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Home My WebLink About185-093CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPB-13 (PTD #1850930) - Failed MIT-IA Date:Monday, September 11, 2023 8:25:18 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 8, 2023 11:26 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPB-13 (PTD #1850930) - Failed MIT-IA Mr. Wallace, MPB-13 (PTD# 1850930) failed an offline non-witnessed MIT-IA to 2700 psi on 9/7/23. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored and AOGCC approval is obtained per AIO 10B.014. Please respond with any questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Friday, September 1, 2023 11:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: UNDER EVALUATION: MPB-13 (PTD #1850930) - IA Broke MOASP Mr. Wallace – On 8/31/23 PWI Injector MPB-13 (PTD #1850930) broke MOASP with an IA pressure of 2034 psi while on injection with an injection pressure of 2220 psi. This well is operated under AIO 10B.014 for PWI only due to IA repressurization approved 8/19/2020. This well has IA/OA trips installed set at 1900/900 psi. The IA tripped the SSV after climbing to 1900 psi and stacked out to 2033 psi. An MIT-IA is planned for today to evaluate barriers. The well will remain shut in until further communication with AOGCC based on MIT-IA results and further diagnostics. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: MPB-13 (PTD #1850930) - IA Broke MOASP Date:Tuesday, September 5, 2023 8:33:16 AM Attachments:MPU B-13 SCHEMATIC 07-26-2020.pdf MPB-13 TIO.docx From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, September 1, 2023 11:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: UNDER EVALUATION: MPB-13 (PTD #1850930) - IA Broke MOASP Mr. Wallace – On 8/31/23 PWI Injector MPB-13 (PTD #1850930) broke MOASP with an IA pressure of 2034 psi while on injection with an injection pressure of 2220 psi. This well is operated under AIO 10B.014 for PWI only due to IA repressurization approved 8/19/2020. This well has IA/OA trips installed set at 1900/900 psi. The IA tripped the SSV after climbing to 1900 psi and stacked out to 2033 psi. An MIT-IA is planned for today to evaluate barriers. The well will remain shut in until further communication with AOGCC based on MIT-IA results and further diagnostics. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility _____________________________________________________________________________________ Revised By: STP 1/08/2020 SCHEMATIC Milne Point Unit Well: MPU B-13 Last Completed: 5/30/1985 PTD: 185-093 TD =10,727 (MD) /TD =7,382’(TVD) 13-3/8” Orig.DF Elev.: 59.0’/ GL Elev.: 24.0’ (Nabors 27E) RKB to Tbg Hanger = 32.5’ (Nabors 27E) 7” 15 13 9-5/8” 1 PBTD =10,352’(MD) / PBTD =7,146’(TVD) 12 KUP C1 2 3 4 5 6 7 8 9 10 14 16 Arctic Pack Est TOC 8,912’ MD EST TOC 2,000’ 11 Csg RA Tag 9,985’ MD 12.99’ Long Tbg RA Tag 10,057’ MD EL Tag 10,286.7’ MD 12/15/19 ECP 10,273’ MD ECP 10,332’ MD KUP B7 i JEWELRY DETAIL No Depth Item 1 1,898’ 3.5” Camco TRDP-1A SSA SCSSV,ID= 2.812” 2 2,166’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#10 Dummy Valve (9/15/12) 3 2,996’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#9 Dummy Valve (9/15/12) 4 3,910’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#8 Dummy Valve (9/15/12) 5 4,942’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#7 Dummy Valve (9/16/12) 6 5,798’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#6 Dummy Valve (9/16/12) 7 6,682’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#5 Dummy Valve (9/16/12) 8 7,562’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#4 Dummy Valve (9/16/12) 9 8,442’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#3 Dummy Valve (9/16/12) 10 9,292’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#2 Dummy Valve (9/16/12) 11 10,048’3.5”KBUG GLM w/ 1” valve, BK-2 latch, ID= 2.813”STA#1 Dummy Valve (9/16/12) 12 10,086’3.5’ Baker SBR Seal Assembly, ID = 3.000” 13 10,104’7” x 3.5” Brown HB Hydraulic Packer, ID = 2.890” 14 10,140’ 3.5” Camco D Nipple,Min ID = 2.750” ****CA-2 Plug set 7-26-20**** 15 10,154’ Pressure Tbg Release -Bottom @ 10,156’ 16 10,275’Fish –Spent 5”TCP Guns (65.42’ Long); Tag on 12/03/2019 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status KUP C1 10,184’10,214’7,039’7,059’30 6/01/1985 Open KUP B7 10,243’10,273’7,077’7,096’30 12/15/2019 Open Kuparuk C1 –TCP Guns: 5” 12 spf 22 gram shoot & drop Kuparuk B7 – 2-3/8” 6 spf 11 gram GeoDynamics HMX Razor WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 56.5 deg. @ 7,700’ TREE & WELLHEAD Tree 3-1/8” 5M FMC w/ Otis Quick Union Wellhead Tbg Adapter 11” x 3-1/8” 5M FMC Tbg Hgr. 11” x 3-1/2” IBT FMC 3” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-21348-00-00 Drilled, Cased and Completed by Nabors 27E -5/30/1985 Perf Add on 12/15/2019 OPEN HOLE / CEMENT DETAIL 13-3/8"Cemented to Surface in 17-1/2” Hole 9-5/8"829 bbl Arctic Set III, 57 bbl Class G & 14 bbl Arctic Set I in 14-7/8” Hole 7”58 bbl Class G CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8"Conductor 48 / H-40 / PE 12.559 Surface 105’ 9-5/8"Surface 36 / K-55 / BTC 8.921 Surface 6,127’ 7"Production 26 / L-80 / BTC 6.276 Surface 10,461’ TUBING DETAIL 3-1/2"Tubing 9.2/ L-80 /IBT 2.992 Surface 10,156’ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC B-13 MILNE PT UNIT B-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 B-13 50-029-21348-00-00 185-093-0 W SPT 6988 1850930 2700 2259 2267 2293 2317 315 325 327 328 REQVAR P Brian Bixby 8/13/2022 2 Year MITIA as per AIO 10B.014 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT B-13 Inspection Date: Tubing OA Packer Depth 467 3022 2960 2955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220815141450 BBL Pumped:3 BBL Returned:3 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 2 Year MITIA as per AIO 10B.014 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 14:38:58 -08'00' David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/14/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Date Log Type MPU B-13 500292134800 185-093 6/25/21 IPROF MPU E-12 500292326200 205-067 6/21/21 IPROF MPU J-27 500292355700 215-153 6/4/21 Multi Finger Caliper MPU K-06 500292272500 196-191 3/14/21 Leak Detect Log MPU L-29 500292254300 195-009 6/23/21 Multi Finger Caliper Please include current contact information if different from above. Received By: 07/14/2021 37' (6HW By Abby Bell at 2:44 pm, Jul 14, 2021 Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, June 30, 2020 12:01 PM To: Wallace, Chris D (CED) Cc: Alaska NS - Milne - Foreman; Bradley Livingston; David Haakinson; Darci Horner - (C); Chad Helgeson Subject: RE: Water Injector MPB-13 (PTD#1850930) Shut-in for IA Pressurization Attachments: B-13 TIO.XLSX All, Milne point water injector MPB-13 (PTD#1850930)) was shut-in today for IA pressurization. The well had been under 28 day monitoring following indications of a possible intermittent or slow leak to the IA. During recent monitoring, the well's injection rate and pressure remained relatively stable during the period of 6/17/20-6/29/20 while the IA increased at an average BUR of -30 psi/day. A TIO plot is attached for reference. The well will remain shut in until integrity can be restored. Path Forward — Operations 1) Perform Tubing Hanger Packoff test to 5000 psi. 2) Set TTP in the D Nipple at 10,140' 3) MIT -T to 2000 psi. 4) If passing MIT -T, leave tubing pressured up for -5 days before bleeding back. Monitor daily T/IA/OA pressures for any indication of slow TxIA communication while shut-in. 5) If no indication of communication, MIT -IA to 2000 psi. 6) If passing MIT -IA, leave IA pressure up for —5 days before bleeding back. Monitor daily T/IA/OA pressures for indication of slow IAxPacker leak while shut-in. Thank You, Wyatt Rivard I Operations Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard(@hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Friday, June 5, 2020 7:42 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Alaska NS - Milne - Foreman <AlaskaNS-Milne-Foreman@hilcorp.com>; Bradley Livingston <blivingston@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: RE: Water Injector MPB-13 (PTD#1850930) Additional Monitoring Chris, Milne Point water injector MPB-13 (PTD#1850930) has remained on injection for 2 weeks for monitoring following an IA bleed on 5/20/20. There have been no additional IA bleeds and IA pressure has remained stable or even decreased during the period (TIO plot attached). Injection pressure has remained flat but injection rate has been down with respect to pre -bleed rates. Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, June 5, 2020 9:28 PM To: Wallace, Chris D (CED) Subject: Re: [EXTERNAL] RE: Water Injector MPB-13 (PTD#1850930) Additional Monitoring Chris, Thank you for the approval. I had meant to followup with a phone call but the day got away from me. Thank You, Wyatt Get Outlook for Android From: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Sent: Friday, June 5, 2020 9:19:16 PM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Alaska NS - Milne - Foreman <AlaskaNS-Milne-Foreman@hilcorp.com>; Bradley Livingston <blivingston@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: [EXTERNAL] RE: Water Injector MPB-13 (PTD#1850930) Additional Monitoring Wyatt, I thought I replied this morning - but cannot see a sent - so maybe I just agreed to your extended monitoring plan and moved on. Any questions let me know. Thanks, Chris -------- Original message -------- From: Wyatt Rivard <wrivard@hilcorp.com> Date: 06/05/2020 7:43 AM (GMT -09:00) To: "Wallace, Chris D (CED)" <chris.wallace@alaska.gov> Cc: Alaska NS - Milne - Foreman <Alaska NS -Milne -Foreman @ hilcorp.com>, Bradley Livingston <blivingston@hilcorp.com>, David Gorm <dgorm@hilcorp.com>, David Haakinson <dhaakinson@hilcorp.com>, "Darci Horner - (C)" <dhorner@hilcorp.com> Subject: RE: Water Injector MPB-13 (PTD#1850930) Additional Monitoring Chris, Milne Point water injector MPB-13 (PTD#1850930) has remained on injection for 2 weeks for monitoring following an IA bleed on 5/20/20. There have been no additional IA bleeds and IA pressure has remained stable or even decreased during the period (TIO plot attached). Injection pressure has remained flat but injection rate has been down with respect to pre -bleed rates. Going forward, Hilcorp would like to leave MPB-13 on injection for an additional 28 day monitoring period to observe the IA following further changes in injection rate & pressure. Monitoring results will be provided at 28 days with the well shut-in at any indication of TxIA communication. Thank You, Wyatt Rivard I Operations Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard0hilcoro com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Thursday, May 21, 2020 2:14 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Alaska NS - Milne - Foreman <AlaskaNS-Milne-Foreman@hilcorp.com>; Bradley Livingston <blivingston@hilcorp.com>; David Gorm <dgorm@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Stan Porhola <sporhola@hilcorp.com> Subject: Water Injector MPB-13 (PTD#1850930) Annular Bleed and Continued Monitoring Hello Chris, As discussed, Milne Point water injector MPB-13 (PTD#1850930) had an IA bleed late last night, 5/20/20 from 1980 psi to 700 psi, all diesel. The well has a history of signs of possible IA pressurization that were ultimately attributed to thermal effects. The well consistently passes MIT-IAs, most recently in 9/23/2018. In June 2017 the well was SI with a plug set in the tubing. A 2000 psi MIT -T was obtained and pressure was left against the plug for 5 days to rule out a small or one-way TxIA communication(information attached). MPB-13's tubing injection pressure has continued to rise gradually over the past few years of injection and the recent bleed occurred during higher than normal injection temps. Hilcorp believes IA pressure is likely the result of these increases and not due to an integrity issue. We would like to leave MPB-13 on water injection for 14 days for continued observation of the IA under stable injection with results to be provided to AOGCC. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JM4 10 Lino REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li para ions shu down Li Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redhill ❑ erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic❑ Exploratory ❑ Service Q 185-093 3. Address: 3800 Centerpoint Or, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21348-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047438 MILNE PT UNIT B-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10,727 feet Plugs measured N/A feet true vertical 7,382 feet Junk measured 10,288 feet Effective Depth measured 10,352 feet Packer measured 10,140 feet true vertical 7,146 feet true vertical 7,011 feet Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' N/A N/A Surface 6,127' 9-5/8" 6,127' 4,674' 3,520psi 2,020psi Production 10,461' 7" 10,461' 7,215' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2 / L-80 / IBT 10,156' 7,022' 1,898 MD Packers and SSSV (type, measured and true vertical depth) 7"x x3.5" HD Hyd CAMCO TRDP-1A SCSSV See Above 1,862 TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:1 0 0 0 200 1 927 Subsequent to operation: 10 0 1,772 1,300 1 1,598 14. Attachments (required per 20 A4c 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 21 Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-529 Authorized Name: Chad HelgesonS Contact Name: Stan Porthole Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.com Authorized Signature: Datc 1/9/2020 Contact Phone: 777-8412 y /.Iyz0 Form 10-404 Revised 4/2017 RBDMS ��JAN 1 3 2020 /,<5Xvvs, Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 8-13 Wireline 50-029-21348-00-00 185-093 12/14/2019 12/15/2019 12/11/2019- Wednesday No operations to report. 12/12/2019 -Thursday No operations to report. 12/13/2019 - Friday - No operations to report. 12/14/2019 -Saturday RU E -line. Test lubricator to 250/3,000 psi (passed). MU 10'x2-3/8" 6 spf GeoDynamics HMX Razor pert gun. RIH and GR/CCL shorted out at 2,800'. POOH. Troubleshoot. Shutdown for the night. 12/15/2019 -Sunday RU E -line. Test lubricator to 250/3,000 psi (passed). MU 10'x2-3/8" 6 spf GeoDynamics HMX Razor perf gun. RIH and tag TCP fish at 10,286.7' MD. Log correlation pass. Place guns on depth of 10,263'-10,273'. Fire guns. 100 psi increase. POOH. All shots fired. MU 20'x2-3/8" 6 spf GeoDynamics HMX Razor perf gun. RIH and tag TCP fish at 10,286.7' MD. Log correlation pass. Place guns on depth of 10,243'-10,263'. Fire guns. 100 psi increase. POOH. All shots fired. Rig down E -line. Turn well over to production operators. 