mscf)(rbbl)stb mscf (rbbl)Ratio (rbbl)
1/31/2020 682,940 628,330 213,667 1,490,994 1,275,718 0 1,288,475 0.86 -202,519
2/29/2020 648,036 579,456 218,223 1,421,621 1,292,807 0 1,305,735 0.92 -115,886
3/31/2020 666,463 541,226 199,178 1,368,028 1,359,904 0 1,373,503 1.00 5,475
4/30/2020 677,572 564,870 168,725 1,353,755 1,359,319 0 1,372,912 1.01 19,157
5/31/2020 696,646 482,494 152,015 1,259,660 1,297,653 0 1,310,630 1.04 50,970
6/30/2020 668,655 506,942 168,130 1,287,435 1,037,892 0 1,048,271 0.81 -239,164
7/31/2020 699,299 591,938 157,353 1,380,446 1,118,772 0 1,129,960 0.82 -250,486
8/31/2020 756,120 610,881 174,475 1,469,823 1,197,157 0 1,209,129 0.82 -260,695
9/30/2020 727,223 581,506 182,419 1,429,993 1,272,374 0 1,285,098 0.90 -144,895
10/31/2020 805,976 667,497 178,472 1,571,714 1,319,876 0 1,333,075 0.85 -238,639
11/30/2020 791,219 736,371 217,090 1,689,143 1,351,251 0 1,364,764 0.81 -324,379
12/31/2020 794,825 712,937 225,431 1,681,069 1,372,442 0 1,386,166 0.82 -294,902
Average:
2020 23,535 19,688 6,169 47,564 41,698 0 42,115 0.89 -5,449
Cumulative:stb stb mscf rb stb mscf rb rb
31-Dec-20 8,614,974 7,204,448 2,255,178 17,303,432 15,255,165 0 15,560,268 0.90 -1,743,164
RESERVOIR VOIDAGE BALANCE
January - December 2020
6. Oil Gravity:
13-22
8. Well Name and
Number:
9. API Number
50XXXXXXXXXXXX
NO DASHES
10. Type
See
Instructions
11. AOGCC
Pool Code
12. Zone 13. Perforated
Intervals
Top - Bottom
TVDSS
14. Final Test
Date
15. Shut-In
Time, Hours
16. Press. Surv.
Type (see
instructions for
codes)
17. B.H.
Temp.
18. Depth
Tool TVDSS
19. Final
Observed
Pressure at
Tool Depth
20. Datum
TVDSS (input)
21. Pressure
Gradient, psi/ft.
22. Pressure at
Datum (cal)
J-19 500292260700 WI 525140 Oa 4014-4047 1/9/2020 3121 SBHP 81 3871 1292 4000.00 0.41 1349
J-01 500292207000 O 525140 Oa/Ob 3979-3984 1/9/2020 2144 SBHP 72 3635 1683 4000.00 0.41 1833
I-19 500292321800 O 525140 Oa/Ob 3944-3990 1/9/2020 1974 SBHP 78 3377 1241 4000.00 0.41 1496
J-08A 500292249701 O 525140 Ob 4038-4051 3/2/2020 22578 SBHP 76 3684 1437 4000.00 0.41 1567
S-28 500292315800 O 525140 Nb 3915-3944 8/25/2020 281 SBHP 80 3770 1360 4000.00 0.41 1454
M-10 500292361700 O 525140 Oa 3950-4000 9/20/2020 352 SBHP 77 3797 1560 4000.00 0.41 1643
M-11 500292362100 WI 525140 Oa 3880-3981 11/1/2020 3489 SBHP 72 3857 1660 4000.00 0.41 1719
E-42 500292363500 O 525140 Oa/Ob 4196-4252 5/16/2020 148 SBHP 82 4053 1168 4000.00 0.41 1146
E-41 500292362200 O 525140 Nb 4313-4352 8/14/2020 974 SBHP 89 4018 1995 4000.00 0.41 1988
F-107 500292359200 O 525140 Oa 4085-4094 7/7/2020 1682 SBHP 77 3663 1711 4000.00 0.41 1849
I-17 500292321200 O 525140 Nb/Oa/Ob 3819-3902 7/29/2020 53 SBHP 79 3890 1105 4000.00 0.41 1150
I-11 500292303300 O 525140 Oa/Ob 3497-3612 12/20/2020 5126 SBHP 72 3485 1405 4000.00 0.41 1616
I-06 500292282200 O 525140 Oa/Ob 3781-3840 11/4/2020 258 SBHP 80 3923 1182 4000.00 0.41 1214
