Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout2019 Endicott Oil PoolHilcorp Alaska, LLC
Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8377
Fax: 907/777-8580
ckanyer@hilcorp.com
April 1st, 2020
Jeremy Price, Chair
Alaska Oil & Gas Conservation Commission
333 W. 7th Avenue, Suite 100
Anchorage, Alaska 99501-3539
RE: DUCK ISLAND UNIT, ENDICOTT FIELD, ENDICOTT OIL POOL, STATE OF ALASKA,
2019 ANNUAL RESERVOIR REVIEW
Dear Commissioner Price:
In accordance with Conservation Order No. 462, Hilcorp Alaska, LLC (“Hilcorp”), as Operator, hereby submits for
your review the following Annual Reservoir Review for the Endicott Field.
This is the Annual Reservoir Review and corresponds to events during the 2019 calendar year. The Endicott Field
has been on production since October 1987.
A.Progress of Enhanced Recovery Project and Reservoir Management Summary
During 2019, no new wells were drilled in the Duck Island Unit. Therefore the locations of all the wells in the
Northstar Unit have remained unchanged.
Production and injection statistics are summarized in Table 1. Average daily oil production from the Endicott Oil
Pool was 6,681 bopd and average daily gas injection was 336.0mmscfpd.
During 2019, injected fluid was calculated to be 10,242 thousand-reservoir barrels (MRB) less than reservoir
voidage. At year end, the reservoir overall cumulative voidage replacement ratio was 0.93. The average reservoir
pressure varies between zones. The average of surveys run in 2019 was 3,994psia.
Hilcorp became the official operator of the Endicott Field effective November 18, 2014. As a result, the historic
reservoir simulation model developed by the previous operator will no longer will be utilized in the enhanced
recovery or reservoir management. Hilcorp will continue to identify and improve waterflood pattern efficiency by
allocating existing water injection volumes and adding perforations in active injection wells. Hilcorp progressed
modeling of the SDI portion of the Kekiktuk K2B reservoir. The model was used to study and sanction additional
attic oil recovery with lean gas injection from SDI. This project was initiated in January 2020.
Page 2
B.Voidage Balance by Month of Produced Fluid and Injected Fluids – 2019
As of 12/31/2019 Full year (1)As of Dec-19 (2)
Producers 58 57
Injectors 25 25
2019
Cumulative Start-
Up through
12/31/19
2,438,480 479,237,034
122,636,985 3,656,317,595
82,519,797 1,832,068,727
82,683,749 2,176,534,839
110,376,460 3,252,889,944
168,345,713 4,725,678,559
158,103,984 4,359,227,336
-10,241,729 -366,451,223
6,681
335,992
226,082
226,531
302,401
3,994 psiaAverage of surveys obtained in 2019
Water, BWPD
Injection
Water, BWPD
Gas, MCFPD
AVERAGE RESERVOIR PRESSURE
DAILY AVERAGE RATE DATA 2019
Production
Oil, BOPD
Gas, MCF/D
Gas (MCF)
Balance
Cum Production (MRB)
Cum Injection (MRB)
Over/Under (MRB)
Oil (BBL)
Gas (MCF)
Water (BBL)
Injection
Water (BBL)
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2019
PRODUCTION/INJECTION STATISTICS
Production
Table 1: ENDICOTT FIELD 2019 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
NOTES:
Month Oil, RB Free Gas, RB
Water,