12/16/2019 - Monday No operations to report. 12/17/2019 -Tuesday No operations to report. Milne Point Unit Well: MPU B-13 SCHEMATIC Last Completed: 5/30/1985 cora Alaska, LLC PTD: 185-093 TREE & WELLHEAD Odg.DF Bev.: 59.0'/ GL hev.: 24.0' (Nabors 27E) RKB to Tog Hanger = 32.5' (Nabors 27E) 133/8" 9-5/8' Arctic Pack I 2 EStTOC 2,000 3 4 s 6 7 8 9 Est TDC 8,917 MD I. 10NRATag 9,985' MD 11 12.99' Long Thg RATag 10,057 MD 13 i 14 15 KUP Cl KUP W ECP 10,273' MD ELTag 10,286.7 MD 12/15/19 16 ECP 10,337 MD M. + 7 ,1 TD =10,727 (MD) / TD= 7,382(TVD) PB1D=10,357 (MD) / PBTD = 7,146(ND) Tree 3-1/8" 5M FMC w/ Otis Quick Union Wt/Grade/Conn Tbg Adapter 11" x 3-1/8" 5M FMC Wellhead Tbg Hgr. 11"x 3-1/2" IBT FML 13-3/8" 3" CIW-H BPV Profile OPEN HOLE / CEMENT DETAIL 13-3/8" Cemented to Surface in 17-1/2" Hole 9-5/8" 829 bbl Arctic Set III, 57 bbl Class G & 14 bbl Arctic Set I in 14-7/8" Hole 7" 58 bbl Class G CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 48/H-40/PE 12.559 Surface 105' 9-5/8" Surface 36/K-55/BTC 8.921 Surtace 6,127' 7" Production 26/L-80/BTC 6.276 Surface 10,461' TUBING DETAIL 3-1/2" Tubing 9.2/ L-80/IBT 2.992 Surtace 10,156' WELL INCLINATION DETAIL KOP @ 500' Max Hale Angle= 56.5 deg. @ 7,700' JEWELRY DETAIL No Depth Item 1 1,898' 3.5" Camco TRDP-1A SSA SCSSV, ID= 2.812" 2 2,166' 3.5"KBUG GLM w/ 1"valve, BK -2 latch, ID= 2.813" STA#10 Dummy Valve (9/15/12) 3 2,996' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#9 Dummy Valve (9/15/12) 4 3,910' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#8 Dummy Valve (9/15/12) 5 4,942' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STAW Dummy Valve (9/16/12) 6 5,798' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#6 Dummy Valve (9/16/12) 7 6,682' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#5 Dummy Valve (9/16/12) 8 7,562' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#4 Dummy Valve (9/16/12) 9 8,442' 3.5"KBUG GLM w/1"valve, BK -2 latch, W= 2.813" STA#3 Dummy Valve (9116/12) 30 9,292' 1 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#2 Dummy Valve (9/16/12) 11 10,048' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#1 Dummy Valve (9/16/12) 12 10,086' 3.5' Baker SBR Seal Assembly, ID=3.000" 13 10,104' 7" x 3.5" Brown HB Hydraulic Packer, ID = 2.890" 14 10,140' 3.5" Camco D Nipple, Min ID = 2.750" 15 10,154' Pressure Tbg Release - Bottom @ 10,156' 16 10,275' Fish —Spent 5" TCP Guns (65.42' Long); Tag on 12/03/2019 PERFORATION DETAIL Sands J Top (MD) Btm (MD)Top (ND) Btm (TVD) FT Date Status KUP Cl 10,184' 10,214' 1 7,039' 1 7,059' 1 30 1 6/01/1985 1 Open KUP B7 10,243' 10,273' 1 7,077' 1 7,096' 1 30 1 12/15/2019 1 Open Kuparuk CS — TCP Guns: 5" 12 spf 22 gram shoot & drop Kuparuk B7-2-3/8" 6 spf 11 gram Geo Dynamics HMX Razor GENERAL WELL INFO API: 50-029-21348-00-00 Drilled, Cased and Completed by Nabors 27E - 5/30/1985 Perf Add on 12/15/2019 Revised By: STP 1/08/2020 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU B-13 Permit to Drill Number: 185-093 Sundry Number: 319-529 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaskc.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, VJe DATED this 11 day of November, 2019. �BDMS4160 NOV 2 5 2019 RECEIVE® NOV 2 0 2019 A®GCC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑� 185-093 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21348-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No ❑� MILNE PT UNIT B-13 9. Property Designation (Lease Number): f 10. Field/Pool(s): ADL0047438 MILNE POINT/ KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,727' 7,382 10,352' 7,146' 2,700 NIA 10,288' Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' N/A N/A Surface 6,127' 9-5/8" 6,127' 4,674' 3,520psi 2,020psi Production 10,461' 7" 10,461' 7,215' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2 / L-80 / IBT 10,156' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7"x x3.5" Brown HD Hyd Packer and CAMCO TRDP-1A SCSSV 10,140 MD / 7,011 TVD and 1,898 MD 11,862 TVD 12. Attachments: Proposal Summary J Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations12/3/2019 : ❑ WINJ ❑� WDSPL ❑ OIL Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Stan Porhola S7P Authorized Title: Operations Manager Contact Email: S orh01a(cDh11Cor .Com Contact Phone: 777-8412 Authorized Signature: Date: 11/19/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IBDMS-Wb) NOV 2 5 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No [!T" Subsequent Form Required: 1 Q '— Ll ®r`� r APPROVED BY 1 Approved by: 1 COMMISSIONER 1, THE COMMISSION Date: u U /ter-� u � 1 U /�{ Submit Form and F m 10-403 Revised 4/2017 Approved applica n I r 2A� A f the date of approval. l�ttachments in Duplicate �//his/.. 44' 9 R 111201 Lot U Hilcora Alaska, LLI Well Prognosis Well: MPU B-13 Date: 11/19/2019 Well Name: MPU B-13 API Number: 50-029-21348-00 Current Status: Injection Well [Active] Pad: B -Pad Estimated Start Date: December 3rd, 2019 Rig: Wireline Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-093 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: Add Perforations Current Bottom Hole Pressure: 3,349 psi @ 7,000' TVD (SBHPS 06/20/2017 / 9.20 ppg EMW) Maximum Expected BHP: 3,400 psi @ 7,000' TVD (New perfs in Kuparuk B7 / 9.34 ppg EMW) MPSP: 2,700 psi (0.1 psilft gas gradient) Brief Well Summary: MPU B-13 was drilled and completed in May 1985 as a gaslifted Kuparuk producer in the C1 sand. Due to low productivity, a mud acid job was pumped but the result was large volumes of water suspected from the 137 sand just below the C1. The well was left shut-in on January 1986. The well was converted to a water injection well in September 2014 and has been on injection ever since, injecting in the Kuparuk C1. Notes Regarding Wellbore Condition • 7" casing tested to 2,400 psi for 30 minutes 09/23/2018. • Tie-in log: Openhole DIL log dated 5/29/1985. Obiective: The purpose of this work is to add perforations in the Kuparuk B7 sand for injection. This will support offset production in well MPU E-04 (PTD 190-005) in hydraulic unit 313. Brief Procedure: (� Eline Procedure: 1. RU E -line. Test lubricator to 250/3,000 psi. 16 I ;x`13 2. MU 20' of 2-3/8" perf guns. 3. RIH and perforate the Kuparuk B7 from +/-10,268'— 10,288' MD. POOH. 4. MU 20' of 2-3/8" perf guns. 5. RIH and perforate the Kuparuk B7 from +/- 10,248'— 10,268' MD. POOH. 6. MU 5' of 2-3/8" perf guns. 7. RIH and perforate the Kuparuk B7 from +/- 10,243'— 10,248' MD. POOH. 8. RD E -line. Attachments: 1. As -built Schematic 2. Proposed Schematic n Itilcoru Alaska, LLP. 0r[&DF Elco.: 59.0'/ GL hev.: 35.0' (Nabors 27E) RKB Elev= 32.5' (Nabors 27E) 13-3/8" Arctic Pack 1 FST TOC 2,000' aJ! 9-5/8' Est TOC 8,912'MD Csg RATag ® 9985 ND i$rt 12.99'lnng i 14 10,057 SLTag 10,276'SLM 10/06/19 3f 16 TD =10,727 (MD) /To = 7,382'MM) PBTD=10,352 (ND) / PBTD= 7,146'(IVD) SCHEMATIC Milne Point Unit Well: MPU B-13 Last Completed: 5/30/1985 PTD: 185-093 TREE & WELLHEAD Tree 3-1/8" SM fMC w/ Otis Quick on 9-5/8" Tbg Adapter 11" x 3-1/8" SM FMC Wellhead. Tbg Hgr.11" x3-1/2" 11 FMC 7" 3" CIW-H BPV Profile OPEN HOLE / CEMENT DETAIL 13-3/8" Cemented to! in 17-1/2" Hole 9-5/8" 829 bbl Arctic Set III, 57 bbl Class G & 14 Top bbl Arctic Set I in 14-7/8" Hole 7" 1 58 bbl Class G CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 48/H-40/PE .559 Surface 105' 9-5/8" Surface 36 / K-55 / BTC .921 j Surface 6,127' 7" Production 26/L-80/BTC .276 Surface 10,461' TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.992 Surface 10,156' WELL INCLINATION DETAI L KOP @ 500' Max Hole Angle = 56.5 deg. @ 7,700' JEWELRY DETAIL No Depth Item Top IN Btm (ND) 1 1,898' 3.5"Camco TRDP-3A SSA SCSSV, ID=2.812" 1 10,184' 2 2,166' 3.5"KBUG GLM w/ 1" valve, 3K-2 latch, ID= 2.813" STA#SO Dummy Valve (9/15/12) 3 2,996' 3.5"KBUG GLM w/1"valve, BK -2 latch, ID= 2.813"STA#9 Dummy Valve (9/15/12) 4 3,910' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#8 Dummy Valve (9/15/12) 5 4,942' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#7 Dummy Valve (9/16/12) 6 5,798' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID=2.813" STA#6 Dummy Valve (9/16/12) 7 6,682' 3.5"KBUG GLM w/ 1" valve, BK-2latch, ID= 2.813" STA#5 Dummy Valve (9/16/12) 8 7,562' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#4 Dummy Valve (9/16/12) 9 8,442' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID=2.813" STA#3 Dummy Valve (9/16/12) 10 .5"KBUG GLM w/1"valve, BK-2latch, ID=2.813" STA#2 Dummy Valve (9/I6/12) 11 5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#1 Dummy Valve (9/16/12) 12 .5'Baker SBR Seal Assembly, ID =3.000" 13 V7"X "x3.5" Brown HB Hydulic PkeID=2890"14 .5" Camco D Nipple, Min ID=2.750" 15 ressure Tbg Release- Bottom @ 10,156' 16 sh—Spent 5"TCP Guns PERFORATION DETAIL Sands. Top (MD) Btm (MD) Top IN Btm (ND) FT Date Status KUP Cl 1 10,184' 10,214' 1 7,039' 7,059' 30 6/01/1985 Open TCP Guns: 5" 12 spf 22 gram shoot & drop GENERAL WELL INFO API: 50-029-21348-00-00 Drilled, Cased and Completed by Nabors 27E - 5/30/1985 Revised By: TDF 11/5/2019 Milne Point Unit Well: MPU B-13 PROPOSED Last Completed: 5/30/1985 Ililoora Alaska, LLC PTD: 185-093 TREE & WELLHEAD Orig.DF Elw..: 59.0'/ GL bev.: 35.0' (Nabors 27E) RKB Dev= 32.5' (Nabors 27E) Arctic Pack FSTTOC Zow 9-5/8" j I i Est TOC 8,917 MD u Gsg RATag 9,985' WD 12.99' Long 1 Tbg RATag 14057' 15 n KUP C1 KUP B7 SLTag 10,276 SLM 10/06/19 TD =10,727 (MID) / TD= 7,382'(ND) PBTD=10,357 (MD) / PBTD= 7,146'(fVD) Tree 3-1/8"SM FMC w/Otis Quick Union Otis 9SM UnC 9-5/8" Tbg Adapter 11"x Wellhead Tbg Hgr.11"x3-1/2"IBTFMC ] 7" 3" CW -H BPV Profile OPEN HOLE / CEMENT DETAIL 13-3/8" Cemented to Surface in 17-1/2" Hole 9-5/8" 829 bbl Arctic Set III, 57 bbl Class G & 14 Top bbl Arctic Set I in 14-7/8" Hole 7" 58 bbl Class G CASING DFTAII Size Type Wt/ Grade/ Conn ID Top B 13-3/8" Conductor 48/H-40/PE 12.559 Surface 105' 9-5/8" Surface 36/K-55/BTC 8.921 Surface 6,127' 7" Production 26/L-80/BTC 6.276 Surface 10,461' TUBING DETAIL 3-1/2" Tubing 9.2/ L-80 / IBT 2.992 Surface 10,156' WELL INCLINATION DETAIL KOP @ 500' Max H ole Angie = 56.5 deg. @ 7,700' JEWFL RY DFTAII No Depth Item Top (ND) 1 1,898' 3.5"Camco TRDP-3A SSA SCSSV, ID=2.812" 10,214' 2 2,166' 3.5"KBUG GLM w/ 1" valve, BK-2latch, ID= 2.813" STA#10 Dummy Valve (9/15/12) 3 2,996' 3.5"KBUG GLM w/1"valve, BK -2 latch, ID= 2.813"STA#9 Dummy Valve(9/15/12) 4 3,910' 3.5"KBUG GLM w/ 1" valve, BK-2latch, ID= 2.813" STA#8 Dummy Valve (9/15/12) 5 4,942' 3.5"KBUG It w/ 1" valve, 11-2latch, ID= 2.813" STA#7 Dummy Valve (9/16/12) 6 5,798' 3.5"KBUG GLM w/ 1" valve, BK-2latch, ID=2.813" STA#6 Dummy Valve (9/16/12) 7 6,682' 3.5"KBUG GLM w/ 1" valve, BK-2latch, ID= 2.813" STA#5 Dummy Valve (9/16/12) 8 7,562' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#4 Dummy Valve (9/16/12) 9 8,442' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID=2.813" STA#3 Dummy Valve (9/16/12) 10 9,292' 3.5"KBUG GLM w' 1" valve, BK-2latch, ID= 2.813" STA#2 Dummy Valve (9/16/12) 11 10,048' 3.5"KBUG GLM w/ 1" valve, BK -2 latch, ID= 2.813" STA#1 Dummy Valve (9/16/12) 12 10,086' 3.5' Baker SBR Seal Assembly, ID =3.000" 13 10,104' 7" x3.5" Brown HB Hydraulic Packer, ID =2.890" 14 10,140' 3.5"CamcoD Nipple, Min ID =2.75D" 15 10,154' Pressure Tbg Release - Bottom @ 10,156' 16 10,288' Fish—Spent 5" TCP Guns PERFORATION DETAIL Sands Top (M I Btm (MD) Top (ND) Btm (ND) FT Date Status KUP C1 10,184' 10,214' 7,039' 7,059' 30 6/01/1985 Open KUP B7 1 10,243' 10,288' 1 7,077 7,106' 1 45 1 Proposed I Proposed TCP Guns: 5" 12 spf 22 gram shoot & drop GENERAL WELL INFO API: 50-029-21348-00-00 Drilled, Cased and Completed by Nabors 27E-5/30/1985 Revised By: TDF 11/5/2019 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday,August 23, 2017 9:43 AM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA) Subject: RE: Injector MPB-13 (PTD# 1850930) Monitoring Results - Remain On Injection Attachments: MPB-13 TIO.xlsx Chris, Milne Point water injector MPB-13 (PTD# 1850930) returned to injection on 6/30/17 for monitoring after passing MITs. The initial 28 day monitoring period included an increase in injection pressure/rate that resulted in a 250 psi increase in IA pressure. The well was observed for an additional 28 day period to confirm integrity under stable injection. Since initial bleeds following return to injection, there has been no further pressurization or bleeds performed. Hilcorp believes there are no integrity concerns with this well and plans to keep the well on injection. A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG 3 0 2017 From:Wyatt Rivard Sent:Wednesday,July 26, 2017 2:19 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Regg,James B(DOA)<jim.regg@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Subject: RE: Injector MPB-13 (PTD#1850930) Continued Monitoring Chris, Milne Point water injector MPB-13 (PTD# 1850930) returned to injection on 6/30/17 for 28 day monitoring after passing MITs. The IA was bled once on 7/1/17 for initial warmup and then again on 7/7/17 to ensure a good differential was in place for continued monitoring. A TIO plot is attached for reference. Following the 7/7/17 bleed, the IA pressure has varied up and down but has increased overall by roughly 260 psi.The IA pressure increase coincides with a similar increase in injection pressure/rate and is not believed to result from TxIA communication.To confirm ongoing integrity, Hilcorp would like to monitor the well under injection for an additional 28 days. Monitoring results will be provided at 28 days with the well shut-in at any indication of TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 (wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday,July 26, 2017 2:19 PM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: Injector MPB-13 (PTD# 1850930) Continued Monitoring Attachments: MPB-13 TIO.xlsx Chris, Milne Point water injector MPB-13 (PTD# 1850930) returned to injection on 6/30/17 for 28 day monitoring after passing MITs.The IA was bled once on 7/1/17 for initial warmup and then again on 7/7/17 to ensure a good differential was in place for continued monitoring.A TIO plot is attached for reference. Following the 7/7/17 bleed,the IA pressure has varied up and down but has increased overall by roughly 260 psi.The IA pressure increase coincides with a similar increase in injection pressure/rate and is not believed to result from TxIA communication.To confirm ongoing integrity, Hilcorp would like to monitor the well under injection for an additional 28 days. Monitoring results will be provided at 28 days with the well shut-in at any indication of TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED AUG '0 9 2017 From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent:Wednesday,June 28,2017 7:47 AM To:Wyatt Rivard<wrivard@hilcorp.com> Cc: Regg,James B (DOA)<jim.regg@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Subject: RE: Injector MPB-13 (PTD#1850930) Request to Return to Injection Wyatt, Yes, I agree with the plan below. A review at 28 days is prudent and should confirm ongoing integrity. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas.Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent:Tuesday,June 27, 2017 5:37 PM 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,June 28, 2017 7:47 AM To: Wyatt Rivard Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) • Subject: RE: Injector MPB-13 (PTD# 1850930) Request to Return to Injection Wyatt, Yes, I agree with the plan below. A review at 28 days is prudent and should confirm ongoing integrity. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. SCANKED , UL �..� " From:Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent:Tuesday,June 27,2017 5:37 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: Regg,James B(DOA)<jim.regg@alaska.gov>; Brooks, Phoebe L(DOA)<phoebe.brooks@alaska.gov> Subject: RE: Injector MPB-13 (PTD#1850930) Request to Return to Injection Chris, Milne Point water injector MPB-13 (PTD# 1850930) had a passing diagnostic MIT-T to 2000 psi on 6/22/17 against a plug set in the tubing. The MIT-T was performed to rule out the possibility of a one-way leak following a passing MIT-IA conducted 6/11/17. Following the MIT-T,the well was left with 2000 psi on the tubing for 5 days with no indication of IA pressurization.The TIO plot and passing MIT-T are attached for reference.At this point Hilcorp believes the appearance of repressurization following a bleed was likely due to thermal effects and that the well does not have an integrity issue. Going forward, Hilcorp requests permission to return MPB-13 to injection for a 28 day monitoring period. Monitoring results will be provided at 28 days with the well shut-in at any indication of further TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 From:Wyatt Rivare Sent:Tuesday,June 13,2017 4:04 PM To: 'Wallace,Chris D(DOA)'<chris.wallace@alaska.gov>;Alaska NS- Mi n- - Isite Supervisors<AlaskaNS-Milne- 1 • • Wallace, Chris D (DOA) • From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday,June 13, 2017 4:04 PM To: Wallace, Chris D (DOA);Alaska NS- Milne -Wellsite Supervisors; Brooks, Phoebe L (DOA) Cc: Regg,James B (DOA); Stan Porhola;Alaska NS - Milne - Field Foreman Subject: RE: Injector MPB-13 (PTD# 185093a.Passing MIT-IA Attachments: MIT MPU B-13 06-11-17.xlsx All, Milne Point water injector MPB-13 (PTD# 1850930) had a passing diagnostic MIT-IA to 2000 psi (attached) on 6/11/17. Additionally,the well had a passing tubing hanger void test to 5000 psi on 6/6/17. Going forward,an MIT-T will be conducted to rule out the possibility of a one-way leak to IA. Path Forward—Operations 1) Set TTP in the D Nipple at 10,140' 2) MIT-T to 2000 psi. 3) If passing MIT-T, leave tubing pressured up for minimum of 5 days before bleeding back. Monitor daily T/IA/OA pressures for any indication of slow TxIA while shut-in. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED .,1_)1\ From:Wyatt Rivard ent:Tuesday,June 06, 2017 11:57 AM To. ' allace,Chris D (DOA)'<chris.wallace@alaska.gov>;Alaska NS- Milne-Wellsite Supervisors<AlaskaNS-Milne- Wellsit• upervisors@hilcorp.com> Cc: 'Regg, . • es B(DOA)'<jim.regg@alaska.gov>;Stan Porhola<sporhola@hilcorp.com>;Taylor Wellman <twellman@hi •rp.com>;Anthony McConkey<amcconkey@hilcorp.com>;Alaska NS- Milne- Field Foreman <AlaskaNS-Milne-Fi- •Foreman@hilcorp.com> Subject: Injector MPB-1 •TD# 1850930)Shut-In for IA Pressurization All, Milne Point water injector MPB-13 (PTD#18509 was shut in on 6/5/17 for signs of IA pressurization.The well had recently returned to injection on 5/12/17 after a RWO • ' s offset producer.The well's IA was bled down on 6/2/17 from 1900 psi to 720 psi.The bleed was initially attributed to •-rmal effects from the recent RTI and increase in injection rate on 5/22/17. However,following the bleed,subsequen -pressurization under a steady injection rate suggests possible TxIA communication.The well will remain shut in until :nostics are complete and integrity is restored.A TIO plot is attached for reference. MPB-13 Diagnostic Steps-Operations 1) Perform a void test of Tubing Hanger seals.Attempt to reenergize if failed. 2) Perform a diagnostic MIT-IA to 2000 psi 1 i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(Ct)alaska.ctov AOGCC.Inspectors(rDalaska.00v phoebe.brooksCc1alaska.00v chris.wallace(c'9alaska.aov OPERATOR: Hilcorp Alaska LLC ! FIELD/UNIT/PAD: Milne Point Unit/B Pad �((ji �7//j 3/ 7 ( 111 I DATE: 06/11/17 OPERATOR REP: Matt Linder AOGCC REP: Well B-13 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mn. PTD 1850930 - Type Inj N • Tubing 735 803 783 - 772 - 764 - 756 Type Test P Packer TVD 8,988. BBL Pump 2.5- IA 120 2022 1978 1966 - 1961 - 1958 - Interval 4 V Test psi 1747 ` BBL Return 2.5 _ OA 265 269 269 269 . 270 - 270 - Result P - Notes: Diagnostic MIT-IA following possible IA repressurization after bleed. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing _ Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA • Result • Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mn. PTD Type IN Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial -15 Min. 30 Min. 45 Min. 60 Min. • PTD Type IN Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type IN Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mn. PTD Type Inj Tubing _ Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) • MIT MPU B-13 06-11-17 I Thank You, Wyatt Rivard I Well Integrity Engineer I1Iilcorp Alaska, LLC 0: (907) 777-854,7 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoita Drive,Suite 1400 I Anchorage,AK 99503 2 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday,June 6, 2017 11:57 AM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors Cc: Regg,James B (DOA); Stan Porhola;Taylor Wellman;Anthony McConkey;Alaska NS - Milne - Field Foreman Subject: Injector MPB-13 (PTD# 1850930) Shut-In for IA Pressurization Attachments: MPB-13 TIO.xlsx All, Milne Point water injector MPB-13 (PTD#1850930)was shut in on 6/5/17 for signs of IA pressurization.The well had recently returned to injection on 5/12/17 after a RWO of its offset producer.The well's IA was bled down on 6/2/17 from 1900 psi to 720 psi.The bleed was initially attributed to thermal effects from the recent RTI and increase in injection rate on 5/22/17. However,following the bleed, subsequent repressurization under a steady injection rate suggests possible TxIA communication.The well will remain shut in until diagnostics are complete and integrity is restored.A TIO plot is attached for reference. MPB-13 Diagnostic Steps-Operations 1) Perform a void test of Tubing Hanger seals.Attempt to reenergize if failed. 2) Perform a diagnostic MIT-IA to 2000 psi Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED JUN 1, 2 J 1 • STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMM__.JN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon u Repair Well Lf Plug Perforations LI Perforate U Other U First Injection Performed' Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4 Well Class Before Work. 5.Permit to Drill Number: Name BP Exploration(Alaska),Inc Development El Exploratory ❑ 185-093-0 3.Address. P 0 Box 196612 Stratigraphit❑ Service ❑., 6.API Number. Anchorage,AK 99519-6612 50-029-21348-00-00 7.Property Designation(Lease Number) 8 Well Name and Number: ADL0047438 KUP MPB-13 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s) MILNE POINT,KUPARUK RIVER OIL 11.Present Well Condition Summary Total Depth measured 10727 feet Plugs measured None feet true vertical 7381.75 feet Junk measured 10288 feet Effective Depth measured 10352 feet Packer measured 10104 feet true vertical 7146.01 feet true vertical 6988.14 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 13-3/8"48#H-40 35-115 35-115 0 0 Surface 6091 9-5/8"36#K-55 36-6127 36-4674 31 3520 2020 Intermediate None None None None None None Production 10427 7"26#L-80 34-10461 34-7214 53 7240 5410 Liner None None None None None None RECEIVED Perforation depth Measured depth 10184-10214 feet DEC 15 2014 True Vertical depth 7039 49-7058 75 feet µ`•►► Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 31-10156 31 -7021 51 " `0GCC Packers and SSSV(type,measured and true vertical depth) 3-1/2"BOT HB Hydraulic Packer 10104 6988 14 Packer 3-1/2"Camco TRDP-1A SSV 1898 1862 5 SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured): GANNED F 0 Treatment descriptions including volumes used and final pressure. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 1507 1041 60 970 0 Subsequent to operation: 0 0 1040 0 232 14.Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑ Service❑' Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPLLLJ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUC] 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt: 313-609 Contact Nita Summerhays Email Nita.Summerhaysabp.com / Pnnted Name Nita Summerha s Title Petrotechnical Data Engineer ••- _C--%r i/ / Phone 564-4035 Date 12/15/2014 (Ice RBC MS DEC 16 24 A /.41.15 Form 10-404 Revised 10/2012 fr. l-firJ Submit Original Only Daily Report of Well Operations ADL0047438 ACTIVITYDATE ISUMMARY T/I/O= 800/200/330 MIT-IA (AOGCC witnessed by Jeff Jones) FAIL. Ran additional test without AOGCC witness PASSED on second attempt. First 15 minutes lost 59 psi, second 15 lost 26 psi, third 15 minutes gained 2 psi. Well to be shut in. Rigged onto Injection line and freeze protect tubing with 22 bbs 60/40. Closed wing and pumped 8 9/14/2014 bbls 60/40 toward header. Lateral valves left open for thermal. T/I/0=1915/211/343 AOGCC MIT IA PASSED to 2500 psi (Witnessed by Bob Noble) Pumped 2.6 bbls diesel down IA to test. IAP lost 24 psi 1st 15 min, &gained 10 psi 2nd 9/25/2014 15 min PASS FWHP's=1893/80/353 Tags hung at wing &casing valve FLUIDS PUMPED BBLS 9.6 DIESEL 30 60/40 METH 39.6 TOTAL TREE: 3 1/8"-5M FMC MPB-13 w/31/2"Otis Quick Union KB Elev.= 59' Nabors 27E GL Elev.= 35' Nabors 27E WELLHEAD:11"5M FMC w/3 1/2" 'H'BPV profile. II, ------iCamco TRDP-1A-SSA SCSSV 1898' (2.812"ID) 13 3/8",48#, H-40 105' , CAMCO 3 1/2"KBUG Gas Lift Mandrels PELP # and tvd dg 10 2166' 2102' 43 9 5/8", 36#,K-55 L-80 BTRC 6127' I 1 9 2996' 2793' 46 8 3910' 3394' 40 7 4942' 3999' 34 KOP @ 500' '/� 6 5798' 4490' 29 MAX Hole Angle: 5 6682' 4992' 36 56.5 DEG @ 7700' II 4 7562' 5497' 38 Minimum Restriction is Camco'D'Nipple 0 3 8442' 5992' 40 2.75°@ 10,140' 2 9292' 6483' 42 1 10,048' 6952' 39 3 1/2",9.2#,BTRS,L-80 TUBING DRIFT ID:2.867' 0 NOTE:ALL Gas Lift Mandrels have CAPACITY:0.0087 BBL/FT X Dummy valves installed in them.9/16/2012 0 \_ Casing R.A.Marker 9985' 7",26#,L-80,BTRC Casing DRIFT ID:6.151" ;`'0 \ Tubing R.A.Marker 10,057' CAPACITY w/tbq: .0264 bpf11 — BOT PBR,Seal Assembly(3.0"I.D.) 10,086' 1617mig BOT'HB'Hydraulic Packer (2.89"I.D.) 10,104' Camco'D'Nipple 2.750"I.D. 10,140' Li_ --Tubing Tail w/Re-entry Guide 10,156' PERFORATION SUMMARY Zone Size SPF MD' TVD' MK 12 10,184'-10,214' 7039'-7058' NOTE:Top of fish 10,288' Tag Fill Wireline 5/29/85 10,352' IN.— 7"26#L-80 BTRS 6.276"I.D. 10,471' DATE REV.BY COMMENTS MILNE POINT UNIT 10/16/12 B. Bixby Convert drawing to Canvas WELL MPB-13 API NO: 50-029-21348 BP EXPLORATION (AK) Imag~roject Well History File' Cover ~l~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes. No. [] Ma ps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~ [] Other: .... OVERSIZED (Non-Scannable) NOTES: ' Logs of various,kinds [3 Other Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /S/ Scanning Preparation BY: O BREN Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY; Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~;,...'~NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~.."~ES NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ned.wlxJ OF Ty • yw Alaska Oil and Gas \ I�j,7 � THE STATE T ofl 1 1 1 V,��1 1 C3noervatkm Commission GOVERNOR SEAN PARNELL +. f� � 333 West Seventh Avenue �� F L 3 s L4, , Anchorage, Alaska 99501-3572 ALAS S A Main: 907.279.1433 7W'� Fax: 907.276.7542 Anthony McConkey Production Engineer �J BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, KUP M4-13 Sundry Number: 313-609 Dear Mr. McConkey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ' - Cathy P. oerster �/ Chair, Commissioner 2644A– DATED this2 day of November, 2013. Encl. . , �� • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 19 2013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCO 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Convert to Infector ig 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development el . 185-093-0 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21348-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KUP MPB-13 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047438 • MILNE POINT, KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10727 7382 10352 7146 None 10288 ' Casing Length Size MD TVD Burst Collapse Structural - Conductor 80 13-3/8"48#H-40 35-115 35-114.99 Surface 6091 9-5/8"36#K-55 36-6127 36-4674.31 3520 2020 Intermediate None None None None Nate None Production 10427 7"26#L-80 34-10461 34-7214.53 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 10184-10214• 7039.49-7058.75 3-1/2"9.3#L-80 L-80 31-10156 Packers and SSSV Type: 3-1/2"BOT HB Hydraulic Packer Packers and SSSV MD(ft)and TVD(ft): 10104,6988.14 • 3-1/2"Camco TRDP-1A SCSSV 1898',1862.5 4. 