The URL can be used to link to this page

Home My WebLink About2019 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, 2019 Issued: May 1st, 2020 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 2019 Development Review and 2020 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 2019 is 629 MMSTB and cumulative gas injection is 115.2 BSCF. This data shows that the voidage replacement ratio averaged 0.86 RB/RB in 2019 compared to 0.72 RB/RB in 2018. The VRR has improved due to improved injection systems at surface. 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 2019, 5 static pressure readings were obtained in the Kuparuk River reservoir. Average pressure from those readings was 2337 psi at a datum depth of 7000’ SSTVD 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 O 525140 C,B6, A3,A2,A1 7165'7209',73282'-7391'3/11/2019 LTSI SBHP 168 6969'1262 7000'0.43 1275 MP L-04 50029220290000 O 525140 C,B6, A3,A2,A1 7151'-7212'',7229- 7240',7244-7263',7274'- 7297'8/30/2019 LTSI SBHP 180 7080'3163 7000'0.43 3128 MP F-37 50029225480000 O 525140 A1 7257'-7287', 7295'-7349', 6/8/2019 2000 SBHP 164 7157 2302 7000'0.43 2234 MP F-79 50029224890100 O 525140 A2,A1 7116'-7128',7138'- 7147',7158'-7176', 7172'- 7156'8/30/2019 216 SBHP 174 6284'2529 7000'0.43 2836 MP F-86 50029230180000 O 525140 A3,A2,A1 7026'-7036',7043'- 7053',7064'-7074',7046'- 7085'8/30/2019 600 SBHP 190 6723'2095 7000'0.43 2214 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 28, 2020 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 2019 PLT Surveys Well Name Reservoir Well Type Rec Date Log Type Field Analysis Final Determination MPC-6 KUP WINJ 7/19/2019 STP/IPROF C 0%, A3 0%, A2 99% MPC-8 KUP WINJ 6/2/2019 STP/IPROF Well logged at inj rate of 800 bwpd on adjustable choke.C 4%, B6 23%, A3/A2 73% MPC-10 KUP WINJ 8/19/2019 STP/IPROF Well inj water at 1375bwpd at 2950psi and 95degF. Asnds 72%, B 28% MPC-19 KUP WINJ 8/17/2019 STP/IPROF No distinct signs of incremental fluid loss over intervals. Asnds 70%, C 30% MPC-39 KUP WINJ 6/3/2019 STP/IPROF Injection splits calculated from mean stop count values. C 5%, B6 16%, A3 4%, A2 75% MPK-18A KUP WINJ 7/24/2019 STP/IPROF Stron temperature signature below Csnd C 25%, B 75% MPL-08 KUP WINJ 7/21/2019 STP/IPROF Overlayed passes presented with in- line spinner only. C 8%, B 15%, A2/1 77% MPL-33 KUP WINJ 7/23/2019 STP/IPROF Inj 1900bwpd at 60degF. Tubing 2350psia. In-line spinner only. C 0%, Aupr 34%, A1 66% Schrader Bluff Oil Pool Waterflood Project Summary The Schrader Bluff Oil Pool cumulative voidage replacement for the calendar year 2019 was 0.9 (target 1.0) with a cumulative voidage replacement for the life of the project is 0.86. The lower the target number for the calendar year was primarily due to delayed injection into the new Moose Pad development. Delayed injection can be attributed to complications completing the water source well , M -04, that would be used for injection water. A new water source well had to be drilled and completed, M-06, and therefore delayed injection by ~ 5 months. Moose Pad cumulative voidage replacement at the end of the calendar year was 0.2, at the time of the submittal of this repor t, 5/1/20, cumulative voidage replacement is up to 0.9. 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 sho wn 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 injectio n 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. A polymer injection pilot is expected to start in the Schrader Oa sand development at F Pad in May 2020. Expansion projects are currently being evaluated based on positive performance that have seen to date. Average pressure throughout the field is 1623 psi at reference depth of 4000’ SSTVD based on 2019 surveys taken. Original pressure at reference depth was 1730 psi. 