MRB
Total
Voidage,
MRB
Year
Cum, MRB
Cum since
start-up, MRB
Formation
Gas, MRB
Water,
MRB
Total
Injection,
MRB
Year
Cum, MRB
Cum since
start-up, MRB
Net
Injection,
MRB
Year
Cum, MRB
Cum since
start-up,
MRB
Jan-2019 296,065 7,223,840 7,474,698 14,994,603 14,994,603 4,579,204,460 6,560,779 7,543,737 14,104,516 14,104,516 4,254,978,638 -890,087 -890,087 -324,225,822
Feb-2019 265,617 6,308,137 6,545,738 13,119,493 28,114,096 4,592,323,953 5,713,384 6,575,088 12,288,472 26,392,988 4,267,267,109 -831,021 -1,721,108 -325,056,843
Mar-2019 286,150 6,683,795 7,004,977 13,974,921 42,089,017 4,606,298,874 6,068,862 7,020,639 13,089,501 39,482,488 4,280,356,610 -885,421 -2,606,528 -325,942,264
Apr-2019 281,045 7,060,147 7,121,933 14,463,125 56,552,142 4,620,761,999 6,421,380 7,130,658 13,552,038 53,034,527 4,293,908,648 -911,087 -3,517,615 -326,853,351
May-2019 276,571 6,688,523 7,153,355 14,118,448 70,670,590 4,634,880,447 6,078,972 7,145,567 13,224,539 66,259,066 4,307,133,187 -893,909 -4,411,524 -327,747,260
Jun-2019 273,564 7,038,612 7,207,441 14,519,616 85,190,206 4,649,400,063 6,431,964 7,230,350 13,662,314 79,921,380 4,320,795,501 -857,302 -5,268,827 -328,604,562
Jul-2019 285,268 6,943,044 6,857,178 14,085,489 99,275,696 4,663,485,553 6,350,514 6,865,289 13,215,803 93,137,182 4,334,011,304 -869,687 -6,138,513 -329,474,249
Aug-2019 295,386 7,083,749 7,309,562 14,688,696 113,964,392 4,678,174,249 6,465,335 7,329,957 13,795,292 106,932,474 4,347,806,595 -893,405 -7,031,918 -330,367,654
Sep-2019 168,337 4,416,659 4,301,503 8,886,498 122,850,891 4,687,060,748 4,016,295 4,323,370 8,339,665 115,272,139 4,356,146,261 -546,833 -7,578,751 -330,914,487
Oct-2019 286,923 7,608,063 7,263,244 15,158,230 138,009,121 4,702,218,978 6,995,287 7,265,740 14,261,027 129,533,166 4,370,407,288 -897,203 -8,475,954 -331,811,690
Nov-2019 285,719 7,634,270 6,925,140 14,845,128 152,854,249 4,717,064,106 7,071,791 6,910,699 13,982,489 143,515,655 4,384,389,777 -862,639 -9,338,593 -332,674,329
Dec-2019 293,743 7,842,692 7,355,029 15,491,464 168,345,713 4,732,555,570 7,245,674 7,342,655 14,588,328 158,103,984 4,398,978,105 -903,136 -10,241,729 -333,577,465
3,294,386 82,531,530 82,519,797 168,345,713 75,420,235 82,683,749 158,103,984 -10,241,729
Produced Fluids Injected Fluids (Injection - Production)
Page 3
C.Summary and Analysis of reservoir pressure surveys within the pool
The following key wells in the Endicott Pool were proposed in 2019;
2019 Key Well Program
1-09A K2A, K2B 2-64 K3C 4-42 K3C
1-17A K3A 2-70 K3B, K3C 1-11 Ivishak
2-14 K3A 3-47 K3B, K3C 2-56A Sag River - Eider
2-22 K3A, K3B, K3C 4-38 K2A, K2B
Endicott Oil Pool Datum:-10,000 ssTVD
Eider Oil Pool Datum: -9,700 ssTVD
Static bottomhole pressures collected in 2019 are summarized and submitted quarterly on the form 10-412 form
below.
Wells 1-17A and 2-56A surveys were deferred to 2020 due to limited production and/or injection support.
Minimal changes reservoir pressure in these areas are expected. The planned survey of the 2-22 well was replaced
with the 2-18 & 2-20 surveys. Similarly, the planned 2-64 survey was replaced with multiple surveys of 2-66A.