12.Attachments: 13.Well Class after proposed work: ■►,a Description Summary of Proposal ❑ a� %.t. Detailed Operations Program El . BOP Sketch ❑ Exploratory ❑ Development [1 Service lyj %NV' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ o , GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Anthony McConkey Email Anthony.McConkeyyBP.Com Printed Name Adt Anthony McConkey Title Production Engineer Signature IS�� Phone 564-5504 /ate/ Prepared by Gary Catron 564-4424 VP ///1.:c ze/3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness oxi ""2.Sundry Number J\2 J — Co OS Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: -6 orerckAe, IA OLCCOrdVn c c, hit Al 0 I O A Spacing Exception Required? Yes ❑ No U Subsequent Form Required: )0- -t`o 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I(—26 —l3 p j ; �'t{6 ll1�►IIb C.ah1 IILI,zoi3 Form 10-403 Revised 10/2012 „\re._ ( , rio�ts[ id for 12 months from the date of approval. Submit F°`1/41i •y • • Milne Point B-13 (PTD# 185093) Current Status The Milne Point well B-13 was drilled and completed as a Kuparuk formation gas-lifted producer in May 1985. The well was only perforated in the C sands, as the B sands were found to be below the WOC. A flow test after completion revealed 40 bopd, 7.5 skin, and 0.151 PI. Five months after completion, a mud acid job was pumped in an attempt to raise the P.I., unfortunately the acid stimulation opened the annulus to the lower lobe of the middle Kuparuk formation which is wet. The production rate of the well changed to 1000+ bwpd. Investigation into the chloride content and volume of water provided sufficient evidence that the water is from the Kuparuk formation. The well was SI in January 1986, due to high watercut. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert well B-13 to B and C sand injector in the Kuparuk pool. The conversion will provide increased injection capacity to the southern portion of the 3B hydraulic unit and better support to producers MPE-08 and MPE-04. Completion A 9-5/8" surface casing was run to 6127' MD (4674' TVD)and cemented to surface with 829 bbls of 12.2 ppg Arctic Set III w/4#/sack Gilsonite and 57 bbls of 15.8 ppg Class "G" cement w/3% NaCI and 0.2% D-46. About 14 bbls of Arctic Set III cement was seen at surface when pumping the class "G", ensuring full cement to surface. Using volumetric calculations, the surface casing is estimated to be cemented from 6127'MD to 5671'MD (4418' TVD)with class "G" cement and 5671'MD to surface with the Arctic Set III cement. MPB-13 (PTD 185093) enters the Kuparuk formation at 9746' MD (6760' TVD). The 7" production casing was run to 10471'MD (7221' TVD), it was cemented with 58 bbls of 15.8 ppg class "G" cement w/0.8% D-60, 0.25% D-13, and 0.2% D-46. Using volumetric calculations, we estimate the class "G" cement from 10471'MD to 9406'MD (6552' TVD). After cement was pumped the plugs bumped, the packer inflated with 2700psi, and floats held. Although no cement bond log was run after the cementing operation, we are confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well is currently perforated in the C sands. Plan Forward: 1) Obtain Sundry for conversion to water injection / 2) Complete water injection header tie-in 3) Place well on water injection (confirm AOGCC approval prior to injection) 4) AOGCC witnessed MITIA once injection has stabilized for fa'o&c4r/ ?ra M cla. t, Coi"eft 4Y cow, Tot e I( "5 q �, o fo r M tf<i'ay r4s v�a6fi k-e// R) o ;A decal" r`f r4e 6psr- o p 7-4 /4°1. G!'�d Coiirri4TI Pt t0 reco vQ/y • • Area of Review - Milne Point B-13 (Permit# 185093) This Area of Review is required prior to the conversion of well MPB-13 from a producer to a water injector. This AOR discusses wells within 1/4 mile of the well's entry point into the Kuparuk Formation to the bottom of MPB-13 well bore completion. The only other wellbore that enters this boundary extent for the Area of Review is MPE-08. The tables below describe the relation between wellbores. Distance woo Name PTD (feet) Annulus Integrity MPB-13 185093 0 TOC estimated at 9406' MD MPE-08 191050 930 TOC estimated at 8500' MD; Table 1: Table showing distance &annulus integrity of wells within AOR Hole Vol, of Well Name Casing Size Cement Kuparuk depth (MD) Kuparuk depth (TVDss) MPB-13 7° 10-1/4' 58 bbls 9746' 6760' MPE-08 7" 8-1/2" 92 bbls 9356' 6850' Table 2: Completion Detail Well MPE-08 (PTD# 191050) was completed in August 1991 . The completion crossed the Kuparuk formation at 6850' MD (5189' TVD). A 9-5/8" surface casing string was run to 5947'MD (4950' TVD). The surface casing was cemented to surface with 550 bbls of 12.3 ppg 'Arctic Pack' Permafrost class E cement, followed by 82 bbls of 15.8 ppg class G cement. The 7" production casing was run 10288' MD (7475' TVD) and cemented with 122 bbls of 15.8 ppg class G cement. The TOC was estimated at 8500'MD (6279' TVD). Plugs were bumped successfully after each of the cementing operations. The packer was inflated at 1500 psi, floats held, and packoff was set. MPE-08 is a fully operable producer. The well is currently shut in, in attempt to get better support from the MPB-05A injector to MPE-04, as MPE-04' production is suffering without proper support. . • • Of l 1 / 1 I a ID ' - 1 / MPB-Q1 , 4 1 4 B ap / BC i J d # it 1! !!�{ /A//�E/� ••••".' ''MP 5A / 1 t ► , y f / 1 • A n �! f 1 i k ■ k A I vq t i r 4, l 1. M -...., .. -15 �C l� MPB-1 I / MPE-1 , '. 81 y + a 1 { CIC1 i - IIIMPE / 1 1 ..,,B B1CI f E / 4 Figure: Map showing wells within 0.25 mi radius from MPB-13. TREE: 3 1/8"-5M FMC M P B-13 w/3 1/2"Otis Quick Union KB Elev.= 59' Nabors 27E GL Elev.= 35' Nabors 27E WELLHEAD:11"5M FMC w/3 1/2" 'H'BPV profile. Camco TRDP-1 A-SSA SCSSV 1898 (2.812"ID) 13 3/8",48#, H-40 105' / , CAMCO 3 1/2"KBUG Gas Lift Mandrels PELP # and tvd dg II 10 2166' 2102' 43 9 5/8", 36#,K-55 L-80 BTRC 6127' I 1 9 2996' 2793' 46 8 3910' 3394' 40 7 4942' 3999' 34 KOP @ 500' 6 5798' 4490' 29 MAX Hole Angle: 110 56.5 DEG @ 7700' 5 6682' 4992' 36 4 7562' 5497' 38 Minimum Restriction is Camco'D'Nipple 1 3 8442' 5992' 40 2.75°@ 1 0,140' _ 2 9292' 6483' 42 IP 1 10,048' 6952' 39 3 1/2",9.2#,BTRS,L-80 TUBING DRIFT ID:2.867" I NOTE:ALL Gas Lift Mandrels have CAPACITY:0.0087 BBL/FT 1 Dummy valves installed in them.9/16/2012 F \_ 7",26#,L-80,BTRC Casing Casing R.A.Marker 9985' DRIFT ID:6.151" ' Tubing R.A. Marker 10,057' CAPACITY w/tbq:.0264 bpf BOT PBR,Seal Assembly(3.0"I.D.) 10,086' BOT'FIB'Hydraulic Packer (2.89"I.D.) 10,104' D Camco'D'Nipple 2.750"I.D. 10,140' Tubing Tail w/Re-entry Guide 10,156' PERFORATION SUMMARY Zone Size SPF MD' TVD' MK 12 10,184'-10,214' 7039'-7058' NOTE:Top of fish 10,288' ' Tag Fill Wireline 5/29/85 10,352' I 7"26#L-80 BTRS 6.276"I.D. 10,471' DATE REV.BY COMMENTS MILNE POINT UNIT 10/16/12 B. Bixby Convert drawing to Canvas WELL MPB-13 API NO: 50-029-21348 BP EXPLORATION (AK) ~ ' Milne Point 2001 Shut In Wells ... Date Reason for Future Utility Plans & Sw Name Shut4n Well Shut-tn f Current Mechanical Condition of Well2 Possibilities 3 Comments MPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle gas. Possible production after gas expansion project, MPB-08 May-94 E No known problems 3 Futher use as an injector not rec/uired &fP,.B.;13. ~ Jan-86 B GL well that was shut in due to high 3 Weilhouse and flowlines removed water cut. Possible channel into water zone. MPB-17 Jan-96 E No mechanical problems. Quick 3 Weilhouse and flowlines removed communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 Weilhouse and flowlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems 3 Further use as an injector not required while associated producer shut-tn MPC-12~ Jan-O0 E :Fish in hole, drilling problems 3 Suspended due to drilling problems. 12a MPC-16 Aug-93 A High GOR well, perfs and completion 3 Weilhouse and flowlines removed abandoned MPC-17 May-O0 D Leak in 9 $/8" casing to surface I Evaluating possible plans for solution to oroblem. MPC-20 Apr-O0 B High water cut well, no mechanical I Evaluating possible plans for solution to problems ,problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I ~ Evaluating possible plans for solution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block problem. Possible alternative uses for wellbore MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well MPE-02 Jun-05 C No known problems 2 Recomplete to upper Kup zone MPE-19 Audi-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities iMPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities MPL-21 0ct-98 E High'pressure block - 5000 psi, no I Possible use for injection when pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP, no other mechanical I Evaluating possible side track plans or ~ssuses recompletion s MPL-39 Jan-99 E Could not inject gas into well, no use I Evalua ting possible side track plans or for it. recompletions !:~ !~/i~h:..G.O~. :':-c.,~re nti3~:-uncomp, el:mve 'to:prod,ace: du:.e::!t~:.-~ ~y::c o-n ~atnt s~. :no-:~w n' mecha m~al pro o 1 em s ~ ~;5~::~Oa~t~o~:5-?~:'.~ :~-~:'~5=-~ ~: ~f~'~ .................................. ~ ~:;~;~.~:~i~-:. ' ..- . :... . *Note- Wells were shut in 100% during2001 Milne PI Shut In Wells 2001.xls . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0,/7 DATE: July 12, 2000 Commissioner' tf //~bc~ THRU: Blair Wondzell, Q1~ P. I. Supervisor . êf ..,( dJ FROM: Jeff Jone~, t1i:1-- SUBJECT: Safety Valve Tests Petroleum I sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 ÞtO~ r~-k-,;>i- 21 well houses were inspected, no failures. .". Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test I~eport Operator: BPX Operator Rep: Larry Niles AOGCC Rcp: Jeff Jones \ ~,::.,"':W eli :b~t~ .r':r> ".~~:"~::,:~"~:",,':;"'~":<:"": ~'.:"'j;ii(/is''';:'' ::~'~"';:'.:'T;~{~~¡.:.~.:~~:»:" '~~~$:)t~~.: :.~'SSV:~ ~,. ':-' ;::J:;.. .." W éll~~.1)T/e:::; t.: Well Pennit Scpar Sct LIP Tcst Test Test Numbcr Nun1ber PSI PSI Trip Code Code Code B-02 1811420 B-03 1820560 B-04A 1821000 B-06 1850130 B-07 1850620 B-09 1850340 B-10 1850170 B-13 1850930 8-15 1851210 B-16 1851490 B-19 1852300 B-20 1860050 B-21 1860230 B-22 1853020 B-23 1890160 N h..) N Wells: 140 140 140 140 140 140 140 140 140 9 COlnponellts: 100 100 100 100 100 100 100 100 100 Submitted By: Date: FieldlUnitlPad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 BPS NI A 115 95 90 95 95 100 P P P 95 90 p P 7/9/00 95 P Oil, WAG, GIN.J, GAS or CYCLE P P P OIL OIL OIL P P P 18 Failures: p p OIL OIL p OIL p P 4 OIL OIL OIL Failure Rate: 5.50/0 090 Day Three well SV's recorded slow closing titnes; B-04A(3 :20), 8-03(3 :03),B-06(3 :30). SOlne of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. Remarl{s: 9,/7/00 Page 1 of 1 Vvo43m 1 t.xls ConOCO Inc. 3201 C Street Suite 200 Anchorage, AY- 99503 (9071 564-7600 May 29, 1987 Ms. Fran Jones Alaska Oil and Gas conservation commission 3001 porcupine Drive Alaska 99501 Anchorage, Dear Ms. jones: "well histories" £rom conocO's Milne Enclosed please £ind the drilling and B-13. point Unit wells No. C-13, C-14, C-15 concerning this well history, additional in£ormati~n I£ you requireDon Girdler at 564-7637' please contact yours ve~ Sr. ;dministrat' DRG/W B-13 C-13, C-14, C-15, RECEIVED JUl',,] --- ,:. 1~87 Alaska Oil & Gas Cons. Commissinn Anchorape Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.15- CONFIDENTIAL (7,319'-Kuparuk River) AFE 10-61-1112 API No. 50-029-21358. Ak. Permit No. 85-103. Elevation: 59' KB. Location: 725' FSL, 2098' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-22-85: Prepare to skid rig & pipe shed; remove red iron. Nipple up 20" diverter system. Strap & pickup BHA & service MWD - brk circ. Function & fluid test 20" hydril to 100 psi & diverter lines. Spud in & drlg from 105' to 2250' w/ surveys @ 450' stations. 5-23: Drlg from 2250' to 3114' & mix, pump pill. POOH from 3114' for BHA change. Change BHA, pickup Navidrill Mach III, orient & test MWD. RIH to 3114' & orient Navidrill. Drlg from 3114' to 4055' w/directional drlg & surveys. Mix & pump pill. POH from 4055' for BHA change. Change BHA (lay down Navidrill & service) make up new BHA. RIH (still tripping @ this time) 5-24: Work on rig SCR circuitry (loose belt on contactor created power surge weakening many relays - destroyed contactor - replaced relays & contactor). Circ. @ 2930'. RIH to 3815' & ream thru last of Navidrill run to 4055'. Drlg from 4055' to 4400' w/light wt.; angle building trying to break arc. 5-25: Drlg from 4400' to 4715'. Circ. & short trip from 4715' to 3100'. POH from 4715' SLM (no correction) & laydown BHA, service MWD. RU csg. crew. Run 119 jts. 9 5/8" 36# buttress csg. w/floatshoe @ 4692'. Float collar @ 4611'; 55 centralizers, good returns w/running. Lost 60 bbls w/circ. Full returns w/cmt'g, and gained 30 bbls of lost fluid back. 124 bbls cement returned to surface. Bumped plug to 2000 psi. Pumped 35 bbls+ 11 ppg Sepiolite preflush, 461 bbls of 12.3 ppg. Permafrost E w/5# sk of Gilsonite, followed by 51 bbls of Class "G" cement w/3% salt & 1% CFR-2, chased by 5 bbls H~O & 351 bbls of 9.4 ppg mud. Floats held. RD cmt & csg tools. Lay ~own landing joint. ND diverter system. 5-26: Install trash ring & speed head torque to 14000 ft/lbs. ~ BOPD. RU to test & test BOP w/AOGCC Insp. H. Hawkins witness. Test 5" pipe rams, valves, choke line, choke manifold, upper & lower Kelly cocks to 500 & 5000 psi test hydril w/350 & 3500 psi. Lay down test joint & install wear ring. Make up BHA, service MWD, orient Navidrill & MWD; test MWD & Navidrill. Rig not operational - SCR system malfunction. RIH to 4598'. Tag cmt top @ 4598'. Test 9 5/8" csg to 1500 psi. Drlg cmt & float equipment, cleanout to 4715'. Drlg from 4715' to 4745'. Circ. & leak off test to 12 ppg EMW @ 4685' TVD. Drlg from 4745' to 5095' w/directional corrections & control. NOTE: Tag float collar @ 4600, float shoe top @ 4681', drillpipe meas. 5-27: Drlg from 5095' to 7160' with directional control. -1- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.15- CONFIDENTIAL (7,319'-Kuparuk River) AFE 10-61-1112 API No. 50-029-21358. Ak. Permit No. 85-103. Elevation: 59' KB. Location: 725' FSL, 2098' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-28: Drlg from 7160' to 7278' (pressure fluctuation, immediate high torque). Survey, pump pill. POH from 7278' (tight spot @ 6160'). Change BHA (lay down motor & MWD, service) pick up new BHA. RIH slowly, brk circ @ shoe (tight spots @ 5140', 6160', 6975'). Wash & ream from 7220' to 7278' and break in bit pattern. Drlg from 7278' to 7665'. T.D. #C-15, Geologist depth + 10'. Circ & mix pill. POH from 7278' to 4683' (9 5/8 shoe) tight spot @ 6416'. 