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186-079
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2P-419 50-103-20483-00 910080528 Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-25 0 12 2P-429 50-103-20378-00 910080397 Kuparuk River Multi Finger Caliper Field & Processed 8-Jun-25 0 13 2T-38A 50-103-20229-01 910106462 Kuparuk River Plug Setting Record Field- Final 8-Jun-25 0 14 2Z-07 50-029-20946-00 910026798 Kuparuk River Plug Setting Record Field- Final 10-May-25 0 15 3K-20 50-029-23019-00 910080196 Kuparuk River Packer Setting Record Field- Final 18-May-25 0 16 3N-12 50-029-21582-00 910080396 Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-25 0 17 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 3-Jun-25 0 18 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 4-Jun-25 0 19 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 6-Jun-25 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40597T40598T40599T40600T40601T40602T40602T40602T40602204-017201-102197-205183-064201-088186-0796/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:47:18 -08'00'186-0793N-1250-029-21582-00 910080396Kuparuk RiverMulti Finger CaliperField & Processed3-Jun-250173N-1250-029-21582-00 910080396Kuparuk RiverPlugSetting RecordField- Final3-Jun-250183N-1250-029-21582-00 910080396Kuparuk RiverPlugSetting RecordField- Final4-Jun-250193N-1250-029-21582-00 910080396Kuparuk RiverPlugSetting RecordField- Final6-Jun-2501 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: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Update 4/30/25 Date:Wednesday, April 30, 2025 10:31:52 AM Attachments:3N-12 90 Day TIO Plot & Schematic 4-30-25.pdf From: Well Integrity Engineer CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, April 30, 2025 10:19 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Update 4/30/25 Well Name: 3N-12 Facility: CPF3 PTD: 186-079 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Plan Forward Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): 12/30/24 Chris, KRU 3N-12 (PTD186-079) is approaching the end of its second 60 day monitor on 5/4/25. The IA is still experiencing suspect IA pressure increases and was shut in yesterday 4/29/25. CPAI plans to secure the well with a tubing plug and conduct further diagnostics. Any proper paperwork for continued injection or corrective action will be submitted once a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, March 3, 2025 11:19 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Update 3/3/25 Chris, KRU 3N-12 (PTD186-079) passed pack off tests, a MITIA to 3000 psi (see attached 10- 426) and completed it’s 60 day monitor today 3/3/25. For the first 7 weeks of the monitor period the IA appeared stable but during the 8th week the IA pressure increased ~400 psi, which is believed to be a response that coincides with an increase in injection rate and wellhead pressure. CPAI plans to bleed the IA pressure and extend the monitor period for another 60 days. Any proper paperwork for continued injection or corrective action will be submitted once the 60-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, December 30, 2024 11:01 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Chris, KRU 3N-12 (PTD 186-079) is showing signs of suspect IA pressurization during injection. CPAI intends to keep the well online and have DHD perform initial diagnostics, including pack off tests, a MITIA and then bleed the IA after which the well will be put on a 60 day monitor period. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Any required paperwork for corrective action or continued injection will be submitted upon conclusion of the diagnostics and monitor period. Attached is a 90 day T/I/O plot and wellbore schematic for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,846.0 3N-12 3/8/2018 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull Gauges 3N-12 9/9/2024 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: Tight Spot in Tubing @ 7731' RKB (unable to pass through w/ 2.0" OD) 3/8/2018 zembaej NOTE: View Schematic w/ Alaska Schematic9.0 1/18/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 38.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,087.8 3,552.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 8,101.7 6,699.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth … 7,757.9 Set Depth … 6,411.9 String Max No… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMo d ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.10 HANGER 8.100 FMC TUBING HANGER FMC 2.441 1,780.7 1,777.0 13.95 SAFETY VLV 4.760 BAKER FVL SAFETY VALVE w/ 6' PUP Baker FVL 2.310 7,483.9 6,184.7 34.62 GAS LIFT 5.500 GLM 2 7/8" x 1 1/2" McMurry Hughes w/ 48/64 CV Merla MHRK latch MMH FMHO 2.347 7,523.3 6,217.2 34.42 PBR 4.750 BROWN PBR Brown 2.500 7,541.0 6,231.8 34.32 PACKER 6.151 BROWN HB PACKER Brown HB 2.875 7,579.0 6,263.2 34.12 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,647.4 6,320.0 33.87 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,684.9 6,351.1 33.76 BLAST RING 3.500 BTC w/ ROCKET BLAST RING (7687 - 7714) 2.441 7,718.7 6,379.3 33.68 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,733.4 6,391.5 33.64 SEAL ASSY 3.500 BROWN SEAL ASSEMBLY w/ LOCATOR Brown 2.441 7,734.9 6,392.7 33.64 PACKER 6.151 BROWN 1B PACKER Brown 1B 3.250 7,751.9 6,406.9 33.60 NIPPLE 3.668 CAMCO D NIPPLE Camco D 2.250 7,756.9 6,411.1 33.58 SOS 3.750 BROWN SHEAR OUT SUB Brown 2.441 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,483.9 6,184.7 34.62 1 GAS LIFT DMY RK 1 1/2 0.0 12/11/2015 2:00 0.000 7,579.0 6,263.2 34.12 2 INJ DMY BK 1 0.0 3/25/2015 8:00 0.000 7,647.4 6,320.0 33.87 3 INJ DMY BKP 1 0.0 6/18/2002 12:00 0.000 7,718.7 6,379.3 33.68 4 INJ HFCV BKP 1 0.0 2/24/2010 11:00 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,692.0 7,709.0 6,357.0 6,371.2 A-2, 3N-12 7/14/1986 12.0 IPERF 5" SEQ Csg Gun, 120 deg phase 7,815.0 7,816.0 6,459.5 6,460.3 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,815.0 7,817.0 6,459.5 6,461.2 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,818.0 6,461.2 6,462.0 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,819.0 6,461.2 6,462.8 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,824.0 6,462.8 6,467.0 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,832.0 7,844.0 6,473.7 6,483.7 A-2, 3N-12 11/13/1991 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,844.0 7,846.0 6,483.7 6,485.4 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,846.0 7,850.0 6,485.4 6,488.