I-03 500292206700 O 525140 Na/Nb/Nc/Ne/Oa/Ob 3733-3972 12/31/2020 265 SBHP 80 3464 1042 4000.00 0.41 1262
G-16 500292318900 O 525140 Oa/Ob 4240-4382 5/20/2020 530 SBHP 82 4153 1421 4000.00 0.41 1358
G-14 500292303100 O 525140 Na/Nb/Ne/Oa/Ob 3929-4152 12/17/2020 8006 SBHP 80 3850 1759 4000.00 0.41 1821
G-15 500292278400 O 525140 Nb/Nc/Oa/Ob 3984-4214 12/31/2020 51504 SBHP 84 3927 1840 4000.00 0.41 1870
G-18 500292319400 O 525140 Oa/Ob 4079-4120 5/21/2020 550 SBHP 84 3863 1311 4000.00 0.41 1367
H-16 500292322700 O 525140 Oa/Ob 3872-3994 2/20/2020 449 SBHP 77 3863 1303 4000.00 0.41 1359
J-26 500292320500 O 525140 Oa/Ob 3749-3967 11/5/2020 2208 SBHP 77 3789 1287 4000.00 0.41 1374
J-25 500292320700 O 525140 Nb 3802-3817 7/2/2020 61 SBHP 75 3518 1009 4000.00 0.41 1207
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:
Reid Edwards
23. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission.
I hereby certify that the foregoing is true and correct to the best of my knowledge.
Reid EdwardsSignature
7. Gas Gravity:
Milne Point Milne Point - Schrader Bluff
Printed Name
Title
Date
Reservoir Engineer
March 30, 2021
4000 0.56
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Hilcorp Alaska LLC 3800 Center Point Dr, Anchorage , AK 99503
Schrader Bluff PLT Logs and Analysis
No PLT logs were run on multi-sand injectors in 2020. Total active multi-sand injectors currently sits at 13 out of total 55 active injectors.
Remaining active injectors are either dual string vertical injectors single string horizontal injectors targeting individual sands.
Sag River Oil Pool Waterflood
Project Summary
A Participating Area for the Sag was approved in 2005. During 2020, Sag Oil Pool had the field total to 6 production, and no active injection wells.
There was no production from the reservoir in most of 1999 and the entire year of 2000 because it was not economical to repair the failed ESPs. At
the end of 2000, one well (MPC-23) was converted to a jet pump completion. In 2001, one well (MPF-33A) was side-tracked and completed with a
jet pump completion and another well (MPF-73A) was deepened from an idle Kuparuk well into the Sag River reservoir as an injector. One
producing well (MPC-23) was shut in for integrity reasons in 2002 and the injection well (MPF-73A) was changed to water service only in 2006 due
to tubing to inner annulus communication on gas injection.
The Sag River Pool oil production averaged 477 STBD and water production averaged 1071 STBD in 2020. Cumulative production through the end
of 2019 is 3.88 MMSTB of oil, 5.3 BSCF of gas, and 4.2 MMSTB of water. The decreases in production in 2020 was due to natural decline and no
addition wells drilled in 2020.
During 2020 two pressure surveys were obtained indicating an average reservoir pressure of 1690 psi at a datum depth of 8750’ SSTVD. SI build up
times will be extended.