5-29: Circ & condition mud for logs. Drop survey & pump pill. POH for logs from 7665' SLM, retrieve survey. RU Schlumberger for logs. Run logs #1 - DIL from T.D. to 4692'; LDT from T.D. to 7200'; CNL-GR from 4692' to 3600'. Hole profile log from T.D. to 6600'. RD Schlumberger. Make up BHA & RIH to shoe @ 4683'. Cut drlg line 100'. RIH to T.D. @ 7665' (clean out 9' of fill). Circ & condition mud for 7" csg run. POH, laying down drill pipe & BHA. Change top set of rams to 7". Pull wear ring. 5-30: Ran 193 jts 7" 26# L-80 btrs csg, shoe @ 7652', FC @ 7572', ECPs @ 7395' & 7374'. RU cmt head, circ and work pipe to unbridge. Pumped 35 bbls and 12 ppg Sepiolite preflush, mixed & pumped 250 sks Class "G" cmt w/l% CFR-2 & 0.3% Hal-24, displaced w/291 bbls of 10.20 ppg NaC1/NaBr, pumped plug to 2850 psi. Inflated pkrs. Back out landing jt. RD csg crew. RU Dresser Atlas, ran GR-CCL-Gyro from 0-7540', RIH, perforated 7442'-68' LK-2. Now RIH for perf gun run #2. 5-31: RIH run #3 & #4. Perforated 7338'-42', 7314'-18' L-8, 7226'-40' MK-1, w/12 SPF. Total all perfs 576 holes. Run GR & junk basket from 0'-7430'. Run wireline pkr, failed to set, firing head wet, rerun wireline pkr. Set @ 7356' WL measurement. RD Dresser. Change rams & test BOP's. RD test tools, RU to run tbg. Ran 231 jts of 3½" 9.2# L-80 BTRS tbg, 2-gas lift mandrels, BOT pkr, and etc. Stab into bottom pkr, run isolation test. Drop ball, WO ball, set pkr to 3000 psi and clear out of bullet nose, PU, space out, install hanger, install control lines, test lines, prepare to displace w/diesel. 6-1: Displaced tbg w/diesel (75 bbls). U-tube diesel, land tbg, test backside to 1500 psi, back out landing it., clean pits, change rams, ND BOP's. ND BOP's, NU tree, test tree & tbg hanger to 5000#. RELEASE RIG. -2- Tom Painter Division Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells · located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mitne Point. ACTIVE: -. B-3, B-4A, B-6, B-9, B-10, B-Ii, B-13, B-15, B-16, C-i, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit ,~ ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. If you have any questions on the shutdown procedure please contact Don Girdler at 564-7637. Yours very truly, -~ ~ Painter ~'~/~v is ion >~ana~er ~---, STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COM ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon -%_ Suspend [] Operation Shutdown Re-enter suspended well ~ Alter casing r'~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing [] Amend order ~ Perforate [.3 Other 2. Name of Oper,.ator 5. Datum elevation (DF or KB) Conoco .LnC. - 59' KB feet 3. Add~e2~l C Street, Ste. 200, Anchorage, Alaska 99503 6. UniLo~Prop~rt¥ name . mi±ne '~oInt uni~ 4. Location of well at surface 532' FSL, 979' FWL, Sec. At top. of productive interval 4696' FNL, 4999' FWL, Sec. At effective depth ~/A At t~p~L' 53' 18, T13N, RllE, U.M. 19, T13N, RllE, U.M. FWL, Sec. 20, T13N, RllE, U.M. 7. Well number B-13 8. Permit number 85-93 9. APl num~9_21348 50-- 10. ~OO~uparuk River 11. Present well condition summary Total depth: measured true vertical 10727 feet 7380 feet Plugs (measured) Effective depth: measured N/A feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 80 ' 16" Surface 6091' 9 5/8" Intermediate Production 10427 ' 7" Liner Perforation depth: measured 10184'-10214' true vertical 7039'-7058' Cemented To Surface 886 bbls 58 bbls Tubing (size, grade and measured depth) 3½", L-80, 10156 T.R.'SC£SV @ 1898' Packers and SSSV (type and measured depth) Measured depth 115' 6127' 10461' ~ue Verticaldepth 115' 4617' 7213' ; Ret. Pkr. @ 10104 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereb_y__c~ertify that the foregoing is true and correct to the best of my knowledge Signed _ ~ -~,^~ Title Rt-_ Prn~,,~¢jnn EngJnPPr Commission Use Only Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test ~ Location clearance Approved by Ap?roved ~eturned ..-- Commissioner J ApprovalNo. by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate _ ,' ' ,---... STATE OF ALASKA -~.-.. · ' ALASKA. ,L AND GAS CONSERVATION C, ,IMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well · OIL ~ GAS [] SUSPENDED [] ABANDONED I-:-], SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 85-93 3. Adc~ress 8. APl Number 3201 C Street, Ste., 200, Anchorage, AK 99503 50_029-21348 4. Location of well at surface 9. Unit or Lease Name 532' FSL, 979' FWL, Sec. 18, T13N, RllE, U.M. Milne Point Unit · At Top Producing Interval 10. Well Number 4696:' FNL, 4999' FWL, Sec. 19, T13N, RllE, U.M. B-13 At TOtal Depth 11. Field and Pool 5023' FNL, 53' FWL, Sec- 20, T13N, RllE, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59'° KBI ADL 47438 Kuparuk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 1 5. Water Depth, if offshore 116. No. of Completions 5-16-85 5-27-85 5-30-85 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10, 7.27' (7380') 10,352' (7148') YES ~] NO[] 1898 feet MDI 1800' 22. Type Electric or Other Logs Run GR- SP-DIL-CNS-CDL-CN-CD-Cal-Gyro-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZEI CEMENTING RECORD AMOUNT PULLED 13 3/8" 481f H-40 0 105' 17~ 100 cf Perm. Cmt. 9 5'/8" 36# K-55 0 6127' 14 7/8 829 bbls Arc. Set I::I 57 bbls Class G an~[ 14 bbls Arc. Set 7" 26# L-80 0 10461' 9 1/4 58 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD in~.erval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~ 3~" a 9.2# L-80 10,156' 10,110' 10,184'-10,214' (7039-7058') MK-1 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5" Hollow Carrier 22 gram 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. : PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12-11-85 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE GAS-OIL RATIO 12-30-85 6 TEST PERIOD I~ Flow '~-ubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 210 1200 24-HOUR RATE I~ -- -- 967 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips. ,'::' Form '10-407 Submit in duplicate Rev. 71-1-80 CONTINUED ON REVERSE SIDE / 29. ~'-._.-Z"- 30. 'k.': ~¢ · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 4781 3905 MA 5246 4174 NA 5585 4370 OA 5825 4504 OB 5923 4559 Middle Kuparuk 10181 7036 Lower Kuparuk 10553 7271 · 31. LIST OF ATTACHMENTS 32. I hereby certify that the fOregoing is true and correct to the best of my knowledge Signe/J~~ T i t I e ~-'~/"~~/'~/~/ Date / INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-~.93 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50- 029-21348 OTHER [] 4. Location of Well 532' FSL, 979' FWL, Sec. 18, T13N, R11E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 12. I 6 . Lease Designation and Serial No. 47438 9. Unit or Lease Name Milne Point Unit 10. Well Number B-13 1 1. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 11-13-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig,qe~d ~ ( ~-~-~/~:-- ~ - Title ~ /// - The space?/ef'ow for Commission use Conditiofis of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SCALE ~ ~S CONOCO ~LNE POINT EXI~TIHG DEVELOP~E N? SEC. lB SEC. 19 HOTE~: 1. S1A1E PLANE CO ORDINATES ACE ZONE 4. 2. ALL GEODETIC POSITIONs ARS BASED ON N.A.O. 1921. OFFSETS TO SEC/ION LINES aRE COMPUTED BASED ON PROIHACTED VALUES OF TH( SECTION CORNER POSITIONS. 4. LOCATED WITHIN SECTION 18 8, 19, TI3 N,RIIE,UM ,AK. ~'-~-~-LL J LOCATION IN SECTION ~nO~ S. LttV! Irnoea w. LfNE B - 12 0 -14 ~TATE pLA NIT COORDS. · GEODETIC ,OaT~GS SAS TINGS LatitUDE 464' ?gO' 6 , 0P3,586.20 57'1,864.47 ?0°28' 2g.019" N. 76~' 920' 6 ,023,888.56 ~71,992.42 ?0~ 28' 31.981"N. POSITIOH LONGI T UDE _ 149024' 46. ?0]" W. 149024' 42.854"W. Dr~TE ~.2,8~ 6.2, 65 i__ J. 6. g. J.B.S. f ~ELD O00K _ ZI- 65 21-65 ~32' 979' 6 ,023,656.07 3T2,0§2.77 T0°28' 29.668'N. 149~24'41.146"w- 6.2, 8§ J.B.S. 21-85 649' 9~0' 6 ~O23 ,772.36 572~022.58 70° 28' $0.835~'N. 149°2¢'42.001".W. 10.23,6§ O.T. 39-85 300' 1037' 6,023,424.25 57'2,113.60 70o28' 27. 402"N. 149°24' 39. 42~"W. 10.23,8§ B.T. 572,085.38 ~72,013.88 416' 1008' IlO' ~! 933' 814' 7'02' B82' 891' ?0°29' 22l. 548"N. TOo28' 23. 376"~ 7Oe28' 32. 458"N. 70028' 33. 127"N. "7o'. z$:33.(~c~_ .. 073' 'X Pro po ~e.~ Loc~ion~ CERTIFICATE OF SURVEYOR : 571~7T3.46 6 , 023,540.44 6 ,023,013.86 6 , 023,935.01 149°24' 40.279' W. 14 9°24' 42.472"W. 149024' 49.20 O"'W. I0.23,8~ t aNU ~URvE rt~k'e. 10.23,~ 6 , 024, 004.84 ~a. o24..oSI.o3, IO.12 O.T, B.I'. LIC[tISED 10 PRACTICE THE Sr~T[ OF ALASKA 57 I, DG I .74 L.Oo 3g 39 - 85 3g I B PAD 071.745.44 14 g° 24'43. 723 "W. II. 15,85 L.O. 39-8§ ~4c)*. Z4'-S;o. 13o ~ 11.7./..~. i · AS. BUILT WELL LOCATION CONOCO SC ACI[ : I S-gl! · 400' Il 2 O~ 3 .......... COIRHENIS ' ~ECT. ~9, A~ ~H~flS FROM S. LJIJL ~1~. II John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached is a Sundry Notice for the Milne Point B-13 well. The well was recently acidized in the Middle Kuparuk (1) formation. Unfortunately, the acid broke down the cement job and opened up the Middle Kuparuk (2) which was wet. We now plan to do a squeeze job to shut-off Middle Kuparuk (2). If you have any questions, please call Don Girdler at 564-7637. Very truly yours, JonR f laskan Operat' RECEIVED oct 2 o:i ~, t~s Cons. Commission ,~ :'iChor .._... STATE OF ALASKA . ALASK/ 'L AND GAS CONSERVATION C .'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ OTHER [] 2. Name of Operator 7. Permit No. 85-93 3. Address 3201 "C" ~r~p~: ~11~ 200, Anchorage, AK 99503 4. Location of Well 532' FSL, 979' FWL, Sec. 18, T13N, RllE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59' KB IADL 47438 12. 8. APt Number 50- 029--21348 9. Unit or Lease Name Milne Point Unit 10. Well Number M~]ne Point B-I~ 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The B-13 well was drilled and completed in the top lobe of the Middle Kuparuk formation. Because of low initial flow rates a drawdown/build-up were run. The build-up indicated severe damage. An acid treatment (12-3 mud acid) was proposed. (Verbal approval given by Mr. Chatterton 10-11-85.) The acid job unfortunately opened the annulus to the lower lobe of the Middle Kuparuk formation which is wet. The well went from a pre-acid flow rate of 50 BOPD to a post-acid flow of 1000+ BWPD. Chloride content and the volume of water recovered leave no doubt that the water is from the Kuparuk formation. It is now proposed that the water zone be shut-off by doing a coiled tubing squeeze job. The work is not yet scheduled but will take place within the next two months. 14. I he~,~ertify that the foregoing is true and correct to the best of my knowledge. Sr. RECEIVED 0OTC 5 1985 Alaska Oil & Gas C0rls. C0rnrnjssjo ..... The space below for Commission use Production Engineer Date 10-17-85 Conditions of Approval, if any: ~¥ ~-'~' ~. ~lfl£1 Approved by COIVIMISSIONER /~pproved Co,ay By Order of the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate co( o co.) John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3OO1 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion'' forms #10-407 from Conoco's Milne Point Unit wells No.-CFP-1, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-10, B-ii, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, ahn R Kemp laska Opera tions lb RECEIVED Alaska 0il & I~as COilS. Commisslor~ Anchorage * ,_ ,~--. STATE OF ALASKA ~---- ALASK, ,_ AND GAS CONSERVATION C .'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] suSpENDED [] ABANDONED [] SERVICE [] 2. Nan-le of Operator 7. Permit Number CONOCO, INC. 85- 93 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21348 4. Location of well at surface 9. Unit or Lease Name 532' FSL, 979' FWL, Section 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 4696' FNL, 4999' FWL, Section 19, T13N, RllE, U.M. B No. 13 At Total Depth 11. Field and Pool 5023' FNL, 53' FWL, Section 20, T13N, RllE, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 59' KBI ADL 47438 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 5/16/85 5/27/85 5/30/85 N/A feet MSL 1 17. Total Depth (MD+TVD)10,727, (7380') 18.Plug Back Depth (MD+TVD)10,352, (7148')YESES19' Directional SurveYNOE] I 20. Depth where SSSV set1898 feet MD I21' Thickness °f Permafr°stl800' 22. Type Electric or Other Logs Run GR-SP-DIL-CNS-CDL-CN-CD-Cal-Gyro-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 48# H-40 0 105' 17-1/2" 100 cf Perm. Cmt. 9-5/8" 36# K-55 0 6127' 14-7/8" 829 bbls Arctic Set III 57 bbls Class G and 14 bbls Arctic Set 7" 26# L-80 0 10461' 9-1/4" 58 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2# L-80 10,156 10,110' 10,184-10,214' (7039-7058') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5" Hollow Carrier 22 gram 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test I Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO I TEST PERIOD II~ Flow Tubing I CasingPressure CALCULATEDI1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · ,- RECEIVED .... · -,..~/:,/'-~o~.: Alaska 0il & 6as C0r~s. 60mmissi0r~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 4781 3905 MA 5246 4174 NA 5585 4370 OA 5825 4504 OB 5923 4559 M. Kuparuk 10181 7036 L. Kuparuk 10553 7271 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". July 2, 1985 Directional Services Pressure Services Chemical Transmission Systems Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATT: William Van Alen CONFIDENTIAL Re: Our Boss Gyroscopic Survey Job No: AK-BO-50055 .Mi~lne'~-~_~'~laska Survey Date: May 2~, 1985 Operator: D. Harger, T. McGuire William Van Alen: Please find enclosed the copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure (2 copies of survey are enclosed) cc: According to distribution list NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED J U L 1 0 !985 Alaska 0il & Gas Cons. Commission Anchorage ....... B'- i !3 .................................... MILNE I-LIN] ALA.:,I'...A L:;F'EF;:RY-SL. IN "WELl._ SLII:~VEYINr; CL]MF'ANY ANCHORAGE ALASI<~ VERTIC:AL SECTIOIq C:AI_RI_ILATED ALnNG CLOSLIRE C 0 M P Li :1- A TI 0 N D A"I' E MAY ':'1, 1 ©'-' =' .., .': F'A G E D A T E ~" F ~:::1 I1:;: V E Y I'1A Y :2'::: 1 '-.? ::: F, BOS'.E; GYROSF:OPIC: '.'_:;LIRVEY ,_lOB NLIMBER AK-BO-5005:B KEI_LY BUSI'-IING EI_FV. = 5'P.00 FT, nF'ERATOR-D. HARGER, T, MCGLIIRE ............................................................. ]';RUE ................... ::_:;[iBL:i~iEA MEASLIRED VERT I C:AL VERT I C:AL ' i DEF TH DEF'TH DEF'TH I NC:L I NAT I ON D I RECT I [:lN SEVER I TY I'iE O M I N I]EGREE'._:; DE:.G / :1. 0(} T'OTAL R E C: T A N G LI L A R c: 00 R D I N A T E S NORTH / SO U ]" H EAST / WE'._:; T · VERT I C:P' . ::~E¢:T I L ) C) 0.00 -59.00 0 0 N 0. 0 E :1.00 ,:.?o. ... 99 ..... 40. '-.?'P 1 ,_,':' '.3 59 . :::'-.?_. W .................... -:=q==..' .)U ................ 1 ":~:: ~5'""... 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'=.-,' 9 71. :.'_::7 90. :39 .1. 