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,850.0 7,854.0 6,488.7 6,492.1 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,855.0 7,857.0 6,492.9 6,494.6 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,857.0 7,862.0 6,494.6 6,498.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,862.0 7,870.0 6,498.7 6,505.4 A-2, 3N-12 11/13/1991 1.0 RPERF 4" Jumbo Jet II Csg gun; 120° phase 3N-12, 9/9/2024 10:00:44 PM Vertical schematic (actual) PRODUCTION; 35.0-8,101.7 RPERF; 7,862.0-7,870.0 RPERF; 7,857.0-7,862.0 RPERF; 7,855.0-7,857.0 RPERF; 7,854.0-7,855.0 RPERF; 7,850.0-7,854.0 RPERF; 7,846.0-7,850.0 RPERF; 7,844.0-7,846.0 RPERF; 7,832.0-7,844.0 RPERF; 7,819.0-7,824.0 RPERF; 7,819.0-7,820.0 RPERF; 7,817.0-7,819.0 RPERF; 7,817.0-7,818.0 RPERF; 7,815.0-7,817.0 RPERF; 7,815.0-7,816.0 PACKER; 7,734.9 GAS LIFT; 7,718.7 IPERF; 7,692.0-7,709.0 GAS LIFT; 7,647.4 GAS LIFT; 7,579.0 PACKER; 7,541.0 GAS LIFT; 7,483.9 SURFACE; 37.0-4,087.8 SAFETY VLV; 1,780.7 CONDUCTOR; 38.0-110.0 KUP INJ KB-Grd (ft) 39.49 RR Date 4/21/1986 Other Elev… 3N-12 ... TD Act Btm (ftKB) 8,115.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292158200 Wellbore Status INJ Max Angle & MD Incl (°) 49.37 MD (ftKB) 3,500.00 WELLNAME WELLBORE3N-12 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 1 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Tuesday, March 4, 2025 1:57 PM To:AOGCC Records (CED sponsored) Subject:FW: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Update 3/3/25 Attachments:Diagnostic MITIA KRU 3N-12 12-31-24 .xlsx; 3N-12 90 Day TIO Plot & Schematic 3-3-25.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 3, 2025 11:19 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Update 3/3/25 Chris, KRU 3N-12 (PTD186-079) passed pack oƯ tests, a MITIA to 3000 psi (see attached 10-426) and completed it’s 60 day monitor today 3/3/25. For the first 7 weeks of the monitor period the IA appeared stable but during the 8th week the IA pressure increased ~400 psi, which is believed to be a response that coincides with an increase in injection rate and wellhead pressure. CPAI plans to bleed the IA pressure and extend the monitor period for another 60 days. Any proper paperwork for continued injection or corrective action will be submitted once the 60-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, December 30, 2024 11:01 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Chris, KRU 3N-12 (PTD 186-079) is showing signs of suspect IA pressurization during injection. CPAI intends to keep the well online and have DHD perform initial diagnostics, including pack off tests, a MITIA and then bleed the IA after which the well will be put on a 60 day monitor period. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Any required paperwork for corrective action or continued injection will be 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. 2 submitted upon conclusion of the diagnostics and monitor period. Attached is a 90 day T/I/O plot and wellbore schematic for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860790 Type Inj W Tubing 2550 2550 2550 2550 Type Test P Packer TVD 6232 BBL Pump 1.0 IA 1482 3000 2985 2980 Interval O Test psi 1558 BBL Return OA 190 190 190 190 Result P 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 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 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 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 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3N Pad Miller 12/31/24 Notes:Diagnostic MITIA to 3000 psi Notes: 3N-12 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)Diagnostic MITIA KRU 3N-12 12-31-24_ Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod ByLast Tag: RKB 7,846.0 3N-12 3/8/2018 zembaejLast Rev Reason Annotation Wellbore End Date Last Mod ByRev Reason: Pull Gauges 3N-12 9/9/2024 applehaNotes: General & Safety Annotation End Date Last Mod ByNOTE: Tight Spot in Tubing @ 7731' RKB (unable to pass through w/ 2.0" OD) 3/8/2018 zembaejNOTE: View Schematic w/ Alaska Schematic9.0 1/18/2011 ninamCasing StringsCsg Des OD (in) ID (in) Top (ftKB)Set Depth (ftKB)Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top ThreadCONDUCTOR 16 15.06 38.0 110.0 110.0 62.50 H-40 WELDEDSURFACE 9 5/8 8.92 37.0 4,087.8 3,552.2 36.00 J-55 BTCPRODUCTION 7 6.28 35.0 8,101.7 6,699.