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) I-15 500292310600 SBHP 525140 Oa/Ob 3910-3975 1/24/2019 432 PIP 76 3321 1147 4000.00 0.41 1425 I-11 500292303300 SBHP 525140 Oa/Ob 3497-3612 3/27/2019 413 PIP 71 3485 1395 4000.00 0.41 1606 G-14 500292303100 SBHP 525140 Na/Nb/Ne/Oa/Ob 3929-4152 2/4/2019 28 PIP 84 3748 1118 4000.00 0.41 1221 S-24 500292314200 SBHP 525140 Nb 3854-3865 4/1/2019 67200 PIP 76 3882 1494 4000.00 0.41 1542 J-19A 500292260701 SBHP 525140 Nb 3875-3911 3/1/2019 525 Perm DH Gauge 77 3729 2083 4000.00 0.43 2200 J-19A 500292260701 SBHP 525140 Oa 4014-4047 3/1/2019 525 Perm DH Gauge 81 3871 1773 4000.00 0.43 1829 J-19A 500292260701 SBHP 525140 Ob 4079-4101 3/1/2019 525 Perm DH Gauge 82 4010 2346 4000.00 0.43 2342 I-17 500292321200 SBHP 525140 Nb/Oa/Ob 3819-3902 3/2/2019 11592 PIP 75 3890 1383 4000.00 0.41 1428 M-10 500292361700 SBHP 525140 Oa 3950-4000 8/13/2019 442 PIP 77 3797 1410 4000.00 0.41 1493 M-12 500292361900 SBHP 525140 Oa 3875-3975 8/13/2019 444 PIP 77 3799 1303 4000.00 0.41 1385 M-14 500292362500 SBHP 525140 Oa 3825-3925 8/13/2019 444 PIP 76 3720 1430 4000.00 0.41 1545 M-16 500292363100 SBHP 525140 Oa 3750-3825 8/13/2019 444 PIP 73 3520 1375 4000.00 0.41 1572 M-18 500292363200 SBHP 525140 Oa 3650-3725 8/13/2019 444 PIP 69 3348 1230 4000.00 0.41 1497 M-20 500292363600 SBHP 525140 Oa 3550-3750 8/13/2019 444 PIP 75 3718 1530 4000.00 0.41 1646 J-25 500292320700 SBHP 525140 Nb 3802-3817 10/22/2019 2520 PIP 76 3518 1128 4000.00 0.41 1326 J-09A 500292249501 SBHP 525140 Oa 3979-3984 8/29/2019 574 PIP 74 3635 1650 4000.00 0.41 1800 J-19 500292260701 SBHP 525140 Ob 4079-4101 10/15/2019 1054 Perm DH Gauge 81 4010 2298 4000.00 0.43 2294 J-19 500292260701 SBHP 525140 Nb 3875-3911 10/15/2019 1054 Perm DH Gauge 81 3729 1924 4000.00 0.43 2041 J-26 500292320500 SBHP 525140 Nb/Oa/Ob 3749-3967 10/13/2019 2482 PIP 75 3789 1354 4000.00 0.41 1441 I-14 500292321400 SBHP 525140 Nb/Oa/Ob 3718-3905 8/1/2019 135 PIP 80 3592 942 4000.00 0.41 1109 I-03 500292206700 SBHP 525140 Na/Nb/Nc/Ne/Oa/Ob 4260-4510 10/23/2019 98 PIP 87 3464 1073 4000.00 0.41 1293 I-04A 500292206801 SBHP 525140 Na/Nb/Nc/Ne/Oa/Ob 3791-4037 12/31/2019 11741 PIP 77 3666 1543 4000.00 0.41 1680 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: Hilcorp Alaska LLC 3800 Center Point Dr, Anchorage , AK 99503 Milne Point - Schrader Bluff Printed Name Title Date Reservoir Engineer April 30, 2020 4000 0.56 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. Signature 7. Gas Gravity: Milne Point Schrader Bluff PLT Logs and Analysis Well Name Reservoir Well Type Rec Date Log Type Field Analysis Final Determination G-01 Schrader Bluff Inj 9/7/2019 IPROF 60-70% fluid entering top of screens at 4151'MD, remaining leaving tubing tail into Oa sand and not injection into Oba N sands - 65% , Oa sand 35%, Oba sand 0% G-11 Schrader Bluff Inj 9/7/2019 IPROF no fluid movement below mid Oa sand at 7052' MD Oa sand - 100% , Oba sand 0% S-15 Schrader Bluff Inj 8/20/2019 IPROF 100% injection into Oa sand Oa sand - 100%, Oba sand 0 % Sag River Oil Pool Waterflood Project Summary A Participating Area for the Sag was approved in 2005. During 2019, 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 (MP F-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. MPK-33 was cycled between Kuparuk and Sag production throughout 2019, and both new Sag wells, MPC -46 and MPB-30 were completed with fracture stimulation treatments. The Sag River Pool oil production averaged 422 STBD and water production averaged 1220 STBD in 2019. Cumulative production through the end of 2019 is 3.7 MMSTB of oil, 4.9 BSCF of gas, and 3.8 MMSTB of water. The decreases in production in 2019 was due to natural decline and no addition wells drilled in 2019. During 2019 three pressure surveys were obtained indicating an average reservoir pressure of 2596 psi at a datum depth of 8750’ SSTVD 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 504 DH Press Gauge 225 8507 3553 8750 0.39 3647 MP B-30 50029235710000 PROD 525150 Sag A, B 8,926’-8,965’9/8/2019 170 DH Press Gauge 231 8728 2220 8750 0.37 2228 MP C-46 50029235760000 PROD 525150 Sag A, B 8,728’-8,753’8/30/2019 696 DH Press Gauge 223 8493 1813 8750 0.39 1913 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 Sag River Oil Pool Printed Name Title Date Reservoir