12../:, 1 1 :':: 7.4 0 166.02 197. :_--:9 2':.'8.6:2: .... :259. :_::/=, '2'F./2..: . 76, :=',27.04 :'::/_-, 2.77 400.96 441.44 4:--:2.94 5 25.0 :'3 566.95 6 09. C.>L:: C). 00 ("). 0 C) S C).. L=.:/'_-,. W ....... .0.12 .:, ~.. 44 1,4 -0. :2:8 ,:. .-, ,:, _ · _, ,: ...... 1 W -0.4::: :~; 4,89 ~ -0,27 S 5.31 W (').72: S ~ 2 '...=.; 4.84- W /_-,. :38 .......... S 4. 18 W 10.59 '.F.; :=:. 02 W 16. C) 0 S 1 · 0:2: N 2:B. :=4 :'4 :.=:; I, :27 E 3:3 · 97 '.F_-; 4.76 E 4/-,. 46 :.=; 11.77 E 6,3,71 S 21.77 E :=:5.. S c,.=, ,=,oE lC)'--/ :::-~] ._! ._~ w · =, 4:=:. 73 E 13:--:. 57 S 66.94 E 172.35 · -,'-' 88 .49. _- '-..-' 10.. 5:_/-._ :-7 11:3~: 33_ -] ....... 250.27 · > 141.42 _ 292.15 S 172.18 ] 336.99 "-' '.-.'C)~ A 0 384 o 4 :--'; '--'239. :=:4 ] 433.74 :_--.; 273.49 '- 484. ~ 3 '.=; 306./-, .... 1 - 5 :q/-, . ,_,~'--"-" · =, 34 C). '-' ~ = 5'-.-; 0 ":":---' · _~-. ~ . . · ~:_ %.. '.=-.; 377 67 : /-,4 ' .:, 4:1. 8 · :i.::; 4/-,_ 1 · 3='._, E 7,'_.', zl, . ("!_ ,_':. B- 1:2: MILNE POINT ALASI<A · ::,'-'F'-. ER"R Y"=;I .... II',l WELL ::;LIRVEY I I',lr3 C:CiMF'AI',.IY A N ~"': H ii R A G E A L A :'_-:'; K A C:OIdF'I.]T~'I"]?DN DA'r'[:: MAY ':' 1 ? 1'..-,'""= ._, :: VERTICAL .=,E..TION CALCULATED ALONG CLOSURE F'A G E :2 D A T I.-':' ~"~ F '::;1_1R V E Y M A Y 2 8, 1 ':',"-' '= · .': C, B 0 S :.:;" Iq Y R 0 S F: i-~ F' I C :551_1R V I--' Y J 0 B N LI FI B E R A K- B O- 5 0 0 5:3 KELLY BUE;HING ELEV. = 5 9.00 FT. 0 P IF- R A T 0 IR- I"~. H A R~'..'i E'IR, T · ' M F: G U I R E T'RLiE ................ i~djB' SEA I'IEARURED VERT I CAL VERT I C:AL DEPTH £ EF 1 H £ EF TH I N C L I N A T I 0 ND I R E _. T I 0 N DEG I't I N DEGREES D 0 G- L E G ......... T 0 T' A L ................ '.'--;EVER I TY IREr':TANFd ILAR C:OORD INA] E._ VERT I I-:Al ,. DEA/IO0 NORTH/SOUTH EAST/WEST SEC:TI .) .. 40 36 4 :':: :1. 6, 5 49 .'1.6 50 1 50 .... 11 51 51 2:3 · -', ,:, (.) t)o .--, ..' 6. 'T, .~ :5:9 0 0 ~_,'.':' ._,':' :3 7 .4 0 400() :'::447,52 4 i00 :_:: 5 (] /:, , :3:_:: 420O :356_-,:_::. 75 4:30 (] 2620. 1. 4 44 O0 ~i6,77. '.-.-/:--: 45¢")(") :3737.49 46, 0 (] :3797.05 4700.q,~ ~..~,, '3:356.6/:., 4:5:0 C)' :3915.99 4900 3':.? 74. :30 .5~'00 .... 4():2i I .'83 51 ,c:~ 0 40:5:'.?. 40 5200 4147· 12 5:30 o 4 c..,O 5.41 .54 O0 426,3. C,'6, 56 O0 437:_-: 21' ... 70o 4434 51 ~ ,-, .-., . ~.,,=, 0 C!~,~.~,' 4490.... 6, L~' 590 C) 4 .... 46.. () 6, · :":4":":' 40 M'7 4 0 ~.!.- .-' ~..~ m . .- .~. '-'":-":'"" ~'.~' 5:5: 24 · '_::447.38 54 28 3504.75 55 31 3561.14 55 49 ..... :2:61 ':' ':/::: 5 ::": '-'. o ~_,, · .- _ .... 367:--:. 49 5:5: 2:_--: 3738.05 5:_:: 25 5:--: 2:3 :37'77./-"~Z~'~ 5:3 :--::356 9'y ' 4:_-_.: :3915.3 o 54 51 3972.8:3 ._4.-q54 40:3 o. 40 ~4.=, 47 4 o 88.12 54 41 4146,. 41 54 0 4204. :::6, 54 27 426_-,2.~, -~/iS'/. ;":' . 4.'_:: 19 21~ 55 26 4.-, ?._, 51 ~/-, '-.' 44:31.-..2":~'-~¢.~.x) 55, 11 44:s:7 ()~, .,., . _~ ,.% ':' Zl. 2. :::'.~ S 41. :5:9 S 4.¢"D. 80 S 4C). :5; ::.:'P, 5c~ .:,"" 4,I'). · 5: :.:.'i; :z:':'.;'. 6, (") c:. :-_:..7,, ~(-) E; :Z:,,E:. 6C) :-'::::. :1.'.'.-/ S :2:::',, 5() ... ':' :2:8. :'::(') :5; :5:7, :39 S :5:7, !5 ::-; :2:7.6, 0 '.:; 37.:2:'.:.) :--: ,:- :2::2:. 80 F; :2:4. :2:C) :=; 1--' .-I c., ,:,._,. 1 0 S :3:3. 10 S 30.69 S ' 2::'-': .-6, 0 S "":' 6o .'. _,. :F.; 28. ,'_':, 0 5 ',':7. 1':..'~ E E:. E E r.'..:. E E E E E ,-- ._ 2.- :.- .-- --_. --_ %- ·- ~.- E E :.~ :;:". 17 1- ~.5":' 04 S -! ,...--! 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A_ '-.?. 212/-,_. 7.5 '._:; 1 '--' .~- . _ · · · .-. 14 '?1 '9/-, 1 E: S 173:3 .~? 1. '7:2: :2267./_-, 8 '.:; 1774. :2'2 (-). 6, 0 2:3 4 (:). '.7..:4 :.--.'; 1,91:2:. 7 L:,: (')... 1 F-;... 24 ]. :2: . 1 ":' L:.; 1 ,:,._,.:,'-' ='''' F'; :.2 · ~, · .,. 1. ]. :3 2--" 4:36,. 4/-, .E :32:6,. 96 E :5:9:3.04 ] ...... 962. C):3 _-- 1034- , ..-.' (..'-' -) .=. 1110. 84 .'_' ]. 187.4 C) _- 1264.65 Z 1342.60 ::" :L420.97 E 150 0.02 E 1579. :5: E 16, 6, 0.6, 9 E 1742, 5'.:.) E 1 E::25. 16 E 1 '?06. ) E 1987.0/ Z 2067.4C) - '°147 69 - 2228. 1 ::: ] 2:2:09.41 " '.-/':791. 10 - 2472.71 - 2554· 2:_:: ] 26:2: 5. :39 - 2716. :'::/_:-, ] 2797, 72 - '7.' '7; ./:, ('),. c:, .-:, ~ ~ ..... ,_, .,~ _- :_--:04'2 ~ ::'; I. :_3124. ,';, ij C:~"IN F'lF':n., I NF':. B- 13 MILNE F'OINT ALA~ KA SPERRY-SLIN WIE. LL .:,,_r-,VEYII',IG C:OMF'ANY ANC:HORAGE '- .... ALAoKA MAY ':'1, 1"""= .-' ? '3.' ,_1 VERTIC:AL c, EL. TILN CALCLILATED ALONG C:LU.=,LRE F'AGE :.7: DATE OF ._o .. RVEY MAY ~._., 1 .'.,:,.:, B 0 S S G Y R n S C: 0 F' I C: '.=;IJ R V E Y ,J Q B N I_1M B E R A ~...- B U-.. (.) (.)._,.=, KELLY. BUSFIING ELEV = 59.0¢) FT, APERATFU-~-D HARL ER T. MCGLII RE ! i-0 MEASLIRED VERT I CAL VERT I CAL I NCL I NAT 113N D I RE ..T I ON DEPTH [ EF ] H DEF'TH DEG M I N DEGREES D 0 G - I... E G T 0 T A I_ '._--;EVER I TY IRECTANGULAR C:OQI;~D INA TE'._:; VER]' I C:AL DEG/:[00.. 1'40RTH/F;.C. dJ]'H. EAST/WEST SECTIr ) 6000 4602.09 6_1. 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B- 1"".=, MILNE F'OI NT ALA, KA SF'EKRY-.:,L'"" '-' ~N WELL SLIRVE Y I FIG C:OM F'AI'4 Y ANE:HORAGE ALA'SI<A C 0 I'1F' U T A T' I 01`4 D A ]"E MAY :31, 1985 VERTICAL SECTION C:ALC:LILATED ALONG CLOSLIRE F:'AGE 4 ][3 A T E I"1 F' '..=_;_ I..I IR V E Y M A Y 28 , 1 '-Y,:,'"._, ~'~ BOSF; -' ~"~ ....... ~ ' bYI~u.:,L.L F IC SLIRVEy ,_10 B N I_1M B E R ('-/I.:..- B u - .:, (2 ¢.)._,..:, I< E L. L Y B L.It.~; H I N G E LIE V. = 59 · 00 F'F · 'I'RUE MEAoL RED VERT I L':AI_ DEPTH DEF'TH ......:,'~iJB-.:,EA,-' ~ ........ L. ULIR.:,E'*:" ' "~: ..................... L. UURoE~" '" "'""" '" VERT I C:AL I NC:L I NAT I ON D I RECT I ON DEF'TH DEG M I N [ EbREE.:, DO G- L E G 1"0 ]"A L · : EVER I TY F4EC'I'ANGLILAR F:FIORD I NATES D E G / 100 1`40 R T H / S 0 I...I 'l' H E A S T / N E '.=; T VERT I CAI .. SECT I ) 'F/1 c~O 6364.89 6:::(')5.89 9~0'0 .......... &;'425 ,' :=:0 ......... 6o6:~-"/:. ..... :-.:~ ~- ' ,-,,/: ,:,/. c.;':3. 00 64,=, :..-,, ,.., _, d4~7-, '-' , '-'_ _ 94 (30 / ~ · _ :,.: 47 4:_-: /=,~,q'" · ~ .... :,. 48 9500 6/:,07.91 6548.91 ';). 60 ('). 6668 . ,_,':' ,_,':' 66 ('). ".'?.. ...... ?,'70C~ d7oO 21 /=,671 ':'1 Y,:, (.)U 67 y...- .... ,= /-,7:-',3 F,2 F,O 42 ............. -.'~i--'4 i"."6C)' 1 '-" 4._,~ 7.49 '-'' ;/(.) ~' .-, - . . .:=, :3 02 ?]'-'"". . 4 .... :,,::, 87 ::i; 0 [50 ......... 4?_.4::3. :27 ':' 0.1 ,..,':' 470. 7.4 ('). S 0.48 4766.69 S (")'~ 1 ':" ...... z~,:,.:,~ · 'T/'-.-~ C)./-_,.,_':' 4 :::.. :::....=;,. 0 '7 S 0.40 494 L=:. 82 '._:; E ' 1"['57 ......... !50C,2 :~"" (..:, E 1 4..'5 50/':,0 ~':' ':' ii # ._ .~.. ...i E 0. d, 9 511 '-.?. . :34.:,'-' E ..... 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SL.IRVEY....MA¥ 28, ,JAB I',IUPIBER AK-BO-50053 KELI_Y BU'.5;HING ELEV, := OF'ERATOR-D. HARGER., T· F'AGE 5 5'?. 0 (') F T. Mr':GI_i I RE ' 'I- I NTERFJLATED VALI_IES FOIR EVEN 1000 FLEET riF MEASL.IRED DEF'TH MEASLIRED ......... DE~"TH ]'RLIE .:, .lB-.=, E A VERT I CAL VERT I CAL [EF1 H [EF1 H TnTAL REr':TANGULAR F:OOI-RD I NATES N 0 R T H / S 0 IJ T H E A .=, T / W E :--; T MD-"I'VD D I F' F ERE. N _.E V E IR ]' I C A I_ L. JRREL. 1 I FiN 0. OC) ("). ,=,,:, 4,5. (:)4 ,.'- J4. :36 55 :.-'. '. 4 8 '.-.?68. 1 7 1:3'P7. ':.? 1 ........... THE-'C:~i'C:FIEATTON'PRi~ji~:E[llJ~:I~i~-; ARE BC~i-~:i-L~IN--'TFiE-'iJ'i;~iE-AF THREE E,':~I't~N:~'IONAL RADIUS OF ,-:URVA:F'0~E "i;IEYHOD. C 01'40C 0., I N C. B-13 MILNE F'OI NT ALASKA F;PERRY-$:;UN WELL SLIRVEYING COM'F'ANY ANCHr'iRAGE A L A S I.:.'.' .r=', L. JMF U TAT I ON DA TE MAY :'-.: 1, 1 '-~'""=" .~ ,_-, ._.l F'AGE /:, DATE OF' F:;LIRVE:Y.. MAY ..::.:--,,--Ii:l ,_10 B l',ll_11'"IB E R A K- B O- 50 (], 5 ::.-': KELLY BUSHING EL. EV. = .5'.-7;.C:~C~, F'I-. _FE. RATI-IR-D. HARGER:. T. MCF. iLIIRE INTERF'rlLATED VALLE._--, FCIIR' EVEN 100 F-~E"F Cfi=. '..{;UB-SEA DEF"I'H MEASURED '1 " [ EF FH ]'RUE .=,UB-.=,EA TO]'AL VERT I CAL VERT I C:AL REI]:TANGLILAF? r:13CJRD I NA'I'FS EF TH DEF"T'FI ];qi'~[RTH ,'-'- I /.=,uL TH ........ EAs'r'/WE.'=-;T MIl- TVD VERT I 6:AL D IFF: EIRENL'::E REiRF?EC:'F I ON .... ' 0 · O0 O. 00 O. O0 O. 02 (:~. 02 O. 03 O. 01 759 7~'-.'"_. . O0 700 . O0 I4 . ~,'"'-,_ _ ._. '=' :.~_,_F, '--~.. ,_,,.':' ~ ';.'... 0 0 8 (]. cl., 0 0 19.. 7 6 S 10 6 0 10 5'P · 0 0 10 0 0.0 0 ::: 7.0 7 S (.,:, (] 02 · _ ._ .'~ · .... · · ._l ._1 · - . · . · 5.1:3 W 0. I5 0.0,/=, 4.4:..]: W 0.2~1 (:} . 11 :_--:. 72:: W 0.4.0 O. 14 1. '.-.-,4 W ..... (:~ . 6;7 ' O. 28 0· :34 E 1 .....'-."=' (). · .=;4_ 11/=. 1 1159. Cx} 1100.00 1 ..' --, ..'1259 ,'-GO 120C~,. O0 1364 1359. (30 1 .'_::OC~. O0 1467 1459. O0 1400. 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MC:GLI I RE ' '1'1 ' ' -I'~' I NTERF_LA]ED VALUE'.E: FL I-~ EVEN _100 FEET 01=' '" I" '"- .=,L B-.=,EA DEF'TH MEASLIRED ......[i'EF'-'TH TRI_IE .=,LIB-c, EA TL-ITAL VERT I CAL VERT I C:AL RECTANGI...ILAR C:F,_]RD I NATER MD-TVD I. EF TH DEF 1 H NIDRTH/.:,UL 1 Fi EAST/WEF:TL"I I: F":'FEF, ENI_.E' ';" -' VER'I" I F:AL E: 0 R R E C: T I 0 N --'4 '--~ '.."::' /".1 '--":: 7 ._ ~"~ ,""~,' · C) (:) :::-- 7 F). F). ' 00 ] ...... '~ 5'7 ' '--5 '...' = ~-- 128 I ' 7:3 E 777 ' 14 P' '" '--''m=':* 73 '-' '= :=: _. 4 _, 70 17 _ 144./-, 75 E 14.4:2 · : ..... ,:: OD '-"-" ' . .:, ;~(2 U 00 I m ~ ,_1 , 50 4 7 4(] fi':/ 0 0 4 0 0 0 0 0 '-' ''"'- 7._ S 1 ,:,,:, ~. ' =~ .~ ~ c, ...... · ._ =,:,. 1 9 EE · _~;'"'-'";'~ = v ............ .*- · ~ ._,~=';. O0 ............... '4 i6t.. PO .......... ~00~',.'~,4" ;:' ' ......... Z 60 :::~. 00 E ~:~'-' ':~ '-' (' ' 21 . 4 ~ .)0 · 0 0 21(.)._, S 1/-, :=:/-, .6 0 E 5566 4'35'F¢, 0C) 4.3C)C), O0 2243, 19 S 1760, 87 E ............F474~i::' ..................... 44o'e';$.. .... i 0(.)~"'; ..................... 4400~": ....... UO:: ......... ~o:=~='"'=:7~ ........ 1 ~=' "- ;=:,=, .:, ........... 1 ,:,.:,'s;s 1,1 5; 592 3 4- ~ ~';~ 00 4. 500 00 '=' ~ 0':' ~ 1 ':' = ......... 190i 11 ! -- · / I ~ ._1 ..... ~:,o4 27 b ].';'/-':' 6...5 E 1.:. :,4 1 F :1. 442.06 6 8. c) 4 ..... 67.7;:.) 69.50 73. :=:0 71,09 74.4'F* 77.72 7'i..'~. '--"-' 77 · '.-'.~:--: 6451 6,625 67'78 6971 7144 74,.-.-',,..=, 7674 .. -'='- ..'7 :, 1,77 .:, ..' 0.:,6. 5(.') E ':' ="- ":' 'R ':' F, .:] c, 4 ..... ,Y. O0 4800.00 ':' ')'-' _ · . ............ S .,_1C,:,. 4/-. E 4'F;5'?. O0 4900.00 30c)5.42 S 21 :=:6.58 E 515'~. 00 = 100 00 ':' ':":' ':' ,., ._,..._,1 64 2:_::54 (').=,, E 525'?. O0 5200.00 :2:341.94 S 2442.5:2: E 545'.-.-.'. 00 .~,4('~(') 00 '""5/':''-"- · .'=]-" .... ,:,._ :,,_,...' ,:: ::; 2621 ,_ / E 555'?. 00 5500. ¢], 0 3 684.44 S 2714.1 c'~ E 159'.':.' · 44 74.71 1666. '.-.?':.? 74.55 "17:_~:'.-.'',, 78 ...................... y~'-; "7'J 181 '-' :34 72 5/-, 1 L::85.5/:, 7:2: · ';:"2 19/=,0. :2:4 ....... 74. '77 ................. 2036./_-,& 76. :2:2 2-I l 5.70 79.04 CONnCF/, I NF:. B-1:3 I-LINT I'11 LIqE -' ] ALA.:,KA · :,F ERRY-o_II',I WELL .:,_IRVEY I NG F':OMF'AI',IY AL A.:,I'...A ANF':HORAGE '-' '" JlA lire .., lEaF'.-,. SLIR VE Y... I':IA Y_ ""'-' L. UMF-: :' ...... ;'"i':L ]'AT ........ I Ul',i:' ...... DA'TIS MAY :.::1, :1.,~,-,=.. ,:,._, ,.lOB NI_II"iBEI-R AI-.':'-BA-SA('):':3 ...... F'AGE 1 ';785 KEI_LY BI..oHING...IELEV .... =.. 59. C)O FT.. r/F'E:RATOR-D. HARGER, T. MCGUIRE .=,L B-.=,EA DEF'TH I NTERF'OLATED VALLE.=, FLH EVEN 100 FEET J-IF '-'1 "'- ] RI. E ~:,LIB-.:,EA TOTAL I~" I I .. - '""* MEAoLIRE~ VERT I C:AL VERT I C:AL RECTANGLiLAR r':F:IJ]].RD INA TE.:, MD-TVD ...... K~EF"'TFi ................................ DEF;TH D'~'J51'H ....... NOR':i' ~'/~;iEi'u'F:I4 .......... EA:-';T /WE:ST D I F F EREN_.E VER'I' I.L-:AL ........................ . C: 0 R R E C T I 0 N 7853 565'.'.'?. 00 5600.00 3800.10 S ............... ~'6.~:"0 ............... E~ ?k'j_;;:, ~ i:iO ..................... 5 Yb'O ~' 0 i) .......................... !~:":~"F::i-:"4:Y- ~i ................... ~'8':~,'i:}' ~' 5 6' 'E 8210 585'.-?. O0 5800. O0 402'?, 72 S 27'..~2.54 E 8385 5'.:/5'..~. O0 5900.00 4141.43 S 3083.73 E .............. i3 ~C:.'i ............ ?~.05'.:?'~" 00 ............... ZjO OC)-:' '00 ............ 42'~ 2'~-':~ ~'-"i~ ............ 3176 :3740 /:,15'F~. O0 /:,100. O0 43/:,7.31 S :3270 8':.? 16 /:,259. O0 /:,200. O0 4475.65 S 3:36/:, ':7254 645':?. O0 6400.00 4680. :34 S :3545 '..T~41 '.~ 6559.00 ....................... 958::: /:;659", O0 9746 /:,759.00 .' 4-? E ........... -.2'Y'?-i'i-'/'::22 ................. 7 3.72 74 E '.'.' 7'-? ~ ":' 9 64 07 ~ d-- . -- m ,m~. · 6500 00 4778 03 :--; :3/:, 3:3.04 E 2:--:/:, 0 11 64 ':' 1 · · . · · ,_l ' -/:, ~ L)~"L) · U"~U .......... 4,:,'~' 7 ._F,. ~;5 '-?':._; o ........... .:,'s-7 ..'.'-'(), 44 F ........... .._'SP6a '.... ~, '.'70 64.80 ~700.00 4'.-771 ""-' .... · ....:, .'_:; :3806.51 E ~ 987. :::~ 6 :-2 9 A 9'?04 6859, O0 6800. O0 5O6:3. 1 '2 S :':::-'::--:6. ~7 ..E ................. :::!045 ~_~:.-_'.' ............. -'~---~ ........... ,~'~:F ~ --~ ............. F'-=: : '; ................ ~:-~_-=:' '-,s=-' ;~. ...... :~:T:~/..-, .1. uu?~U G ...v._, ... L)(.) 6 yuU · UU ~, 1 ._,._, · ,:,U c,.:, .. :,.... C)A_ E ._, 10 ~., 37 55. :::/-,_ ,.... 4,:. ':; 4 (') 37 0'-? E :3157.20 55 8:3 10216 7059.0 C) 70(')C) 0(') .:i,'-' '-' '"'" . · . . ,'-,._", ._ . . . . · .... .=i'-' /:,6: - . ...... .-- ....~'. ....... 5':' · _F'._'-'.'_ 10:374 715'.'? O0 710£) OO ._.:,44. S 411:_'~. :::4 E ::::ZlS... 7 · .... '-'~< ....... :1:05::3 ......... ?:259':"(i0 .......... '~200-:'0¢F-- ......... ..,: ),"':,+.+ .~; '-':-"5".._-, .-. ;'::.:, ......... '4 la:l.. . 0.=;_ _ E :::274 .67 5"?. . 106'.'72 735'.'?. 00 730C). 00 ~="::'-' '-'/'-' '-' .... "-' 5'?. 1 '1 · _ ..,._ ,:,. 11 S 4.- :,,:,. 26 E .:,.::.:,.:,. 7 :--: 10720 7376.11 7317.11 5554./: ._, S 42:--: 1.47 E 3:343.89 10 11 ]'HE CALCLILATION F'ROCEDLIRES USE A LINEAR INTERF'OLATION BETWEEN THE NEAREST 20 FOOT MO (FROM RADILIS OF C:LIRVATURE) i=;F'ERRY'SI IN · {.~ELL '..':;URVEYING COMPANY ANCHORAGE ALA~:;KA C El N El I'] F'I, I N C · B-13 MILNE F'OINT ALASKA L. JMF U1 AT I ()N [iA~FE' "4 ':'~ '-' ~- MAY ,_1, 1:.,=,.:, F'AGE 10 ,-'l" - 28, ':)'-' ~-' DATE OF .=,_IRVEY MAY 1.-.,=,._, ,_IF)B r',II_IMBER AK-BO-50(')5:2: KELLY BUSHING ELF_V. = 59.00 FT. OF'ERA]'OF;;-D, ' ~'P " HAl'-,. _.,ER T. MI_-;L--iU I RE INTERPOLATED VALI_ E.:, FI_ R .:,F EL. I AL .:,1_ F',VEY PO I N'I".::; )"RULE ,-' ,-I ' .=,I_IB-._ EA MEA.=,LIRED VERT I C:AL VER]' I CAL ..... DEF'~'H DEF'TH ......... DEF'TH ' TOTAL RECTANGLILAR L':OE~RD I NATES N 0 f;:TH / SI21jTF! ........ EA S T / WE F; ]" MAI:;tI<ER (')5 E I<A 24 E KB '--2 I:- ; .3 E KC (')5 E KD ....j Ii--. LA 81 E: LB 5:247 4174.29 4115.29 2(')24.46 ~:--; 1620.19 I-_- o,.~=' ~ ~./_"~::74-', ................... 4. ,_, 7 ¢. ):5 ..... ~ ......., ..~.F"7 .......... 4._,~:~ ........... 1 1 ,-:;;;~7 ........................... ,.' ,' 57~'=":';~ ............._,._,e-F..