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth … 7,757.9 Set Depth … 6,411.9 String Max No… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMo d ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.10 HANGER 8.100 FMC TUBING HANGER FMC 2.441 1,780.7 1,777.0 13.95 SAFETY VLV 4.760 BAKER FVL SAFETY VALVE w/ 6' PUP Baker FVL 2.310 7,483.9 6,184.7 34.62 GAS LIFT 5.500 GLM 2 7/8" x 1 1/2" McMurry Hughes w/ 48/64 CV Merla MHRK latch MMH FMHO 2.347 7,523.3 6,217.2 34.42 PBR 4.750 BROWN PBR Brown 2.500 7,541.0 6,231.8 34.32 PACKER 6.151 BROWN HB PACKER Brown HB 2.875 7,579.0 6,263.2 34.12 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,647.4 6,320.0 33.87 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,684.9 6,351.1 33.76 BLAST RING 3.500 BTC w/ ROCKET BLAST RING (7687 - 7714) 2.441 7,718.7 6,379.3 33.68 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,733.4 6,391.5 33.64 SEAL ASSY 3.500 BROWN SEAL ASSEMBLY w/ LOCATOR Brown 2.441 7,734.9 6,392.7 33.64 PACKER 6.151 BROWN 1B PACKER Brown 1B 3.250 7,751.9 6,406.9 33.60 NIPPLE 3.668 CAMCO D NIPPLE Camco D 2.250 7,756.9 6,411.1 33.58 SOS 3.750 BROWN SHEAR OUT SUB Brown 2.441 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,483.9 6,184.7 34.62 1 GAS LIFT DMY RK 1 1/2 0.0 12/11/2015 2:00 0.000 7,579.0 6,263.2 34.12 2 INJ DMY BK 1 0.0 3/25/2015 8:00 0.000 7,647.4 6,320.0 33.87 3 INJ DMY BKP 1 0.0 6/18/2002 12:00 0.000 7,718.7 6,379.3 33.68 4 INJ HFCV BKP 1 0.0 2/24/2010 11:00 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,692.0 7,709.0 6,357.0 6,371.2 A-2, 3N-12 7/14/1986 12.0 IPERF 5" SEQ Csg Gun, 120 deg phase 7,815.0 7,816.0 6,459.5 6,460.3 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,815.0 7,817.0 6,459.5 6,461.2 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,818.0 6,461.2 6,462.0 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,819.0 6,461.2 6,462.8 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,824.0 6,462.8 6,467.0 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,832.0 7,844.0 6,473.7 6,483.7 A-2, 3N-12 11/13/1991 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,844.0 7,846.0 6,483.7 6,485.4 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,846.0 7,850.0 6,485.4 6,488.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,850.0 7,854.0 6,488.7 6,492.1 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,855.0 7,857.0 6,492.9 6,494.6 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,857.0 7,862.0 6,494.6 6,498.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,862.0 7,870.0 6,498.7 6,505.4 A-2, 3N-12 11/13/1991 1.0 RPERF 4" Jumbo Jet II Csg gun; 120° phase 3N-12, 9/9/2024 10:00:44 PMVertical schematic (actual) PRODUCTION; 35.0-8,101.7 RPERF; 7,862.0-7,870.0 RPERF; 7,857.0-7,862.0 RPERF; 7,855.0-7,857.0 RPERF; 7,854.0-7,855.0 RPERF; 7,850.0-7,854.0 RPERF; 7,846.0-7,850.0 RPERF; 7,844.0-7,846.0 RPERF; 7,832.0-7,844.0 RPERF; 7,819.0-7,824.0 RPERF; 7,819.0-7,820.0 RPERF; 7,817.0-7,819.0 RPERF; 7,817.0-7,818.0 RPERF; 7,815.0-7,817.0 RPERF; 7,815.0-7,816.0 PACKER; 7,734.9 GAS LIFT; 7,718.7 IPERF; 7,692.0-7,709.0 GAS LIFT; 7,647.4 GAS LIFT; 7,579.0 PACKER; 7,541.0 GAS LIFT; 7,483.9 SURFACE; 37.0-4,087.8 SAFETY VLV; 1,780.7CONDUCTOR; 38.0-110.0 KUP INJ KB-Grd (ft)39.49 RR Date4/21/1986 Other Elev…3N-12...TDAct Btm (ftKB)8,115.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292158200 Wellbore StatusINJ Max Angle & MDIncl (°)49.37 MD (ftKB)3,500.00WELLNAME WELLBORE3N-12 AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: TRDP 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: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Date:Tuesday, January 7, 2025 3:49:20 PM Attachments:3N-12 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, December 30, 2024 11:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Report of suspect IA pressure increase Chris, KRU 3N-12 (PTD 186-079) is showing signs of suspect IA pressurization during injection. CPAI intends to keep the well online and have DHD perform initial diagnostics, including pack off tests, a MITIA and then bleed the IA after which the well will be put on a 60 day monitor period. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Any required paperwork for corrective action or continued injection will be submitted upon conclusion of the diagnostics and monitor period. Attached is a 90 day T/I/O plot and wellbore schematic for reference. Please let us know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,846.0 3N-12 3/8/2018 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull Gauges 3N-12 9/9/2024 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: Tight Spot in Tubing @ 7731' RKB (unable to pass through w/ 2.0" OD) 3/8/2018 zembaej NOTE: View Schematic w/ Alaska Schematic9.0 1/18/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 38.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,087.8 3,552.2 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 8,101.7 6,699.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth … 7,757.9 Set Depth … 6,411.9 String Max No… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMo d ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.10 HANGER 8.100 FMC TUBING HANGER FMC 2.441 1,780.7 1,777.0 13.95 SAFETY VLV 4.760 BAKER FVL SAFETY VALVE w/ 6' PUP Baker FVL 2.310 7,483.9 6,184.7 34.62 GAS LIFT 5.500 GLM 2 7/8" x 1 1/2" McMurry Hughes w/ 48/64 CV Merla MHRK latch MMH FMHO 2.347 7,523.3 6,217.2 34.42 PBR 4.750 BROWN PBR Brown 2.500 7,541.0 6,231.8 34.32 PACKER 6.151 BROWN HB PACKER Brown HB 2.875 7,579.0 6,263.2 34.12 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,647.4 6,320.0 33.87 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,684.9 6,351.1 33.76 BLAST RING 3.500 BTC w/ ROCKET BLAST RING (7687 - 7714) 2.441 7,718.7 6,379.3 33.68 GAS LIFT 4.750 GLM 2 7/8" x 1" Merla TMPD w/ Dummy BK-2 latch Merla TMPD 2.375 7,733.4 6,391.5 33.64 SEAL ASSY 3.500 BROWN SEAL ASSEMBLY w/ LOCATOR Brown 2.441 7,734.9 6,392.7 33.64 PACKER 6.151 BROWN 1B PACKER Brown 1B 3.250 7,751.9 6,406.9 33.60 NIPPLE 3.668 CAMCO D NIPPLE Camco D 2.250 7,756.9 6,411.1 33.58 SOS 3.750 BROWN SHEAR OUT SUB Brown 2.441 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,483.9 6,184.7 34.62 1 GAS LIFT DMY RK 1 1/2 0.0 12/11/2015 2:00 0.000 