Milne Point Unit
Sag Pool
Production Rate Averages:Injection Rate Averages:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Prod Rate Prod Rate Prod Rate Voidage Inj Rate Inj Rate Replacement Replacement Balance
12/31/2012 (stb/day)(stb/day)(mscf/day)(rbbl/day)(stb/day)(mscf/day)(rbbl/day)Ratio (rbbl/day)
1/31/2020 452 1,604 1,127 3,206 0 0 0 0.00 -3,206
2/29/2020 409 1,269 1,067 2,767 0 0 0 0.00 -2,767
3/31/2020 471 1,042 1,083 2,599 0 0 0 0.00 -2,599
4/30/2020 604 1,118 1,140 2,837 0 0 0 0.00 -2,837
5/31/2020 538 790 1,059 2,365 0 0 0 0.00 -2,365
6/30/2020 406 907 1,023 2,347 0 0 0 0.00 -2,347
7/31/2020 693 903 1,253 2,807 0 0 0 0.00 -2,807
8/31/2020 517 1,059 909 2,459 0 0 0 0.00 -2,459
9/30/2020 421 1,034 794 2,237 0 0 0 0.00 -2,237
10/31/2020 416 708 577 1,662 0 0 0 0.00 -1,662
11/30/2020 419 1,039 1,133 2,611 0 0 0 0.00 -2,611
12/31/2020 375 1,380 894 2,665 0 0 0 0.00 -2,665
Cumulative Production:Cumulative Injection:
Oil Water Gas Reservoir Water Gas Voidage Voidage Voidage
Month Cumulative Cumulative Cumulative Voidage Cumulative Cumulative Replacement Replacement Balance
12/31/2012 (stb)(stb)(mscf)(rbbl)stb mscf (rbbl)Ratio (rbbl)
1/31/2020 14,026 49,722 34,927 99,384 0 0 0 0.00 -99,384
2/29/2020 11,852 36,808 30,944 80,235 0 0 0 0.00 -80,235
3/31/2020 14,587 32,317 33,563 80,554 0 0 0 0.00 -80,554
4/30/2020 18,117 33,538 34,197 85,116 0 0 0 0.00 -85,116
5/31/2020 16,675 24,480 32,829 73,308 0 0 0 0.00 -73,308
6/30/2020 12,167 27,219 30,699 70,420 0 0 0 0.00 -70,420
7/31/2020 21,487 27,988 38,829 87,031 0 0 0 0.00 -87,031
8/31/2020 16,028 32,824 28,176 76,243 0 0 0 0.00 -76,243
9/30/2020 12,641 31,012 23,809 67,096 0 0 0 0.00 -67,096
10/31/2020 12,890 21,945 17,874 51,533 0 0 0 0.00 -51,533
11/30/2020 12,557 31,169 33,976 78,327 0 0 0 0.00 -78,327
12/31/2020 11,611 42,784 27,718 82,619 0 0 0 0.00 -82,619
Average:
2020 477 1,071 1,005 2,547 0 0 0 0.00 -2,547
Cumulative:stb stb mscf rb stb mscf rb rb
31-Dec-20 174,638 391,805 367,541 865,763 0 0 0 0.00 -865,763
RESERVOIR VOIDAGE BALANCE
January - December 2020
6. Oil Gravity:
38
8. Well Name
and Number:
9. API Number
50XXXXXXXXXX
XX NO DASHES
10. Type
See
Instructio
ns
11.
AOGCC
Pool
Code
12. Zone
13. Perforated
Intervals
Top - Bottom
TVDSS
14. Final
Test Date
15. Shut-
In Time,
Hours
16. Press. Surv.
Type (see
instructions for
codes)
17. B.H.
Temp.
18.
Depth
Tool
TVDSS
19. Final
Observed
Pressure
at Tool
Depth
20. Datum
TVDSS (input)
21.
Pressure
Gradient,
psi/ft.
22.
Pressure
at Datum
(cal)
MP S-90 50029232760000 PROD 525150 Sag A, B 8,791’-8,827’8/9/2019 15 DH Press Gauge 225 8507 2060 8750 0.39 2154
MP C-46 50029235760000 PROD 525150 Sag A, B 8,728’-8,753’8/19/2020 96 DH Press Gauge 223 8493 1115 8750 0.39 1226
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:
Daniel Taylor
23. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission.