Enginner March 28, 2020 8750' SS 0.65 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 MPU Pool Allocation Factors Total Milne Point production increased a total of 1.7 MMBO from 2018 to 2019 primarily due to significant development 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 3771732 6960749 873139 5858846 6373317 2172475 2087114 -587432 1299336 Kuparuk 3609623 21874097 3831361 3287182 20771207 3920084 -322441 -1102890 88723 Sag River 225100 453091 337914 153654 445501 310794 -71446 -7590 -27120 Total 7606455 29287937 5042414 9299682 27590025 6403353 1693227 -1697912 1360939 Allocation Pool Oil Water Gas Oil Water Gas Oil Water Gas frac frac frac frac frac frac frac frac frac Schrader Bluff 0.50 0.24 0.17 0.63 0.23 0.34 0.13 -0.01 0.17 Kuparuk 0.47 0.75 0.76 0.35 0.75 0.61 -0.12 0.01 -0.15 Sag River 0.03 0.02 0.07 0.02 0.02 0.05 -0.01 0.00 -0.02 20192018 2018 2019 2019 - 2018 Delta 2019 - 2018 Delta I. FIELD OVERVIEW The MPU consists of the Kuparuk Reservoir in the Kuparuk Participating Area, the Schrader Bluff Reservoir in the Schrader Bluff Participating Area, the Sag River Reservoir in the Sag River Participating Area, C-23 Tract Operations, K-33 Tract Operations, and the Ugnu S-37, S-39, S-41, S-43, and S-203 Tract Operations. II. 2019 Development A. Drilling Program Hilcorp Alaska drilled 26 new wells 2019:  M-10 through M-22 single laterals in the Schrader Oa - (7 producers / 6 injectors)  E-36 /37/38 single laterals in the Schrader Oa – (2 inj / 1 prod)  E-40 / 41 single laterals in Schrader Nb – (1 prod / 1 inj)  E-39 / 42 dual laterals in Schrader Oa and Ob (1 prod / 1 inj)  S-203 – Ugnu Mb sand producing well  K-44 – Kuparuk C sand producing well  F-116 – Kuparuk A sand producing well  M-04 – Water source well  M-06 – Water source well B. Workover Program Hilcorp completed the following well projects:  F-107 – Schrader Bluff Oa sand producing well – ESP change out  F-93 - Kuparuk producing well – ESP change out  E-32 – Schrader Bluff producing well – ESP change out  E-35 – Schrader Bluff Oa sand producing well – ESP change out  L-46 - Schrader Bluff Oa sand producing well – ESP change out  K-44 – Kuparuk producing well – ESP change out  L-29 – Kuparuk producing well – ESP change out  I-17 – Schrader Bluff producing well – ESP change out  L-05 – Kuparuk convert to injector  L-41 – Kuparuk producing well – ESP change out  J-26 – Schrader Bluff producing well – convert to jet pump  J-25 – Schrader Bluff producing well – convert to jet pump  I-06 – Schrader Bluff producing well – ESP change out  F-45 – Kuparuk producing well – ESP change out  F-37 – Kuparuk producing well – ESP change out  F-66A – Kuparuk producing well – ESP change out  K-17 - Kuparuk producing well – ESP change out  M-22 - Schrader Bluff producing well – convert to jet pump  C-14 - Kuparuk producing well – ESP change out  E-04 - Kuparuk producing well – ESP change out  G-16 – Schrader Bluff producing well – convert to jet pump  H-16 – Schrader Bluff producing well – convert to jet pump  E-10 – Kuparuk producing well – ESP change out C. Major Facility Projects Key activities included:  Completed construction of Moose Pad Facility;  Completed installation of power module at L Pad for Moose Pad Power III. 2020 PLAN OF DEVELOPMENT AND OPERATIONS A. Proposed Drilling Program  M-23 through M-26 Schrader Oa wells ( 2 prod / 2 inj)  I-35/36 – Schrader Nb (1 prod / 1 inj)  I-20/21 – Schrader Oa (1 prod / 1 inj)  I-27/28 – Schrader Oba (1 prod / 1 inj)  S-56/57 – Schrader Ne (1 prod / 1 inj)  M-43/44/45 – Schrader Nb (2 prod / 1 inj)  L-59/60/61/62 – Schrader Nb (2 prod / 2 inj)  F-69 – Kuparuk A sand producer B. Proposed Workover Program During the 2020 calendar year, Hilcorp anticipates completing up to 16 well workovers with the ASR1 rig. C. Major Facility Projects Key facility projects anticipated to be undertaken during 2019 include:  Installation of Schrader Oa Polymer Injection Plant at F Pad  Installation of new electrical module and well testing module at I Pad for planned Schrader development wells