7,579.0 6,263.2 34.12 2 INJ DMY BK 1 0.0 3/25/2015 8:00 0.000 7,647.4 6,320.0 33.87 3 INJ DMY BKP 1 0.0 6/18/2002 12:00 0.000 7,718.7 6,379.3 33.68 4 INJ HFCV BKP 1 0.0 2/24/2010 11:00 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,692.0 7,709.0 6,357.0 6,371.2 A-2, 3N-12 7/14/1986 12.0 IPERF 5" SEQ Csg Gun, 120 deg phase 7,815.0 7,816.0 6,459.5 6,460.3 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,815.0 7,817.0 6,459.5 6,461.2 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,818.0 6,461.2 6,462.0 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,817.0 7,819.0 6,461.2 6,462.8 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2, 3N-12 9/24/1988 5.0 RPERF 2 1/8" EnerJet II, 0° phase 7,819.0 7,824.0 6,462.8 6,467.0 A-2, 3N-12 9/24/1988 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,832.0 7,844.0 6,473.7 6,483.7 A-2, 3N-12 11/13/1991 4.0 RPERF 2 1/8" EnerJet II, 0° phase 7,844.0 7,846.0 6,483.7 6,485.4 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,846.0 7,850.0 6,485.4 6,488.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,850.0 7,854.0 6,488.7 6,492.1 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,855.0 7,857.0 6,492.9 6,494.6 A-2, 3N-12 11/13/1991 6.0 RPERF 2 1/8" EnerJet II, 0° phase 7,857.0 7,862.0 6,494.6 6,498.7 A-2, 3N-12 11/13/1991 7.0 RPERF 2 1/8" EnerJet II, 0° phase 7,862.0 7,870.0 6,498.7 6,505.4 A-2, 3N-12 11/13/1991 1.0 RPERF 4" Jumbo Jet II Csg gun; 120° phase 3N-12, 9/9/2024 10:00:44 PM Vertical schematic (actual) PRODUCTION; 35.0-8,101.7 RPERF; 7,862.0-7,870.0 RPERF; 7,857.0-7,862.0 RPERF; 7,855.0-7,857.0 RPERF; 7,854.0-7,855.0 RPERF; 7,850.0-7,854.0 RPERF; 7,846.0-7,850.0 RPERF; 7,844.0-7,846.0 RPERF; 7,832.0-7,844.0 RPERF; 7,819.0-7,824.0 RPERF; 7,819.0-7,820.0 RPERF; 7,817.0-7,819.0 RPERF; 7,817.0-7,818.0 RPERF; 7,815.0-7,817.0 RPERF; 7,815.0-7,816.0 PACKER; 7,734.9 GAS LIFT; 7,718.7 IPERF; 7,692.0-7,709.0 GAS LIFT; 7,647.4 GAS LIFT; 7,579.0 PACKER; 7,541.0 GAS LIFT; 7,483.9 SURFACE; 37.0-4,087.8 SAFETY VLV; 1,780.7 CONDUCTOR; 38.0-110.0 KUP INJ KB-Grd (ft) 39.49 RR Date 4/21/1986 Other Elev… 3N-12 ... TD Act Btm (ftKB) 8,115.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292158200 Wellbore Status INJ Max Angle & MD Incl (°) 49.37 MD (ftKB) 3,500.00 WELLNAME WELLBORE3N-12 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-12 KUPARUK RIV UNIT 3N-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3N-12 50-029-21582-00-00 186-079-0 W SPT 6231 1860790 1558 2400 2460 2460 2460 220 220 220 220 4YRTST P Bob Noble 8/25/2024 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:KUPARUK RIV UNIT 3N-12 Inspection Date: Tubing OA Packer Depth 450 1800 1760 1760IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240827113345 BBL Pumped:1.2 BBL Returned:1.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:53:30 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, August 18, 2020 C P.I. Supervisor 714- 1I5i Zhu SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3N-12 FROM: Brian Bixby KUPARUK R1V UNIT 3N-12 Petroleum Inspector Src: Inspector Reviewed By: � P.I. Supry Zfls� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-12 API Well Number 50-029-21582-00-00 Inspector Name: Brian Bixby Permit Number: 186-079-0 Inspection Date: 8/15/2020 — Insp Num: mitBDB200816082135 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min `1`1e11 3N-12 Type Inj w TVD 6231 Tubing I 3000 3000 3000. 3000 ' PTD 11 1860790 Type Test SPT Test psi j 1558 IA 510 1810. 1770 - 1770 - BBL Pumped: 1.2 `BBL Returned: 1.2 - OA 1 20 20. 20 20 Intervale 4YRTST P/F P Notes: Tuesday, August 18, 2020 Page 1 of I Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, August 4, 2019 8:07 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3N-12 (186-079) Monitor Update Attachments: KRU 3N-12 TIO plot 90 -day 8-4-19.JPG Chris, KRU 3N-12 (186-079) is near the end of an extended monitor to review the IA behavior during water injection. Based on the extended monitor, the injector appears to have integrity. Attached is a 90 -day TIO plot. CPAI plans to return the well to normal injection status. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, June 6, 2019 9:08 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Update Attachments: KRU 3N-12 TIO plot 90 -day 6-6-19.JPG Chris, KRU 3N-12 (PTD 186-079) is at the end of its extended water injection monitor period. The extended monitor has not conclusively shown the condition of the well. CPAI intends to continue to monitor the well during water injection service for up to another 60 -days to determine the state of the well. During this next period, the IA may be manipulated more to assist analysis. CPAI will follow-up either when the condition of the well is conclusively determined or at the end of the 60 days. Please let us know if you have any questions or disagree with this plan. Attached is a 90 -day TIO plot. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Tuesday, May 7, 2019 8:02 AM To: Wallace, Chris D (DOA) <chris.wallacePalaska.aov> Cc: CPA Wells Supt <nl03OPconocophillips.com> Subject: RE: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Chris, 3N-12 (PTD 186-079) is at the end of a 30 -day water injection monitor to investigate previously reported suspect IA behavior. The well passed a diagnostic MITIA to 3010 psi near the beginning of the monitor, however, a temperature increase over the past month has made it difficult to assess the meaning of the TIO trend. CPAI intends to extend the water injection monitor for another 30 -days to confirm the wells condition. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: I Integrity Supv CPF3 and WNS Sent: Sunday, April 7, 1 AM To: Wallace, Chris D (DOA) <chris.wa s alaska. ov> Cc: CPA Wells Supt <n1030@conoco0hillips.c0m Subject: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, May 7, 2019 8:02 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Chris, 3N-12 (PTD 186-079) is at the end of a 30 -day water injection monitor to investigate previously reported suspect IA behavior. The well passed a diagnostic MITIA to 3010 psi near the beginning of the monitor, however, a temperature increase over the past month has made it difficult to assess the meaning of the TIO trend. CPAI intends to extend the water injection monitor for another 30 -days to confirm the wells condition. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, April 7, 2019 9:01 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <nl030@conocophillips.com> Subject: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Chris, Kuparuk injector 3N-12 (PTD 186-079) is showing signs of suspect IA pressurization during injection. CPAI intends to commence a 30 -day monitor period to observe and investigate the IA behavior. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, April 7, 2019 9:01 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: KRU 3N-12 (PTD 186-079) Suspect IA Behavior Attachments: KRU 3N-12 TIO plot 90 -day 4-7-19.pdf Chris, Kuparuk injector 3N-12 (PTD 186-079) is showing signs of suspect IA pressurization during injection. CPAI intends to commence a 30 -day monitor period to observe and investigate the IA behavior. If communication is confirmed during the monitor or diagnostic testing, the injector will be shut-in as soon as possible. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 •OF Thy THE STAT Alaska Oil and Gas ,03/,,- .... ;, of/` IAS Conservation Commission itt _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS*P- Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCO #` 6 ?{OP Staff Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-12 Permit to Drill Number: 186-079 Sundry Number: 317-569 Dear Mr. Burke: uke. 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, Hollis S. French Chair DATED this (3 day of December, 2017. RBDMS 1 1, 2017 • I• • RECEIVED STATE OF ALASKA DEC 0 6 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION • ZS t 1.113/i 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend U Perforate U Other Stimulate U Pull Tubing U Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: DAD ACID StimulatU 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory U Development U 186-079 3.Address: Stratigraphic 11Service 0 , 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21582-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3N-12 ' Will planned perforations require a spacing exception? Yes 1=1No Il 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25520 • Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 8,115' 6,711' • 7980 . , 6596 3175psi NONE NONE Casing Length Size MD ND Burst Collapse Conductor 72' 16" 110' 110' Surface 4,051' 10" 4,088' 3,552' Production 8,067' 7" 8,102' 6,699' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7692-7870 MD ' 6357-6505 ND 2.875" J-55 7,757' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BROWN HB PACKER MD=7541 ND=6232 PACKER-BROWN 1B PACKER MD=7735 ND=6393 " SAFETY VLV-BAKER FVL SAFETY VALVE w/6'PUP MD=1781 ND=1777 12.Attachments: Proposal Summary U Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program U BOP Sketch U Exploratory U Stratigraphic U Development 0 Service 0 14.Estimated Date for 12/25/2017 15.Well Status after proposed work: Commencing Operations: OIL U WINJ D WDSPL U Suspended ❑ 16.Verbal Approval: Date: GAS U WAG ❑ GSTOR ❑ SPLUG U Commission Representative: GINJ U Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer i� Contact Email: Jason.Burke@cop.com e''...------- _� / Contact Phone: (907)265-6097 Authorized Signature: i 9- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5/7 " &. Plug Integrity U BOP Test U Mechanical Integrity Test U Location Clearance U Other: 1� B D T,9 L 1 4 r;� Post Initial Injection MIT Req'd? Yes U No I�s at+svi�J �'� CE!17 Spacing Exception Required? Yes U Nod Subsequent Form Required: (G t° 4 • APPROVED BY (Z I i3Itl Approved by: COMMISSIONER THE COMMISSION Date: /(\ ''1' i (A/?h7- "f W70 vT / / ,1q0 R 1 G I N AL Submit Form and V'\7 Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • G. Well Work Request Form ' Well: 2N-337C Date of Request: 11/14/2017 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Well Type: Injector Req.Written by: Jason Burke,265-6097 Job Scope: DuraKleen Shut-In Reason Code: Well Shut in Date(if SI): Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: 10405103 Job/SAP Comment: Wells Group use ❑Well Work is not justified via increased production []Preventive Maintenance Program Request Injection Well C_ Surrounding Producer Data Current Injection Rate(RVBPD) Total Offset(AOF)Oil Rate(BOPD) Expected Post Job Rate(RVBPD) Total Offset(AOF)Gas Rate(MSCFD) Enter Benefit Correction-cell Offset WC Need Offset Total Offset(AOF)Water Rate(BWPD) IGOR for CPF(SCF/STB) 26000 Rate Prediction Engr./Source Gross Oil Benefit(BOPD) Enter Rates NOB(BOPD) Enter Rates Success Probability 90% If job fails,expected rate Zero Est.Duration of Job(SI Days) 1 Risked NOB(BOPD) Enter Rates Est. Number of Equipment Days 1 Risked NOB/Equip.Day Enter Rates Last SBHP 3793 psi Last Tag 7,830'md H2S(PPM): O'ppm SBHP Date 1/16/2015 Tag Date 1/6/2015 Any Fluid Restriction on Well? no SBHP Datum(TVD/SS?) 6187 SS Max Inclin. 