I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signature
7. Gas Gravity:
Milne Point Sag River Oil Pool
Printed Name
Title
Date
Reservoir Enginner
March 30, 2021
8750' SS 0.65
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Hilcorp Alaska , LLC.3800 Centerpoint Dr. Anchorage, AK, 99516
MPU Pool Allocation Factors
Total Milne Point production increased a total of 2.7 MMBO from 2019 to 2020 primarily due to significant development drilling in
the Schrader Bluff sands
Production
Pool Oil Water Gas Oil Water Gas Oil Water Gas
stb stb mscf stb stb mscf stb stb mscf
Schrader Bluff 5858846 6373317 2172475 8614974 7204448 2255178 2756128 831131 82703
Kuparuk 3287182 20771207 3920084 3287363 20122349 4037614 181 -648858 117530
Sag River 153654 445501 310794 147638 391805 367541 -6016 -53696 56747
Total 9299682 27590025 6403353 12049975 27718602 6660333 2750293 128577 256980
Allocation
Pool Oil Water Gas Oil Water Gas Oil Water Gas
frac frac frac frac frac frac frac frac frac
Schrader Bluff 0.63 0.23 0.34 0.71 0.26 0.34 0.08 0.03 0.00
Kuparuk 0.35 0.75 0.61 0.27 0.73 0.61 -0.08 -0.03 -0.01
Sag River 0.02 0.02 0.05 0.01 0.01 0.06 0.00 0.00 0.01
20202019
2019 2020
2020-2019 Delta
2020-2019 Delta
MPU Well Tests and Oil Allocation Factors
Date Kuparuk Schrader Sag Total Kuparuk Schrader Sag Total Kuparuk Schrader Sag Total
Jan-20 383 234 29 646 69 49 6 124 5.6 4.8 4.8 5.2 0.91
Feb-20 307 226 15 548 67 51 5 123 4.6 4.4 3.0 4.5 0.91
Mar-20 293 222 24 539 70 53 5 128 4.2 4.2 4.8 4.2 0.85
Apr-20 391 269 31 691 69 52 6 127 5.7 5.2 5.2 5.4 0.85
May-20 371 259 21 651 70 53 5 128 5.3 4.9 4.2 5.1 0.85
Jun-20 385 236 25 646 71 53 5 129 5.4 4.5 5.0 5.0 0.89
Jul-20 344 196 28 568 68 55 5 128 5.1 3.6 5.6 4.4 0.91
Aug-20 324 158 20 502 65 55 5 125 5.0 2.9 4.0 4.0 0.88
Sep-20 285 112 20 417 68 55 5 128 4.2 2.0 4.0 3.3 0.90
Oct-20 284 137 14 435 73 56 5 134 3.9 2.4 2.8 3.2 0.89
Nov-20 267 136 18 421 68 56 5 129 3.9 2.4 3.6 3.3 0.88
Dec-20 245 103 8 356 70 56 5 131 3.5 1.8 1.6 2.7 0.85
MPU Oil
Allocation Factor
Well Test Count Active Well Count Average Well Test per well
Annual Plans of Development Review (38th (2020) and 39th (2021))
A. 38th POD Drilling Program – 21 wells drilled and completed in 2020
• Moose Pad Schrader Bluff
o M-24, M-34, M-43, and M-45 (4 horizontal producers)
o M-35, M-25, and M-44 (3 horizontal injectors)
• L Pad Schrader Bluff
o L-60 and L-62 (2 horizontal producers)
o L-59 and L-61 (2 horizontal injectors)
• S-Pad Schrader Bluff
o S-57 (1 horizontal producers)
o S-56 – ( 1 horizontal injector , Temporary P&A)
• I Pad Schrader Bluff
o I-36, I-38, I-40 (3 horizontal producers)
o I-35, I-37, and I-39 (3 horizontal injectors)
• K Pad Kuparuk
o K-44B sidetrack (1 vertical producer)
• L Pad Kuparuk injectors
o L-63 (vertical injector)
o L-21A (vertical injector)
• 1 F Pad Kuparuk vertical producer sidetrack – F-62A
B. 38th POD Workover Program – 25 well workover completed in 2020
• G-02 – Schrader Bluff producing well – ESP change out;
• F-58 – Prince Creek water source well – ESP change out;
• F-29 – Kuparuk producing well – ESP change out;
• I-19 – Schrader Bluff producing well – decomplete for I Pad redevelopment drilling
• F-116 – Kuparuk producing well – convert from jet pump to ESP;
• E-42 – Schrader Bluff producing well – failed ESP to jet pump conversion;
• J-01A – Schrader Bluff producing well – decomplete for I Pad redevelopment drilling
• J-03 – Schrader Bluff producing well – decomplete for I Pad redevelopment drilling
• L-25 – Kuparuk producing well – ESP change out;
• L-36 – Kuparuk producing well – ESP change out;
• E-41 – Schrader Bluff producing well – failed ESP to jet pump conversion;
• L-41 – Kuparuk producing well – ESP change out
• F-38 – Kuparuk producing well – convert from jet pump to ESP
• F-57 – Kuparuk producing well – decomplete for sidetrack
• F-54 – Kuparuk producing well – ESP change out
• I-14 – Schrader bluff producing well – downhole P&A for redevelopment drilling
• F-34 – Kuparuk producing well – ESP change out
• F-78 – Kuparuk producing well – ESP change out
• I-06 – Schrader Bluff producing well – ESP change out
• L-36 – Kuparuk producing well – ESP change out
• L-14 – Kuparuk producing well – ESP change out
• I-11 – Schrader Bluff producing well – convert from jet pump to ESP
• F-116 – Kuparuk producing well – ESP change out
• F-58 – Water Source Well – ESP change out
• J-10 – Kuparuk producing well – ESP change out
C. 38th POD Major Facility Projects
• F-Pad Schrader Bluff polymer facility installation and start-up;
• J and L-Pad polymer silo upgrade;
• LM2500 turbine overhaul completion;
• Portable heater for test separation;
• Solar Titan 130 power generator and associated infrastructure start-up;
• Moose Pad production segregation from F&L Separation;
• L-Pad PLC upgrade.