6. Oil Gravity:
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)psig
1-09A 50029217430100 GI 220100 K2A, K2B 10,052'-10,167'4/18/2019 20,702 SBHP 208.8 10,000 4,041 10,000 0.08 4,041
1-11 50029221070000 O 220150 Ivishak 10,028'-10,114'3/25/2019 77,294 SBHP 194.4 10,000 3,502 10,000 0.43 3,502
2-08 50029217710000 O 220100 K3A 9,936' - 10,052'9/17/2019 279 SBHP 201 9,999 3,760 10,000 0.43 3,760
2-14 50029216390000 O 220100 K3A, K2B 9,982'-10,139'3/31/2019 6,582 SBHP 204.3 10,002 3,992 10,000 0.41 3,991
2-18 50029220320000 O 220100 K3A, K3B 9,921' - 10,105'9/12/2019 172 SBHP 193.3 9,358 3,614 10,000 0.09 3,673
2-20 50029220480000 O 220100 K3B, K3C 9,879' - 10,137'9/23/2019 393 SBHP 204.9 10,000 1,158 10,000 0.03 1,158
2-56A 50029228630100 O 220165 Sag River 9,434' - 9,506'2/2/2019 364 SBHP 186 9,400 1,291 9,700 0.30 1,380
2-66A 50029223740100 O 220100 K3C 10,002' -10,087'5/14/2019 150 SBHP 207.5 10,000 3,788 10,000 0.42 3,788
2-66A 50029223740100 O 220100 K3C 10,002' - 10,115'12/27/2019 435 SBHP 206.6 10,000 4,076 10,000 0.43 4,076
2-70 50029218990000 WI 220100 K3B, K3C 9,988'-10,321'11/2/2019 38,074 SBHP 196 10,001 4,084 10,000 0.45 4,084
3-27 50029215860000 O 220100 K3A 9,860' - 9,971'9/13/2019 203 SBHP 220 9,977 4,101 10,000 0.43 4,111
3-47 50029215690000 WI 220100 K3B, K3C 9,939' - 10,307'4/20/2019 10,550 SBHP 199.6 10,000 4,569 10,000 0.43 4,569
4-14A 50029218630100 O 220100 K3C 10,006' - 10,137'9/23/2019 443 SBHP 215 9,999 3,984 10,000 0.43 3,984
4-26A 50029218350100 O 220100 K2B 9,866' - 9,877'9/13/2019 198 SBHP 214 9,830 4,007 10,000 0.43 4,081
4-38 50029224820000 O 220100 K1,K2A,K2B 9,932' - 10,179'6/22/2019 6,564 SBHP 213.5 9,800 3,812 10,000 0.11 3,833
4-42 50029217310000 O 220100 K3B, K3C 10,007 '- 10,284'2/1/2019 17,390 SBHP 200.2 9,542 5,708 10,000 0.45 5,914
4-46 50029219570000 O 220100 K3B, K3C 9,998' - 10,284'11/1/2019 468 SBHP 213.7 10,001 4,852 10,000 0.43 4,852
Comments:
7. Gas Gravity:
Duck Island Unit/Endicott Endicott Field/Endicott Oil Pool -10000 .88
3. Unit or Lease Name:4. Field and Pool:5. Datum Reference:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RESERVOIR PRESSURE REPORT
1. Operator:2. Address:
Hilcorp Alaska, LLC 3800 Centerpoint Dr Suite 1400, Anchorage AK 99503
Chris Kanyer
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
Printed Name
Title
Date
Reservoir Engineer
December 31, 2019
Page 4
The following key wells in the Endicott Pool will have static bottomhole pressure measurements captured in 2020;
2020 Key Well Program
1-09A K2A, K2B 2-70 K3B, K3C 4-14A K3B, K3C
1-17A K3A 3-01 K2A 4-18 K3C
1-25A K1 3-23A K2B 1-11 SDN - Ivishak
2-14 K3A, K2B 4-38 K2A, K2B 2-56A Sag River - Eider
Endicott Oil Pool & Ivishak Datum:-10,000 ssTVD
Eider Oil Pool Datum: -9,700 ssTVD
D.Summary and Analysis of Gas-Oil Contact or Gas Monitoring Surveillance Plan.
The following table summarizes the results of the logs run in 2019 for gas monitoring.
A field wide current GOC is not likely to be identified as the Kekiktuk sands have several subzones that are
vertically separated and have different permeability. In addition, faulting in the reservoir may lead to hydraulic
isolation or partial pressure communication within a sub zone. Utilizing RST log and some production
observations, the current GOC can be as deep as 10,077'ssTVD.
E.The Following Year Gas-Oil Contact or Gas Monitoring Surveillance Plan.
In 2020, we will run at least two cased hole pulsed neutron logs. Planned wells are the 1-25A and the 1-29
production wells. The logs will be used to monitor GOC and any potential remaining oil zones following additional
rig intervention/workover. Additional candidates may be identified and logged to continue GOC surveillance of
the Endicott Oil Pool.
F.Results and Analysis of Production and Injection log surveys, tracer surveys, observation well surveys
and any other special monitoring
There were two new production and injection profiles were obtained in 2019. The concentration of surveillance
work focused on the northern fault block and specifically the Kekiktuk UPSZ reservoirs.
END 2019 GOC Monitoring Program
2-16 MPI Gas Saturation Log CCL/GR/Press/Temp/Sigma 6/24/2019 GOC observed in all Kekiktuk reservoirs
above 10,780'MD (-9,874'ssTVD)Well was logged in fluid
Log Results Notes
Using the 2019 RST log results and some observations from the 2019 production, the current MPI K3B GOC is estimated at -9,874'ssTVD.