49° Max Dogleg 4°/100'and Min. I.D(at/above work) 2.31" Max Incl. Depth 3,500'md Max Dogleg Depth 2,500'md Well Work Justification & Objectives 3N-12 is an injector that may have mixed deposits,the plan is to pump a DAD treatment to increase injection. Risk/Job Concerns: Steps: CTU: 1. MIRU CT unit 2. MU Slick BHA of CTC,DFCV and Spin Cat wash nozzle 3. Begin RIH pumping diesel at 1 BPM,washing tubulars as CT reaches TD(as deep as possible) 4. Begin pumping 100 bbl of DAD at 1 BPM,when DuraKleen has reached the nozzle(CT volume pumped away)shut in backside choke and begin POOH at 10 FPM 5. Once DAD has been pumped,chase with—35 bbl diesel,and squeeze the treatment into formation. 6. POOH and RDMO CTU 7. Put well back on injection 3N-12 DAD Procedure.xlsm Printed 12/4/2017 KUP I 3N-12 ConocoPhilhhps 1 Well Attribut _ Max Angle&MD TD p.l71;:1(et.Ire, ' Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Con0CatiNips"'1," 500292158200 KUPARUK RIVER UNIT INJ 49.37 3,500.00 8,115.0 °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 35-12,12/4/29173:51 08 PM SSSV:TRDP Last WO: 39.49 4/21/1986 Vertical s liama0c:(at.'tual)... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,830.0 1/6/2015 Rev Reason:MANDREL ORIENTATION pproven 1/10/2016 ■ _ _ Casing Strings HANGER;35.0II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread J "' CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED L t I A, t. Casing Description OD(in) ID(in) Top lake) Set Depth(ftKB) Set Depth(N ...Wt/Len p...Grade Top Thread SURFACE 95/8 8.921 37.0 4,087.8 3,552.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread PRODUCTION 7 6.276 35.0 8,101.7 6,699.4 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...I"") n) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade lop Connection CONDUCTOR;38.0-110.0 ► TUBING 27/81D(i 2.4411 3501 7,757.91 6411.91 6.501 J-55 1EUESrdABMod Completion Details SAFETY VLV;1,780.7 -t . Top(ftKB) Top(ND)(ftKB) Top Incl(°1 Item Des Corn Nominal I ID t 35.0 35.0 0.10 HANGER FMC TUBING HANGER 2.441 1 1,780.7 1,777.0 13.95 SAFETY VLV -BAKER FVL SAFETY VALVE w/6'PUP 2.310 7,523.3 6,217.2 34.42 PBR BROWN PBR 2.500 7,541.0 6,231.8 34.32 PACKER BROWN HB PACKER 2.875 SURFACE;37.0-4,087.8--. l 7,684.9 6,351.1 33.76 BLAST RING BTC w/ROCKET BLAST RING(7687-7714) 2441 7,733.4 6,391.5 33.64 SEAL ASSY BROWN SEAL ASSEMBLY w/LOCATOR 2.441 7,734.9 6,392.7 33.64 PACKER BROWN 1B PACKER 3.250 GAS LIFT;7,483.9 ' t_ 7,751.9 6,406.9 33.60 NIPPLE CAMCO D NIPPLE 2.250 I7,756.9 6,411.1 33.58 SOS BROWN SHEAR OUT SUB 2.441 PBR;7,523.3 Perforations&Slots PACKER;7,541.0 Shot rr.. Den Top(ND) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;7,579.0 7,692.0 7,709.0 6,357.0 6,371.2 A-2,3N-12 7/14/1986 12.0 IPERF 5"SEC/Csg Gun,120 deg phase 7,815.0 7,817.0 6,459.5 6,461.2 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg phase GAS LIFT'7,847.4 7,815.0 7,816.0 6,459.5 6,460.3 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,817.0 7,819.0 6,461.2 6,462.8 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg phase IPERF;7,692.07,709.0 T 7,817.0 7,818.0 6,461.2 6,462.0 A-2,3N-12 9/24/1988 5.0 RPERF 21/8"EnerJet 11,0 deg phase 1 7.819.0 7,824.0 6,462.8 6,467.0 A-2,3N-12 9/24/1988 4.0 RPERF 21/8"EnerJet ll,0 deg phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet ll,0 deg GAS LIFT;7,718.7 phase 7,832.0 7,844.0 6,473.7 6,483.7 A-2,3N-12 11/13/1991 4.0 RPERF 21/8"EnerJet II,0 deg phase SEAL ASSY;7,733.4 7,844.0 7,846.0 6,483.7 6,485.4 A-2,3N-12 11/13/1991 6.0 RPERF 21/8"EnerJet II,0 deg PACKER;7,734.9 s`4/•_ phase 7,854.0 6,488.7 6,492.1 A-2,3N-12 11/13/1991 6.0 RPERF 21/8"EnerJet ll,0 deg 7,846.0 7,850.0 6,485.4 6,488.7 A-2,3N-12 11/13/1991 7.0 RPERF 21/8"EnerJet ll,0 deg phase NIPPLE;7,751.9 7,850.0 phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg SOS;7,756.9 phase 7,855.0 7,857.0 6,492.9 6,494.6 A-2,3N-12 11/13/1991 6.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,857.0 7,862.0 6,494.6 6,498.7 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg phase RPERF;7,815.07,816.0- 7,862.0 7,870.0 6,498.7 6,505.4 A-2,3N-12 11/13/1991 1.0 RPERF 4"Jumbo Jet II Csg gun; RPERF;7,815.00.7,817.0 .8 120 deg phase Mandrel Inserts st ati RPERF;7,817.0-7,818.0 on Top(ND) Valve Latch Port Size TRO Run RPERF;7,817.0-7,819.0-.-s• N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,483.9 6,184.7'MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/11/2015 2:00 -... RPERF;7,819.D-7,820.0- ... 2 7,579.0 6,263.2 Merla TMPD 1 INJ DMY BK 0.000 0.0 3/25/2015 8:00 RPERF;7,819.0-7,824.0-. 3' 7,647.4 6,320.0 Merle TMPD 1 INJ DMY BKP 0.000 0.0 6/18/2002 12:00 4 7,718.7 6,379.3 Merla TMPD 1 INJ HFCV BKP 0.000 0.0 2/24/2010 11:00 Notes:General&Safety RPERF;7,832.0-7,844.0--.4 End Date Annotation RPERF;7,844.0-7,848.0-4. 6/12/1994 NOTE:WAIVERED WELL:T x IA COMMUNICATION 1/18/2011 NOTE:View Schematic w/Alaska Schematic9.0 RPERF;7,048.0-7,850.0--. -- -- RPERF;7,850.0-7,854.0- . � RPERF;7,854.0-7,855.0-.. 1 RPERF;7,855.07,857.0-. RPERF;7,857.0-7,862.0 RPERF;7,882.0-7,870.0 PRODUCTION;35.0-8,101.7 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,November 02,2016 P.I.Supervisor ^e1JC, Il jL01 t(o SUBJECT: Mechanical Integrity Tests l` �' CONOCOPHILLIPS ALASKA INC 3N-12 FROM: Brian Bixby KUPARUK RIV UNIT 3N-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-12 API Well Number 50-029-21582-00-00 Inspector Name: Brian Bixby Permit Number: 186-079-0 Inspection Date: 10/25/2016 Insp Num: mitBDB161026044127 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-12 - Type Inj W TVD 6231 Tubing i 2950 . 2950 . 2950 . 2950 - PTD 1860790 Type Test SPT Test psi 1558 IA 955 2010 - 1970 1960 . Interval OTHER PAF P OA 390 430 . 430 430 Notes: This is a Post Packer Seal Repair Test.Sundry#315-684. 