• Moose Pad Schrader Bluff polymer facility installation and start up;
• I-Pad electrical infrastructure upgrade;
• I-Pad test separator upgrade;
• I Pad polymer facility installation and start up
• Installation of Chemical Storage Tanks at B-Pad; and
• S Pad pad expansion
39th PLAN OF DEVELOPMENT AND OPERATIONS
A. Executed YTD Drilling Program (January 2021 through March 2021)
• I Pad Schrader Bluff
o I-21 horizontal injector
o I-28 horizontal injector
o I-07A vertical injector (Schrader Core Acquisition and Kuparuk untested fault block, found Kuparuk wet so recompleted as
Schrader injector
• J Pad Schrader Bluff
o J-29 horizontal producer (failure on completion)
o J-30 horizontal injector
• C Pad Kuparuk
o C-04A sidetrack CTD producer (current)
B. Propased Drilling Program (April 2021 to December 2021)
• I Pad Schrader Bluff
o I-20 horizontal producer
o I-27 horizontal producer
• S Pad Schrader Bluff
o S-45 horizontal producer
o S-45 horizontal injector
o S-46 horizontal producer
o S-47 horizontal injector
• C Pad Kuparuk
o C-11A sidetrack CTD injector
• F Pad Kuparuk
o F-22A sidetrack CTD injector
o F-05A sidetrack CTD producer
• L Pad Kuparuk
o L-06A sidetrack CTD producer
C. Executed wellwork and workover program (January 2021 through March 2021)
• I-07 - P&A for sidetrack I-07A
• I-38 – Schrader Bluff producer – ESP swap
• L-62 – Schrader Bluff producer – ESP swap
D. Planed wellwork and workover program (April 2021 through December 2021)
• I-40 – Schrader Bluff producer – converstion to jet pump
• Approx 15 additional unidentified workovers , majority of work repairing future failed ESPs
E. Major Facility Projects Planned for 2021
• F Pad Kuparuk polymer pilot installation and start up
• E-Pad Schrader Bluff polymer facility installation and start-up;
• Fuel gas compressor installation and start-up;
• 2020 Shutdown for A-Train process vessel inspections and upgrades; and
• G-Pad replacement test separator installation.
• S-Pad gas injection compressor installation and start-up;
• V-5304 Grid Replacement;
• S-Pad test separator replacement;
• S-Pad Polymer engineering / procurement;
• Solar Titan 130 Power generator engineering / procurement; and
• Diesel tank to slop oil tank conversion.
Long Term Development
Schrader Bluff
• Develop NW acreage in the Net Profit Share Leases (“NPSL”),
• Pending results from recent I Pad redevelopment drilling and polymer injection, continue redevelopment in the Tract 14 and S Pad areas
• Initiate chemical flood pilot in mature polymerflood pattern
Kuparuk
• Continue to infill drill utilize rotary and CTD drilling to maximize recovery in developed fault blocks
• Develop NW acreagea in the Net Profit Share Leases (“NPSL) with rotary horizontal producers and injectors
• Pending results of polymer pilot initiated in 2021, expand polymer injection into F and L pad Kuparuk wells
Sag
• Continue to work up economically viable development strategy