Well Location Log Type Log Description Date
END 2019 Production/Injection Logging Program
2-18 MPI Production Profile Spin/Temp/Press/Deft/GR/CCL 10/21/2017 Majority oil production (98%) and 46% gas
below 11,003'MD (-10,052'ssTVD)
Perfed intervals 10,851'-
11,065'MD
2-22 SDI Injection Profile Spin/Temp/Press/GR/CCL 6/20/2019 Majority water injection below
11,846'MD (-10,136'ssTVD)
Perfed intervals 11,452'-
12,016'MD
Well Location Log Type Log Description Date Log Results Notes
Page 5
Sampling from the previous waterflood tracer program has been discontinued. No current tracer program is in
place.
G. Future Development Plans & Review of Annual Plan of Operations and Development
In 2019, Hilcorp increased unit production through well intervention projects and other optimization
opportunities. The ongoing field study of the Duck Island Unit ongoing updates with additional well intervention
results. The re-mapping of horizons, analyzing production and injection data, and geophysical work is ongoing.
Some additional wellwork was initiated due to data provided by surveillance activities, summarized below.
Projects completed during the 2019 calendar year:
·SDI 4-42 (Prod) – Endicott Oil Pool – Kekiktuk UPSZ RWO – WINJ Conversion (May 2019);
·SDI 3-31 (Prod) – Endicott Oil Pool – Kekiktuk K2A/K2B (Non-rig) – Twin surface flowlines (May 2019);
·SDI 4-26A (Prod) – Endicott Oil Pool – Kekiktuk K2B (Non-rig) – Bradenhead Weld Repair (March 2019);
·MPI 2-12 (GINJ) – Endicott Oil Pool – Kekiktuk (Non-rig) – Surface Casing Repair (April 2019);
·MPI 1-61 (Prod) – Endicott Oil Pool – Kekiktuk (Non-rig) – Surface Casing Repair (July 2019);
·MPI 2-66A (Prod) – Endicott Oil Pool – Kekiktuk UPSZ (Non-rig) – Add Perforation in UPSZ FIII (July 2019);
·MPI 2-16 (WINJ) – Endicott Oil Pool – Kekiktuk UPSZ (Non-rig) – Recomplete well to producer (July 2019);
·MPI 2-26 (Prod) – Endicott Oil Pool – Kekiktuk UPSZ (Non-rig) – WINJ Conversion – Surface piping (November
2019);
·SDI 4-26A (Prod) – Endicott Oil Pool – Kekiktuk K2B (Non-rig) – GINJ Conversion (December 2019/January
2020);
·Continued separation train water removal improvements. Added roughly 20,000bwpd production capacity.
(May 2019)
·Main Gas Compressor A -Train Turbine Overhaul (September 2019)
In 2020, Hilcorp will pursue increased unit production through additional well intervention projects, any necessary
infrastructure and facility repairs, and other optimization opportunities as they arise. Workover activities are
tentatively planned with the ASR#1 rig at Endicott for Q3 or Q4 2020 calendar year. Coil tubing, and other rigless
interventions and planned throughout the year.
No drilling activities are planned at Endicott within the 2020 calendar year.
Projects planned for the 2020 calendar year:
·Add Perfs in existing production wells
o Add perf in bypassed pay in Endicott Oil Pool.
o Identify additional oil pay with gas saturation logging
·Perform WSO/GSO
o Identify excessive water or gas production with PPROF/RST logging
o Perform water/gas shut off using wireline/coil.
·Perform water/gas flood maintenance work
o Run several static BHP surveys or IPROF logs to identify unhealthy water flood patterns
·4-26A Conversion to GINJ - Endicott Oil Pool - Kekiktuk K2B (January 2020).
o Support active SDI 3-09A, 3-15, 3-23A, & 3-31 wells (PROD)
o K2B attic GINJ ongoing evaluation and reservoir management.
·MPI 1-29 (PROD) RWO - Endicott Oil Pool - Kekiktuk K2A
o Pull tubing, patch casing, run completion and begin production.
·MPI & SDI - possible additional RWO(s) opportunities will be evaluated, and possibly executed.
Page 6
Hilcorp will continue to progress the field study of the Duck Island Unit. This may include re-mapping potentially
productive horizons, updating well histories, reviewing all production and injection data, material balance
calculations, and reviewing results of recent well intervention projects.
Sincerely,
Chris Kanyer
Reservoir Engineer - Endicott