1.5 BBLS Diesel to Fill IA and 1.5 BBLS were bled back. SCANNED APR 2 : 2017 Wednesday,November 02,2016 Page 1 of 1 • 2340 WELL LOG TRANSMITTAL# I,^ L:.it.7taG.0 -1 '5'2r 4 i. K. yc;,IA i4 To: Alaska Oil and Gas Conservation Comm. June 10, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 iifsiw/Y` rmte RE: Leak Detect Log with ACX: 3N-12 Run Date: 7/4/2015 ` The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3N-12 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-21582-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-21582-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED DEC 0 92016 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ALa'h'0." 6€01-eat 2-Gs'0 WELL LOG TRANSMITTAL#903001404 To: Alaska Oil and Gas Conservation Comm. January 22, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Ri ve° DATA LOGGED Anchorage, Alaska 99501 JAN 26 l K.BENDER poGGC RE: Multi Finger Caliper(MFC)/Radial Cement Bond Log: 3N-12 Run Date: 12/18/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3N-12 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21582-00 Radial Cement Bond Log 1 Color Log 50-029-21582-00 t PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: diALL,Ita..0 / , ,t . AWAE OF ALASKA KRU 3N-12 OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon IT Plug Perforations IT Fracture Stimulate r— Pull Tubing T 'Operations Shutdown r— Performed: Suspend r Perforate T Other Stimulate IT Alter Casing I •••. Change Approved Program r— , Plug for Redrill T Perforate New Pool IT Repair Well F Re-enter Susp Well 0/(11 Jo c le-,pkr '67- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I Exploratory T 186-079 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic I Service 50-029-21582-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25520 ALK 2556 KRU3N-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8115 feet Plugs(measured) None true vertical 6711 feet Junk(measured) None Effective Depth measured 7980 feet Packer(measured) 7541,7735 true vertical 6596 feet (true vertical) 6232,6393 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 0 0 0 SURFACE 4051 9 5/8 4088 0 0 0 PRODUCTION 8067 7 8102 0 0 0 a f Perforation depth: Measured depth: 7692-7870 5 , True Vertical Depth: 6357-6505 II " , Please see attached schematic for detail perforations ) JAiw 2P i Tubing(size,grade,MD,and ND) 2.875,J-55,7757 MD,6411 TVD AOGGe Packers&SSSV(type,MD,and ND) PACKER-BROWN HB PACKER @ 7541 MD and 6232 TVD PACKER-BROWN 1B PACKER @ 7735 MD and 6393 TVD SAFETY VLV-BAKER FVL SAFETY VALVE w/6'PUP @ 1781 MD and 1777 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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 0 0 0 1150 0 Subsequent to operation 0 0 0 1150 0 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory IT Development Service F Stratigraphic Copies of Logs and Surveys Run T 16.Well Status after work: Oil IT Gas IT WDSPL I Printed and Electronic Fracture Stimulation Data GSTOR IT WINJ F WAG T GINJ T SUSP T SPLUG r- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-684 Contact Mike Hazena265-1032 Email Michael.C.Hazen anconocophillips.com Printed Name Mike Hazen Title Staff Wells Engineer Signature Phone: 265-1032 Date �ZO T'S'-' ( 6 Aggzjil... vfl- 2 1 ito Form 10-404 Revised 5/201 „,,, ,-,,4 RBDMS l.L JAN 2 1 2016 Submit Original Only KUP III 3N-12 Con©coPhi lips Well Attribut Max Angle TD Alaska ire. Wellbore APIIUWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm OMB) Ca,,,,,a otos 500292158200 KUPARUK RIVER UNIT INJ 49.37 3,500.00 8,115.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3N-12,1/7/2016 2:01:14 PM SSSV:TRDP Last WO: 39A9 4/21/1986 ...Vertical schematic(actual) Depth End s - Annotation Last Mod By End Date Last .• 831 1 . 1 Rev Reason:GLV C/O,PULL CATCHER AND pproven 12/15/2015 WRP asing rings Casing Description OD On) HANGER,35.0 r gill { TopThreadSetDepth(ftK 1 ' . CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth PIKS) Set Depth(TVD)... Wt/Len(I...Grade Top Thread a..9 SURFACE 9 5/8 8.921 1 4,08736.00J-55 BIC f : •••• •tion OD(in) ID Top 1 Set Depth 1 Set Depth II Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;38.0-110.0 TUBING 27/81 2.4411 5. 7,757 7,757.91 6,411.91 6.50IJ-55 EUE8r4ABMad Completion Details SAFETY VLV;1,780.7 r11 '_ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 35.0 35.0 0.10 HANGER FMC TUBING HANGER 2.441 1,780.7 1,777.0 13.95 SAFETY VLV BAKER FVL SAFETY VALVE w/6'PUP 2.310 7,523.3 6,2172 34.42 PBR BROWN PBR 2.500 7,541.0 6,231.8 34.32 PACKER BROWN HB PACKER 2.875 7,684.9 6,351.1 33.76 BLAST RING BTC w/ROCKET BLAST RING(7687-7714) 2.441 SURFACE;37.0-4,087.8 7,733.4 6,391.5 33.64 SEAL ASSY BROWN SEAL ASSEMBLY w/LOCATOR 2.441 7,734.9 6,392.7 33.64 PACKER BROWN 1B PACKER 3.250 GAS LIFT;7,483 9 7,751.9 6,406.9 33.60 NIPPLE CAMCO D NIPPLE 2.250 7,756.9 6,411.1 33.58 SOS BROWN SHEAR OUT SUB 2.441 PBR;7,523.3 i Perforations&Slots PACKER;7,541.0 a c. Shot Dens PI a n Tap IND) Btm(TVD) (shots/ Top(ftKB) Btm(PoOB) OMB) (ftKB) Zone Date R) Type Com GAS LIFT;7,579.0 7,692.0 7,709.0 6,357.0 6,371.2 A-2,3N-12 7/14/1986 12.0 IPERF 5"SEQ Csg Gun,120 deg phase 7,815.0 7,817.0 6,459.5 6,461.2 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet 11,0 deg phase GAS LIFT;7.ea7.4 7,815.0 7,816.0 6,459.5 6,460.3 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg phase S. 7,817.0 7,819.0 6,461.2 6,462.8 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg phase (PERF;7692.0-7709.0-- 7,817.0 7,818.0 6,461.2 6,462.0 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,819.0 7,824.0 6,462.8 6,467.0 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg GAS LIFT;7,719 ' 7 ]: tlh phase 7,832.0 7,844.0 6,473.7 6,483.7 A-2,3N-12 11/13/1991 4.0 RPERF 2 1/8"EnerJet II,0 deg phase SEAL ASSY;7,733.4 . — 7,844.0 7,846.0 6,483.7 6,485.4 A-2,3N-12 11/13/1991 6.0 RPERF 2 1/8"EnerJet