~-";=:-.:, ............. 1: ..... 76.:,'-" '" ~, / (J E- .... '-"-'¢: "]'-' 1.,:,. 1":' E 561 ~ 4.:,,:,", 72 4._ ..7 72 227:_--,' ~'-" ':' '7,-,(') %. · · · "]/-/--'-" - '~ '~=" 28 '=' 798 .... ,...., 441 ~. 2:--: "::'312 57 ._, · +~..-,'+. ,.. . 1 . E.'?. · -i ,-I i-i · =;67'-"" .....44 ..' .,::.. 7o 4o'-'/:,.:,'-', 7:3.... ~3.~:24 , ;'-'5 S 1 :-::0":", . 44 E 57' 15 4442 :=:'-.";' '":":"-' '..R':".' '-'::":' R 1 16 ':' 4 ...... :, 1:_--:1'~" 74 E ,,.T4 .-, ,.:::. ,-, ,,..: ..:, r'- 5,...-._, 45(:)4 17 4445.17 24:":: 1:_--:A '-' 1,=, :,..., 4,4 ,- '-?.=,' ' '" '-' ~- -= 0 4 :--; :3 7 _~ i 0 4 F .: .. o o & ~ 4 8 0 'l /-, .~ :q'-.-; · 0 ~ . · .... ~ 'Z: '" ,_l 1 9678 ^7_ ~ &. 7~ ~.&._=,7_. 73 4..:,8n.. . 94 ._.':':3770. n2. I 0 ~ 81 7036.39 6777. 3'-.-,. ,_,,-..-7.='-"-' :-% ::; 4020. 1022(') 7(]6 I · 44 7002, 44 5251 . (.')9 S 403:~I. 172 E MA NA NB NC , NIl NE OA LINC M-19 . K I M K- 1 B / M K- 1 ....... .................................................. i~i~,;ERRN;'L.'siLIiN/""I~ELE L~URVEY!NC4 coMF'~INIy F'~GE 1 1 ~NL. HUR~L E AL~.=,F..A '"1 " '~":' ':t'-' ~ CCINC,2:I3, INC. DATE OF ..:,.IRVEY _..MAY 1: ,:,._, B- 13 COMF'LITAT I CIN DATE MILNE POINT. FlAY 31~ 1'-' '-' =;',:, ._, dOB NUMBER AK-B~]-~O0~:~ ...... ALASKA KELLY.~ BI_!SIgING. ELEV.. = 59.00 FT. OF'ERATOR-D. HARGER~ T. MC:Gl_lIRE I "" .=,F EL.I AL t=;I IRVEY F J INTS; I'NTERF'OLATED VALLE.=, FOR '"' "' __ ... 'F · =,UB-.=,EA TOTAL TRUE '-' "' MEAoI_ RE[ VERT I C:AL VERT I CAL F~EL. TANb_ILAR F:Fii]RD I NAT E.:, ......... DEP]~H [iiEF;:TFI .............. DE'F'TH NoRTH2SOLiTFI ...... EAST/WFST ....... MARKER 1.... ~...rr-"'" '~. 7o77,.._. ,. .=;7 70 16. ._7~ 5'264. ,:.'-'c.) S 4049, 5:3 E ...............,fi',"~":~'?4,..... .................. ............... '~"~ "FP-i '"-':~: :'~ 7044.,:,.-,.-.,.., ~;,. ,:.'~-;;5'~:c.. ,.,, ' ';=,~:' '"'~.~;,:, .., . ............... ~'~i' 7 ¢~, ""~,:, :, E' 1 ' '-' ' ' 7053 1 ':' =--',,,,-, '--' r. ':' 0 o 00 711 '."' 1 "-' ._,.~.-.- ~- 4077 65 E 10:--;79 7161.79 71.0'..'.' 79 5'"'~'~''-"-' ':' ... . ._._-,-,.,. o,: .... 4115. '-"J'-."~ E ................! 0 ,-1.1 ..................... 7 7 ! -a;~ ,:, .., ....... 6 ~ 7 ....................... 71 :~' ..' 6 ......... c-. ; ...................... 7 ~':;';';"'"~ ._, .:, 7 o. ............. 47 .:, ;< ............. Z I. ........ .1_ ._ '~-/.[ ..... 4 ._ ':i "-~ E ..... 104:_q4 719/., 3/-, 71 :--~7:2~/_., 5""-" ..... ._ ..-,,:, 0· 81 ~5; 4142 ·/-., ,_,':' E M~!~..,.:2 B/I I1'...-.~ .:,I_II-,,VE Y DEF'TFI . H..t.B,. ~_.~_[.? 1_-8 ~T~ I~1 [/L-,:, 1 (. 44c, 72(3..=,. ., 15 7146 ,1 ._, =' _ _ ... ':'":' S 4149 4'7 E L-9 J. 0;4,.,,.," ..... ~"'= ............... 7..o.-.:5 '~'-0-. ,.,._,-'-~' '~- .................... 71,_,0. ,_,..,e: '=--'=-= .................... ._,a-.=.;',~5 ......... .-ii' ~"~,7 ..... ;5-._, ............... 41 ._,,_'a :5 .... ;5 7 ..... E ~: ................... B/L '£"'5.. 1 '"-=' ="-' .=;' "~ .=""" ,.,,.._,,:, 7271. 15 7212. 1 =' " ._, .. ~._ .:,. 14 .':, 4 2 0 0.4:3 E L K- 1. · ] ~' ,-, -" -! '_':, ,Z,'":, ?, ":., '7 .":,...2 .':, 52 ~ a "7 ":, ,-, 1 ,...,,=, z . ~ ...:.....,. ..:. .............. :, 1 S 4. 216.9 :--: E B / L K - 1 .. ..................1 O' .......................... 677 7 ,:,:-; 4 ';=? . 0=-,:,;'; .............. 7 .-"~;"5.~ 0 = ..... O: ,:,'-; .............. ._,a" ~'.~., ;,:, -"._, .. ....... '= .:.:~.' '"-':" .......... 4:260.60 E B / K I 10726 7379. :::~ 7320. - -' =='?';'"' '-'c - - :::::, 4 2 8 4 ':":' ,_,,.,,. ,>..:, .)._':; . ._,,_, E TD qK-BC -SOOSZ i-i b.'.JC, sc ' 1072~ --CC' C. CC SOC. ;, r~q' ,_.~. L'C ~ . _ '2.'03 4000.00 SCALE :- i l~Ch iC 2000.00 / 20OC. £ HiLNE ~O!Ni ~ONOCO. B-l~ M~ 2~. qK--BO-SCC~ 10726 [ I ~ I 2,003. ,,3C 42:1,3. CG ..,J~Nu,_.u, iteL:. COMPUTATION PAGE NO. 1 PAD B, WELL NO: 13 4TH REVISED PROPOSAL TIME DATE ~ILNE PT , NORTH SLOP~, ALASKA 08:53:48 1 = ' = ' ..,-MAY-8~, ' ~RUE ~EASURED DRIFT DRIFT VERTICAL VERTICAL '='~,_IBoEAI ~' R E E: T A N G Il_ L A R C L 0 c.._, Li R E DOG LE~ DEPTH ANGLE DIRECTION DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIREC:TION SEVERI'F~ FEET D M Ii FEET FEET FEET FEET' FEET D M DG/IOOF' O. 0 0 0 0.00 0.00 -59.00 0.00 0.00 0.00 , 0 0 0.00 500. 0 0 0 500. O0 0. O0 441.00 0.00 0.00 0.00 0 0 0.00 600 '~ 30 S 37 E 59'~ 'p7 2.1:3 :4.0 '27 1 72 S 1.:34 E 2.18 S 37 :' ... · ~ .......... 0 E 2.~A 700. 5 0 S 37 E o~.75 8.72 640.75 6.8c*, S 5,35 E ,_,o,72 ~'=; 37 M~_. E 2.50 800. 7 30 ..,'= 37 E 7'P9. t4 1';*,61 740 14 t5 48 .=, ~' 1Z~,03 E 1'~,61 S :37 5~] E '~' r~n 9<-) A 10 0 c. 37 E '-'¢, ...... o ~ 7. ? 7 34 , :=:_ .._? :=: :38 · :-? 7 27 .50,.,c' ..-1'-', ~:/--,_ E ,:,4~' . ,=,'" ~.'-' S 37 ,.,= cj E ..~.' . 50 1000. 12 '-~ c' 'p 96.04 :~'~ '"~':' .... ) :5; :37 E .-4~ ....... .... ,4~_"",:_'-: 37 E ~_, . · ...._i mi · .~-'l ... 1100. 15 0 S 37 E lC) 92 17 78 · ' ' · - · · · · · -. m . . .,i - ~ , 12 <'Dc). 17:3<'~ S 37 E 11 '-"--, - - ,=,; · 17 10 A_ · 07 11:30 · 17 ,..,'='..,":' · 77 ~--; 65· 07 E 10/-,_ · 07 ._,¢' 37 ._,U = ' E .=':' . 50 1 .':: 0 ¢) 20 c'D '.E; 37 E 12 ::: ~: '-'.~ .:, o .:, 224 ':'.~ 84 78 ':' o ._ 1 i 1 1 - · - :1. 37 5<'D E 2 SO -- -- · · re_m0-. · 1400 .... · -':Z :::<3 :;; 37 E 1377 ')= :37. c .... , 174 4A l°l"" 05 1 78 '.--; ~ 107 01 E 174 46 S 3'7 5c'D E '.-' ~ ,i # '--' · i, -- . ,l.. · _ . :l 500 · 25 0 S 37 E 146:3 · 57 214.7:3 14 C)':?, 57 169 · 58 '._-';" 131.72 E 214.7:3 '.--; .7:7 50 E 2 · 50 1/:,Otb 27 3c)_ .=,'" :'-.:7 E 1 ~':' , ,'?.=l.._ '.'.'~'=, ,:,'~ · 5:=,, ,:,= ...... , .......... : .... 14'P':.'?. 2F, 204 51 S 1 :-=:4 E '.:'.~,:~ ; .., S :37 50 E '-' ?, m · -i .,.,.~.. · ..' · - . 1700 :30 0 S 37 E 1/-.4.~ 92 :307 <')~ 1~'-' 242 50 S ¢"=' ':'~ ¢' - - -,. ,. _ ._,,_-. 6 ,9. 2. · 1 ,.,I ,__l '._,._ E :::_ 07 · f'D..~_ .., 37 5_ <'D. E ,-';" · 50 1 :--: 0(') 32 :::(') .~ :37 E 17:31 40 7-: ~:~ '.:,'-' '-' ~'" '~'"" :37 5 ' - - - .- ........... ..... .. -... 1672.40 2:33.4/-, S .$,.? A 16 E _,.. ,=,. .. ~. :3 <.) E2. ~_ <'). 19¢D0 :::5 c') '.:"; 37 E 1¢' = .':,Rz~ -':, · ¢' ?_-:7 50 E Z,50 - - .-,14 · 54 414.. 47 1755 ._,4 :2:27 34 c. - .... , , .., ........ ..4 E 414 47 ,., 2 000 :37 3 0 c. :37 E 1 o.:, ~ 18 4 7:3 6 0 1 '=' '~-/- · .-, - ,-, ...-. · ,_,...,.,, 18 :374 · 0:3:3 .,_';' 9. c').. 51 E 473 .6 <'). S :37 50 E .,_'::' . F,_ c'D. 2100 · 40 0 '-E; :37 E 1 'F/7:3.1/_-, 536. 1 ~ 1 fY 14 · 16. 423 · 46, S :3's.' :3. 'F./0 E 536 · 1 '.-? '.E; 37 50 E 2 · 5 ¢) 2200 42:3 c: S :37 E '-, o zt o :34 602 12 ! '.-.-¢ 8'P :34 · - ~- --- ,,-, . · . 475 · .. =..,._-, ~' S :'~, .... A'-? · 34 E A_ <'). 2 · 1 ._'T" ._,~ :37 5 c'). E 2 · F,_ 0 2~¢D~'), 45 CD S 37 E -.120.57 671 '-"/- 2CD/-,1 57 ~::'.('D 14 c. ........ 411 76 E /_-,71 2/_-, c- .7:7 50 E 2 MO · . -- · - - . · ..~ · · ._, _ · ._ 2400. 47 30 S 37 E 2189.72 24'F/5. 4.9 ._2 S .7:7 E ,~:z.-'5z,45 61:34. 4;~ 52 S 37 E 4630.00 'P722, 4? 52 '.S 37 E 6':-.'10.00 10143. 4;~ 52 S 37 E 7181.00 743.49 2130.72 587.1:3 S 456.06 E 814.87 2193.45 643.56 S 4.?]$~ · :35 E 36:35.?1 4571.00 2871.51 S 22:30.30 E 6:341. 20 /_-,851 . 0¢) 5c'x'~:. ...... ('DY-, '.E: ,.,':"='°'--',_,,_, .. · 75 E 6662.75 71 .-.-. '~'':' c'). c) .=,,...._ _ ~_ .'s'A'--' 01 S 4('D. :=:_ A.. '.-]. g. E 743.4¢¢ :3:37 50 E 2. 8_1.4.87 S .7:7 50 E 2.bO 3635.'P1 S 37 50 E 0.00 6341.2 c')_ c.._, 37 50 E ('). c') 6662.75 S 37 50 E 0.00 10483. 47 52 S 37 E 7400, O0 6'P22.60 7341.00 5467,23 S 4246, 39 E 6922·/--,0 S 2:7 50 E 0,00 FINAL CLOSURE - DIRECTION: D I F;TANC:E: S 37 BEGS 50 M INS E 692'2· 60 FEET Eastman / -: Whipstock l Suggested form to be inserted im each "Active" well folder to check for timely compliance with our regulations. oPEEL~TOR, WELL NAME AND NUMBER Reports and Materials to be received by: Z- ~-~ Date Required Date Received Remarks Complet_ .i~o~n Report ~'~ ~ ' Core Chips Core-Description Inclination Survey : Directional Survey Drill Stem Test Reports Production Test Reports Digitized Data,. L.FJ.04 GEARHART INDUSTRIES. INC. CUSTOMER o~o~o. T~C_ FIELD -I% NOR~ SLOPE ALASKA Well Name MIIN~ POT_L~ UNIT~-(~ County State Type-of Logs Distributed~L{2~~,~%~, ~L Date %~0.~-~ Date Job Ran ~'~G-~- ~ Blue Line ~ Sepia Pre-Fold ~ Rolled Logs mailed to: COMPANY PERSON ADDRESS AL/~KA OIL AND GAS iAF~T,T,T~'rvi V~ .AT,T,lqN ~)~.. 3001 DORCUPINE DRIVE CRRR# PRINTS MAILED FROM DISTRIBUTED BY TESSIE HORNBECK 2"/l oo '/ TYPE iDA t... TDF DEPTH B~0~0M DEPTH 5"/100 TYPE -lq o'~ Please date and sign and return in the enclosed self-addressed and return to Conoco. NO. OF LIS TAPES SIGNED DATED RECEIVED OC{O / BBb ~Alaska Oil & Gas L;o~ ........ Anchorage GEARHART INDUSTRIES, INC. CUSTOHER FIELD ~~ Well ~ame MII_NEPOIN~ UNIT County KUP~ State Type of Logs Distributed~)\~. ~ 0-~)~\o~, C.~R:Q~?.~_~, Date Date Job Ran....S-~V-~,q-~S Blue L~ne I Sepia Pre-Fold Logs ma~led to: COMPANY_ .~L,O.,,t,~ '~.;_~ '--A- d~ cUD ('~ Rol led PRINTS MAILED FROM GEARHART INDUSTRIES DISTRIBUTED BY TESSIE HORNBEQ< 2"/100' TYPE DEPTH ~-\~ BOI~OM DEPTH - (~b SD- \on bn 5"/100' TYPE Please date and sign and return in the enclosed self-addressed and return to Conoco. ,o. Anchorage N LOCATION. IN SECTION FROM. $. LI~[ FR{~ W. LIN[ 790' 920' 979' SEC. 18 SEC. 19 · ii i STATE PLANE CO-ORD$. NORTHINGS FASTINGS ii ! ' B - II 464' 6 ~ 023~586.20 571,864. 4T 765' 6 ,023,888.56 571,992.42 $32' 6 ,023 ~655.07 :}72 ~052.7T MILN[ PT. U~lf? LAGOON SCALE IN MIIIrS CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT NOTES: I. S. TA'TE PLANE CO.ORDINATES AR[ ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. LOCATED WITHIN SECTIO~ 18 8, 19, TI3 N,fllIE~,U.M.~AK. GEODETIC LATITUDE 70028' 29.019" N. ro° a.' ~ ,9~1" N. ?0° 29' 29.688'N. POSITION LONGITUDE 149024. 46.703" W. 149°24' 42.854"W. 149° 24' 41. 146" W. DATE 6.2,85 6.2, 85 6.2, 85 J.B.S. CHECKED t J.B. $. J.B.S. IrlE LD BOOK 21 ' 85 ~1-8s 21-85 STATE ALASKA ALASKA r~ AND GAS CONSERVATION CC-'MISSION MONTHLY REPORT DRILLING AND WOR OVER OPERATION$ · Drilling well ~ Workover operation [] 2. Name of operator Conoco Inc. 7. Permit No. 85-93 3. Addre~ 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21348 4. Location of Well FWL, Section 18, T13N, RllE, U.M. 6. Lease Designation and Serial No. ADL 47438 at surface 532' FSL, 979' 5. Elevation in feet (indite KB, O~:, etc.} 59 'KB 9. Unit or Lease Name Milne Point Unit 10. Well No. B No. 13 11. FieldandPool Kuparuk River Field Kuparuk River For the Month of May ,19 85 12. D~th a! ~ ~ month, fo~t-~j~ ~iiled, fi~ing jobs, directional drilling problems, spud date, remarks Spud Date: 5-15-85 Drilled surface to 10,730' during the month Depth at end of month: 10,730' 13. Ca~i~ o~ Ain~r run a~ q~anti~ie~ of ~mmt. results of pressure tests Run 156 jts. 9 5/8" 36# K-55 BTRC csg. Pumped 829 bbls 12.2 ppg. Artic Set III w/4#/sk Gilsonite, 57 bbls Class "G" 15.8 ppg. w/3% NaC1, .2% D-46. Ran 265 jts. 7" 26# L-80 BTRC, csg. w/float shoe @ 10,461'. Pumped 58 bbls 15.8 ppg Class "G" cmt. w/.8% D-60, .25% D-13, .2% D-46, 396 bbls 9.6 ppg NaC1 brine. 14. Cori~ ~es~roe a~ ~f d~iotion Sidewall cores taAen-at 5588 - 89', 5625 - 31', 5664 - 70', 5682 - 88', 5833 - 39', 5933 - 39'; Attempted 41, Rec. 35 15. Lc, g~_ run and d~[h whe,-e run GR-SP-DIL; CNS-CDL; 2500' to 6072' GR-SP-DIL 10,730' to 6127', CN-CD-caliper 10,730' to 7865'. Gyro survey 10,300' to surface. Run CCL-GR 10,330' to 9900' GR-CCL f/O' to 10,730' 1 6, DST data. perforating da'a. shows of H2S. mJsceJJlaneous data None 41aSka Oii &A~,Gas- Cons. Commission 17. I hereby certify that the fore~oing is true and correct to the best of my knowledge. NOTE--Fieport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate Rev. 7-1-80 ~~ .--._- - ': 'f GEARHART INDUSTRIES, INC. CUSTOMER 0 '_-' _ .-~- -. . . . .... . : ~-~,-._:. - -:.;~.~-:. ..... ..... . , . -i - .'~- -. ...... . '- ,'1 -" Type of Logs 'OfStributed ~b~~" "O~L '~':C~L[~~a~e' ~:~ ¢ [' a~ :Date Job Ran ~-i~-~.~~?:?:.:.'~Blue L~ne ~ Sepia P~e?Fold & Roiled · - L-_ -'-'.. :~-' ',:~.-.~::.'~:.' :-.: --.::~ :--:t~.~:.t~ ..~-~--,.:~j;_:::: ._~-::: :.-._:-~?~__: -~: .~ ::~-' :~-J.~ ": ~_...:: :.:' ~- .:..t~ ~... :~_: ...:-~::~ .:..?"- ?~m~;:~j~?'m:..:' ., Logs 'miled",~°:'.~':~-: ' COMPANY ~a'~~ ,'~'-' ~ '~'~ ~'-_,:'-."z-'~'~m?;:f~.,~:":' '-~' ~.~,~.: ¥.- _ .:_-~ , :-~._ .-:~:..--_~ :- .,-: -~ :.~:.T:~_..7-t~:..~.~_~.~-.:::~.:__:~.~-. ~/~,~-~:~-_ ~'/_~....~.- ~:_ L,_~ .,_ ?-~:~.%)?. ~,, .... :. ~..: ~?-:_~ .~., ----' --.:- ' -' .~ ~:--. :~ --~ -~ :--_--'-? - ~'.:':?~:~,~:'~:::,'~.~-:~:.~-~;~t~- :~:::-7: .:-.: _-- "-.'" ~/' -- ~:-- '-'. ::: ~'; ~ , .~::~ -~":-':-~'::~;- ~::"'~-': ' '- ' 2"/100" ' '~-. '-.~. -- TOP_ DEPTH ~-':-~:''-' '. BOSOM DEPTH F~-~-'~-':~':]:~?::];:;'.~'-'~:- :;~-- T~E '~-: :- ::: ];'-;,..': -" '~ -:~::--:.-'-' '":':/':~'.::' "" "-;-:',~'" .: . ~,::-- ' ~:~ - ~ .:t~~: ?~--: .... - -%:,~_~::L~?~-F-~?:~ .-~- ~ ":~~:~ ~'-~ ~D.'-_-~-'~"--¥~D/~.~ ~- '/ --.' I -"::::.-:_. --._~ -_~ .~-::..~---:_?~?~T.:::.-_-t..:.--~-:--t--:-~/:::::-:F.:~-;./.-,:..:~.~ ~ ..... ' ~ . '.. ~ - 5,,/~oo'-:::. '-?~:~-~::-':-':.:.':~:..-__~':/_~t::?~-~?~/-~;:;-.:~' -.:~-:'-;..t' ~:,'-,.--:..:~ ,:.'_., .~.:;- _-- '; . . .;. · :~~o.~ - /~---'?-'::'- '~ 5~b:'::~:: ~ ~~5 :~ ''''' ~ D~o :, :~' ':._ - -.. ~ ~~---.-_ Ds ~'-~--~:; .';.-~ ~5--::- "-- ~ ~ ~o/:;-:~-:~' Ptease d'~te and s~gn and return in the enclosed self?addressed and return to cJ.oco ' ~~ 0 o?e~-~2'd ~ -/m ?¢z~· - · ' . · - :'--~-m~_.¢.:;_:...... - '_.: . ,_'. '~ . .,... :::' ." -.. '.. ' ' :-- "- :' "Ap' S "'-:-::-t:~"' ~'' ' ' ' -' "siGHED ' m HO.._OF LIS T E;' "::'".: : · ~ .- . _ ,d. ,,j ~_~, ~yy~. .... -. '~. ~'-.~l%~a O~:t &.Gas Con~.'COm~ssion ................... · . ..Anchorage MEMORANOUM State of Alaska TO: THRU: ~ALASKAOILAND GAS CONSERVATION CO~R~ISSION C. ~.~t ~terton Lo~mie C Smith ~ ?~ Commissioner FROM: Doug Amos /~--~" ~-*) SUBJECT: Petroleum Inspector DATE: FILE NO: TELEPHONE NO: June 4, 1985 D. ADA. 18 BOPE Test Conoco's Milne Pt. B-13 Well, Permit No. 85-9~, Kuparuk River Field. Mpnday, Ma~- 20, 1985: I traveled this date from Nabors Rig 26E to ConOCO'S Miine"P~ti~-B-13 well to witness the BOPE test. Tuesday, May. 21, 1985: The BOPE test commenced at 9:45 pm and was honci~ded aT' 11:30 p~m. There were no failures and I filled out an AOGCC BOPE inspection report which is attached. in summary, I witnessed the successful BOPE test at Conoco's Milne Pt. B-13 ~ell. Attachment 02-O01A(Rev. I0/79) O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well . 5 ' Location: Sec Drilling Contractor Representative Psrmit# - ~ ~ ~./~Casing Set · Rig # ~ ~ Representative. Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams ~ ~ Blind Rams c~ Choke Line Valves H.C.R. Valve~''~ Kill Line Valves/~' Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure %.~6D psig Pressure After Closure !~0~ psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: N2 ~1~. ~i Controls: Master Remote .~O~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves Test Pressure Test Pressure Test Pressure Test Pressure ! Test Pressure No. flanges Adjustable Chokes Hydrauically operated choke Test Results: Failures Repair or Replacement of failed equipment to be made within. min__~_sec min~__sec Test Time \ .hrs. days and Inspector/Commission office notified. Remarks: Dis tr ibut ion orig. - LO&GCC cc - Operator cc - Supervisor Inspector May 10, 1985 Mr. J. R. Hand Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re .- Milne Point Unit No. B- 13 Conoco Inc. Permit No. 85-935-$~ ~x~ ~3~ Sur. Loc. -6~'FSL,~'~, Sec. 18, T13N, R]..1E, UM. Btmhole Loc. ~, tq~3-Ul~L, Sec. ~q~_, T13N, RllE, UM. Dear Mr. Hand: ~ ~ ° 1= $~ 1¢'/=la-t... $,c. ~ Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many.rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the-regulations promulgated thereunder (Title 5, · A!amka Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. James Hand Milne Point Unit B-13 -2- May 10, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~ C. V. Chatterton Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~fISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower7 John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 May 6, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-13. A $100 check is being submitted with the permit application to fulfil], the permitting fee requirement. If you have any questions, please call Jim Hand 564-7600. ~hn R. Kemp_ anager of Alaskan Operations JRH/vv cc: MP B-13 Correpondence File RECEIVED MAY 0 8 1985 Alaska Oji & Gas Cons. Commission A/Ichor'ag8 STATE OF ALASKA ALASKA ~ _ AND GAS CONSERVATION CC .¢IISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OILx[~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L_~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street~ Suite 200, Anchorage~ AK. 99503 ~) ~ 4. Location of well at surface I~ t~ ~'~ ~.. 19. Unit or lease name ,.'~ ~"C/ , .1~~ Milne Point Unit ~ FSL, ~' ~ Sec 18, T13N~ ~, U.M. At top~f ~ro~sed producing interval /~ ~ ~ Well number ~' ~, ~FEL, Sec 19~ T13N,RllE, U.M. ~8 At total~ ~d p~h ~Z~ ~ ~- S~ ~88 ~ ~ . W~ ~ ~ *~O~1 11. Field and pool serial no.'~af~8 ' ~Z ~/~/O~ 5. Elevation in feet'(indicate KB, DF etc.} ,' 6. Lease designation and ~Oh ~0~ ~ ~ 59' ?ad 2b' ~ fiTb38 ~u~ruk R~ 12. Bond information (see 20 AAC 25.025) Type ~aQ~e~ Surety and/or number 8086-~-5~ Amount ~200.000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi NW of Deadhorse miles 217' @ 10750' (T D ). feet ' 580' 16. Proposed depth (MD & TVD) 17. Number of acres in lease t~ feet 10~ 7~' MD 7400' TVD 2,544 19. If deviated (see 20 AAC 25.050) ~~20. Anticipated pressures KICK OFF POINT ~ feet. MAXIMUM HOLE ANGLE~(see20AAC25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program well B-12 120 feet 18. Approximate spud date .... psig@ Surface ~_uu 59: .... psig@ ft. TD (TVD) 3 IUU SIZE Hole / R~" Casing Weight 13 3/8' 48 9 5/8' 36 7" 26 CASING AND LINER Grade Coupling Length ~-/,~ ]~'T D ] ~ I K-55 _nTRS I 6238 ' 22. Describe proposed program: SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD MD BOTTOM TVD (include stage data) I 35' i 35' 35' ! 35' I I 35' I I I (~115' I 145' 6273' I 46~0' I !0750' i I *!700 sks Permafrost Cmt -+280 sks Class G ~60 BBL Arctic Pak Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River field. Mud system wil; be non-dispersed, low solids with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20" 2000 psig diverter will be installed on the 13 3/8" conductor for drill- ing the surface hole. A 13 3/8" 5000 psig RSRRA BOPE stack will be used on surface casing. Pressure tests will be performed as per State Regulations. Maximum anticipated surface pressure was based on a fluid column,at T.D. of 80% gas and 20% oil. Casing will be pressure tested to 1500 psig. B No. 13 is no closer than ~o B No. 12 T~'-B~ll w~l-t--pre~i~s~~om the B-1-2-well~~-s~ut~ast~q-r~ct~ton. At a depth of ~4~5~'-i'~ will come within l~kT' of B-5 which was drilled in an easterly direction. Arctic pak will be placed in the 7" X 9 5/8" annulus after disposing of test oil and excess drilIing fluid, The perforatin§ and completio! assemblies will be run in the well before releasing the drilling rig. the well flow tested once the drilling rig has moved off location. 23.1herebycertifythattheforegoingistrueand correcttothe best of my knowledge SIGNED The space Samples required The perforating guns will be detonated an~ []YES ~0 Permit number DATE May 6, 1985 Mud log required Directional Survey required I APl number OYES /[~,NO I [j~'YES i--IN• , 50- 02-~-9.[5¢~ Approval date ~ ~-~05/1~/85 ) SEE COVER LETTER FOR OTHER REQUIREMENTS ~ ).~ ~ ~' I OMMISSIONER APPROVED BY Form 10~.01 Rev. 7-1-80 DATE May 1<~, 1985 by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al- Milne Point No. B-13 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM Ae The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Be The 9-5/8" surface casing will be cemented with ±1700 sacks of Permafrost cement followed by ±280 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±285 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6760' subsea TVD. III. FORP~TION EVALUATION Ao Wireline logs for both the 12¼" hole (from casing point to ±2500') and for the 8~" hole (from T.D. to ±1000'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. A~asKa Oil & G&s ConS. Ye A low solids non-dispersed gel/water mud system will be used from 1000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 6273'-T.D. DIRECTIONAL PROGRAM The B-13 well will_b~drilled to a proposed KOP of~)~', then build angle in a south ~ east direction. ThB. c~osest that the B-13 will come to another we,l~bore is £r~ ~r~%~_~tc ~QP, where the proposed B-13 will be ~ southeast of the existing B-~-~ well. An MWD tool is to be run while drilling for surveying purposes. Final hole angle will be =' °° * The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 30~-~-, a Sundry Notice will be submitted. · FROU' $. Liked I~fE~Vl W. UNE '/6,5' ' 552' ~T~T£ PLANE: CO-ORDS. NORTHINGS '7¢~,o' G. az3.'7oz. 69 ! .079 &, 0z3 65~36 -950' lb~-/:- - (,, mz'3.4Z~. ! IOO8, 6.0z=~, 540.2S o CASTINGS 571. ~'54.'7-.I 572.05'Z .94- 57Z .022, 6& 57'Z, !13.4S 572. o$~. LATITUDE -'/o'. z2,L 3o.! ~,s ~ 7o'-zZ-5o. sS&~ LOt~GI'T UDE - 47. 56O ~o "21. !~ 9'- Z4'-40 255u/ '-u-%- 84. II -=_,-gA )1-::3.$~ C.[C~ED jrlrLD BO0~ ii -~... I--= tJ .o . CKKTirlCLTr OF SURVEYOR : I #(R£11f CZRTIFY 7HAl' J ..A.M PROPEFLL't' '. [NGJN£KR~ LA. NO · 'B' PAD ~S° ,BO4LT ~q£,LL 3.,DC,ATJ ON CONOCO · ~C~L~ ::..j~.~rT , I' · 400' ' ~ '~ Or 2 CO~ E NTS s . '. ~ ,f FR~'N LINE [EOf. 19, ALL ~HKRS FROM S. LINE N SIMPSON LAGOON I, IILN£ POINT ' UNIT EXISTING DEVELOPMENT · · .. . L STATE PLANE CO.ORDINATES ARE .2ONE 4. " ~'. ALL GEODETIC POSITIONS ARE BASED ON N.A.D, 1927, 'OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACT£D VALUES OF THE SECTION CORNER POSITIONS. , , LOCATION I~ .~;EC?IOH ~'ELL FROGS. Li~E] FRDMW. LINE 5-7 I" ~5~' · e ,.- 1Z 7~,5 ' B- 13 j 552' e.14 ~ G4--9" :500' i i m, PLANE CO~RD~. NORTHINGS FASTINGS i i , 57t, ~,34.7-1 POSITION LATITUDE I -050' g,, ozD.'?TZ-.~'7 572,o~z, b$ 105-/: - 6.[rz3.424. 15,' - S7'Z, i1'5':.4.,q 7O'.-Z~'-ZT. 4otJ 70: z~'- Zg.& ~l ~ 70'- z$'-zs.s~[,' 1 LONGITUDE - 149'- z~'-47. 5~0 ~u 149: 24L41.1zII ~ 1/~9'- 24'-41.99~ ~ 't 4. q~zz~ 'B9.4~, ~j DATE 11-5-~ '-u-%- $4 3,-H. CHECKED lriELu BOOK ' 3.14. '' II -5-84 3.-H- II-B-$4 S7Z, o$~. Zo In 9% Z 4'-40.?~ S ~v lOO8 C[RTIIrlCLTE OF SURVEYOR : -: I ~[~CEI¥ C£RTiir"f-THAT I ~M PROPE~Y 4ND OTHER ~TAILg ARE CORRECT. NOCO' ~H]r ET ; · 'Z OF 2 AS-I~UILT ~[LL ,lOCATION Sut,vey~ ft~ . :.. CO~ENT$ e . '. DI~ENSION TH~'~ FR~'N. LIN[ SECT. 19, ALL ~HERS fROM S. LINE SECT. 18. CALCULATION OF LEAST [ IoTANCE BETWEEN WELLS WELL 1 --- CONOCO, INC. FILE 2687 PAD B, WELL NO: 13 4TH REVISED F'ROPOSAL MILNE PT., NORTH SLOF'E, ALASKA COORDINATES: 532.00 N ~79.00 E KB = 5.9. WELL 2 --- C:ONOC:O, INC. FILE 1202 MILNE PT., WELL NO: B-5 GMS/MMS/MMS dOB NO: AO882G0464 KUPARUK FIELD, NORTH SLOPE, ALASKA E:OORDINATES;: 68.00 N 1110.00 E KB = 59. RANGE OF MEASIJRED DEPTH WELL 1 0. FT TO WELL,-'-' (]. FT TO 5205. FT WITH A 10.0 FT INTERVAL. 4702. FT WITH A '10.(:) FT INTERVAL MEASURED TVD DEPTH RI<B $~ 1 NF-; EW WELL 1 -.~._.0.00 2070.4A 40.4A N WELL,~ ~.' 208o.. 00 ~.'s'A27. .84 35.6.5 N DISTANCE BETWEEN POINTS IS ('~ 91 8 . 1360.78 E 1441.97 E Eastman z Whipstock .~ ~:' FRO{ HOR'""ONT AL PROJECT I ON .... SCALE 1 IN. = 1000 FEET .. CONOCO. INC. PAD B. WELL NO' 13 PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. _;Z.;.'i._-_:_ 1000 .' ..... 0 -,i-. ___.1000 "'2000_ '- _ 3000 ..... 4000 ;..:...5000 ..... ~-$000 : - 1000 " I I ' I I I i I. SURFACE LOCATION~ ........ ' - " ' 6~9' FSL. 950' F~I1. ...... ~ ...... ; ...... : ................................ SEC. 18. TI3N. RI IE'-~"}'-~ ..... ;'~'-! .......i-) ............................................ ; .........; ........ · ; . . _ ._ .1000 _ ._ ; _. : ..... . . . . _ . _ . 2000 _ . 3000 _ '4000 _ 5000 _ 6000 _ '' ' S =~ ~'~'~' ""' M IN E 6596' (TO TARGET) . TARGET TVD=6910 TARGET LOCATION, TMD=9956 4700' FNL. 400' FEL DEP=6596 SEC. 19. TI3N. Rl lE RECEIVED MAY 0 8 1985 Alaska Oil & 6as Cons Anchorage TD PAD B. WELL NO' 13 PROPOSED MILNE PT.. NORTH SLOPP~ ALASKA EASTHAN WHIPSTOCK. ~NC. _. 0 SURFACE ....... 1000 . .. _5.2000 . . KOP TVD=600 THD=600 DEP=O $ 20 ~ ~' - 2.5 ....... BUILD 2 t/2 OEO PER.lO0 FT . . - ' ~ . 30 . - .... ~ ............ 35 .... ~ ' 50 EOB TVD=2400 THD=2670 DEP=873 .... .... :3000 ._4000 _ 5000 ................................. _ .......... :_,:__ . ~ AVERAGE ANGLE ................ 5:, D~G~ ~ MIN 6000 7000 TARGET TVD=691 0 "TENTATIVE' 9 5/8" CSG PT TVD=4630 TMD=6273 DEP=3Z03 RECEIVED '. ' MAyo 81985 o~°ns' Commission TMD=9956 DEP=6596 "~ TD TVD=7400 TMD=10748 DEP=7217 '''''~ 8000 I I 1000 2000 I I I I 3000 4000 5000 6000 7000 VERTICAL SECTION 800 ' , 700 _ NORTH 12OO 1 ~00 I I CONOCO. INC. PAD B, WELL NO~ 13 PROPOSED MI LNE PT., NORTH SLOPE. ALASKA -i: .... , i ~,~ i . THIS VIEWING WINDOW .\ ~.'_.5:00 '._ __'.':~'_~ --:'- -!i~'~'~z~ i: -. i' - i ' : .... . :' '__ _' Z"'_-_'_ii _i__ .~ . L~' ...... ~ 1659' ~400 . ., ...... 300 200 100 . EASTHAN WHIPSTOCK, INC. NOTE' WELL PATHS EXTEND BEYOND ~ - 1832 1915 . ! 996 · - . . . ~ . . ~ 3248 3367 ,oo 1 400 I 1 5OO I 4270 15 4040 3920 3778 2149 2221 3444 1584 17; 229O 958 2131 2213 2356 1600 I KILL UANIF'OLD FROU REUOTE HIGH PRESSURE PUMP --"' · NOTE: - - L NIORIULIC: CC.~T~JL s¥srEg FOR 8~ ~ACX 8 C~O~ a4~OLO ~0 ~CLU~E (51 STATI~ CONTROL UANIFO~ L~T[D REMOTELY WITH 3~0 PSI ~CCU~ULATOR SM. ~ROL aA~FO~ PLUS VARIAS~ CNOK[ ~T~L TO BE ~T[D ~ RIG FLO0~. .. Z ~ 8 CHG~ ~ANIFOLDS ~ MEET I ~ ~aNJF~O SIZE-RATING Z"-5~O { ~ ~ANIFO~ ~iZE - RATING * ~- 5~ ~'~ FRO~ UUD PUUP RL-~OTE PRESSURE GAGE SENSOR · · HYDRAULIC CONTROLLED REMOTE OPERATED DRILLING SPOOL HYDRAULIC CO,qTROLLED REUOTE OPERATED REBOTE PRESSURE GAGE SENSOR ADJUSTABLE CHOKE CHOKE ADJUST,~' ~LE: MA/'~IFOLD CHOKE VARIABLE CHOKE CONTROL ----. TO SHALE SHAKER BLE~D LINE TO PIT t TO ATMOSPHERIC ),IUD/GAS SEPARATOR RECEIVED MAY 0 8' ]985 CHCXE 5 KILL UAt:IFOLDS FOR c1'~/8'~ & 7" OD CASIi'JG BOP STACK ~O? ",:,, .,,-,,,IFOLD LAYOUT - CONOCO : INC. MILNE POINT UNIT 20" DIVERTER STACK 6" Relief Line Fill-up Line .- ! 'Annular .:.. ~Preventer ) HCR ~ Valve L T ---------~ m | Drilling > Spool × ~ 2000 p~ Flow Line HCR Valve , 6" Relief Valve Diverter Quick Connect Assembly Saver Sub Head ' . ' Assembly Starting ~ ',' ' Casing ' ~c/i...-. · ~ . 1. Relief lines from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specif£aations and AOGCC regulations. 3. Both tICK valves will open when the preventer closes, then either one may be closed. Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRC 7-17-84 MILNE POINT UNIT BOP STACK (1) B.O.P'. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated (2) BOPE to be operated on each trip ..- & pressure tested weekly. Fill-up Lima~FlOw Line reventer 1 f RA?! ~ 13 5/8" - 5000 ~ .-~ . /~" C-T-. ~ .'] ~ s - sooo SPO0 3" - 5000 S~de .. . · . (-" ~.~ _] ~ ~/~" - ~000 . _ _ 2" - 5000 ' -- Side Ou~le~ .~_j~~., 11" - 5000 B" - 5000 CSG ~ 'o''- Side Outlets SPOO ~.'" , ~ ' . (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 '' ' gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. RECEIVED MAY 0 819B5 Alaska Oil & G~s Cons. Con;rniss~°rL Anchorage CHECK LIST FOR NEW WELL PERMITS Comp any Lease & Well Noo ITEM APPROVE DATE _ (1) Fee (2) Loc (~ thr'u 8) (4) Cas~ h:~L'~' '"'~'~ ":" ( ,' +, ,:" ~ ,~ , ,,.'? .b (13 thru 21) (22 thru 26) (6) Add:~ ',- . mm 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. -24. 25. 26. 27. YES ,. Is the permit fee attached .......................................... ~ ~.__ Is well to be located in a defined pool ............................. Is well located proper distance from property line ................. Is well located proper distance from other wells i Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ....... Is operator the only affected party ...................... Can permit be approved before ten-day wait .......................... NO REMARKS Does operator have a bond in force .................................. ~ .... Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ , Is conductor string provided ....................................... Is enough cement used to circulate on conductor and ~Urface . Will cement tie in surface and intermediate or production strings ... ~i~ Will cement cover all known productive, horizons ..................... Will surface casing protect fresh water zones ........................ Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ , ,. Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached....... ~...,~o'v,c~ Does BOPE have sufficient pressure rating - Test to :' .-".'t.', psig .. ,' "' Does the choke manifold comply w/API RP-53 (Feb.78) .................. :-'":' Is the presence of H2S gas probable ................................. Additional requirements ............................................. Geology: En~qeerin~: ncs SEW JAL~::~ ,/ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. 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