II,0 deg PACKER;7,734.9 )'57 phase 7,846.0 7,850.0 6,485.4 6,488.7 A-2,3N-12 11/13/1991 7.0 RPERF 21/8"EnerJet 11,0 deg phase NIPPLE;7,751.9 7,850.0' 7,854.0 6,488.7 6,492.1 A-2,3N-12 11/13/1991 6.0 RPERF 2 1/8"EnerJet 11,0 deg phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg phase SOS;7,756.9 II 7,855.0 7,857.0 6,492.9 6,494.6 A-2,3N-12 11/13/1991 6.0 RPERF 2 1/8"EnerJet ll,0 deg phase 7,857.0 7,862.0 6,494.6 6,498.7 A-2,3N-12 11/13/1991 7.0 RPERF 21/8"EnerJet 11,0 deg _ phase RPERF;7,815.0-7,816.0---- 7,862.0 7,870.0 6,498.7 6,505.4 A-2,3N-12 11/13/1991 1.0 RPERF 4"Jumbo Jet II Csg gun; RPERF;7,815.0-7,817.0+ I 120 deg phase -- Mandrel Inserts SI ah RPERF;7,817.0-7,818.0 on RPERF;7,817.0-7,819.0---- . s N Top(ND) Valve Latch Port Size TRO Run Top(9613) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com 1 7,483.9 6,184.7 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/11/2015 RPERF;7,819.0-7,820.D-- ` 2 7,579 0 6,263.2 Merle TMPD 1 INJ DMY BK 0.000 0.0 3/25/2015 RPERF;7,8190-7,824.0 3 7,647.4 6,320.0 Merle TMPD 1 INJ DMY BKP 0.000 0.0 6/18/2002 4 7,718 7 6,379.3 Merla •• 1 INJ HFCV BKP 0 000 11 2/24/2010 ..— Notes:General&Safety RPERF;7,832.0-7,844.0 End Date Annotation 6/12/1994 RPERF;7,844.0-7S48.0--. ~ NOTE: • • • .— 1 • 1 RPERF;7,848.0-7,850.0 RPERF;7,850.0-7,854.0.--. RPERF;7,854.0-7,855.0—. RPERF;7,855.0-7,857.0. RPERF;7,857.0-7,882.0—....... RPERF;7,862.0-7,870.0--. PRODUCTION;35.0-8,101.7 • 3N-12 11, DTTM JOBTYP SUMMARYOPS START 11/20/15 SLICKLINE PULLED 2.25" CATCHER FROM 7638' RKB.PULLED 2.25"WFT WRP FROM 7640' RKB. MISC. B&F W/2.25" CENT,2.5" BLB &2" GAUGE RING FROM 7440' SLM TO 7510' SLM. DRIFT, TAG, JOB IN PROGRESS.... ETC. 11/22/15 SLICKLINE DRIFTED W/2.28" CA-2 DUMMY DOWN TO 7590' SLM.SAW NO RESTRICTIONS. MISC. SET 2.25" WFT WRP @ 7504' RKB.PRESSURED TBG TO 2500 PSI TO VERIFY PLUG DRIFT, TAG, HOLDING. FTC .IC)R IN PRC)C;RFSS 11/23/15 SLICKLINE DEPLOYED 2.25" CATCHER. PULLED 1.5" DGLV FROM ST#1 @ 7483' RKB.SET 1.5" MISC. RKP-CIRC VALVE IN ST#1 @ 7483' RKB.RAN 2.25" LIB,TAGGED CATCHER @ 7462' DRIFT, TAG, SLM.RECOVERED G-FISHIN NECK IMPRESSION. ETC. WELL READY FOR RESIN JOB... 12/10/15 ANNCOMM PULLED 1.5" HFVC & SET 1.5" REVERSE CHECK VALVE @ 7483' RKB. OBTAIN GOOD DDT. READY FOR RESIN. IN PROGRESS. 12/11/15 ANNCOMM Pumped fullbore WeIlLock Resin leak repair spotting —2.5 bbls resin in IA to let swap to top of packer. Tbg freeze protected with 12 bbls diesel, IA w/80 diesel. Note: Resin to be @ full hardness in 7 12/11/15 ANNCOMM STANDBY FOR RESIN TO BE PUMPED; PULLED CATCHER @ 2.25"WRP @ 7504' RKB; PULLED 1.5" REVERSE CHECK VALVE (LIGHTLY FLOW CUT) & SET DV @ 7483' RKB. READY FOR E- LINE IN 7 DAYS. 12/18/15 SLICKLINE LRS PERFORM PASSING MITIA TO 2500 PSI. LOG RADIAL CEMENT BOND LOG FROM MISC. 7650' TO 6500' LOOKING DRIFT, TAG, FOR RESIN BEHIND TUBING ABOVE PACKER. LOG 24 ARM CALIPER FROM 7722'TO ETC. SURFACE. COULD NOT FALL PAST 7722' AND STICKY PICKING UP OFF BOTTOM. JOB COMPLETE. ID • • ti 7177;�,w'\� % THE STATE Alaska and Gas �,, �, of TConservation Commission ,AsKAL t k __ 333 West Seventh Avenue ITh, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®� Main: 907.279.1433 ALA Fax: 907.276.7542 www.aogcc.alaska.gov Mike Hazen Wells Engineer 4 2:0 ConocoPhillips Alaska, Inc. 50 �� `ki 6 0 P. O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3N-12 Sundry Number: 315-684 Dear Mr. Hazen: 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, tW-4 ,4- Alc- -_, Cathy P. oerster Chair DATED this /AJ day of November, 2015 Encl. RQ,pM 831401/ 1 7 2015 RECEIVED STATE OF ALASKA AASKA OIL AND GAS CONSERVATION COMMIS. NOV 0 4 2015 1 4 a APPLICATION FOR SUNDRY APPROVALS (� 1 20 AAC 25.280 IS OGC 1.Type of Request: Abandon '- PlugPerforations F Fracture Stimulate r Pull Tubing [-- Operations Shutdown 1— Suspend 3..... Perforate I Other Stimulate r Alter Casing [- Change Approved Program 1-11- Plug Plug for Redrill (- Perforate New Pool 1— , Repair Well F Re-enter Susp Well I— Other. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory 1— Development (— 186-079 - 3.Address: 6.API Number: Stratigraphic ' Service - P.O.Box 100360,Anchorage,Alaska 99510 50-029-21582-00 - 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Wit planned perforations require spacing exception? Yes [ No Fi / KRU 3N-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25520 ALK 2556 Kuparuk River Field/Kuparuk River Oil Pool • 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): 8115 6711 7980', 6596' 7640' Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 4051 9 5/8 4088' 3552' PRODUCTION 8067 7 8102' 6699' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7692'-7709' -Please see 6357'-6371'-Please see attached schematic for detailed Perfs ✓ attached schematic for detailed Perfs 2.875 J-55 7757 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB PACKER MD=7541 TVD=6232 PACKER-BROWN 1B PACKER MD=7735 TVD=6393 SAFETY VLV-BAKER FVL SAFETY VALVE w/6'PUP MD=1781 TVD=1777 • 12.Attachments: Description Summary of Proposal f 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development 1 Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/9/2015 OIL � WINJ - WDSPL E Suspended E 16.Verbal Approval: Date: GAS n WAG ('" GSTOR E SPLUG F. Commission Representative: GINJ Op Shutdown IT Abandoned IT 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Hazen @ 265-1032 Email: Michael.C.Hazenconocophillips.com Printed Name Mike _.zen Title: Wells Engineer Signature ` I 'rOPhone:265-1032 Date: 2 Nov 15 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315- ($2.%LE I_. e Mechanical Integrity P Plug Integrity 1 BOP Test /g y Test Location Clearance Other: tk)t, ns.tsc.-c I� - ( T' LA 11131:*S gYNO V yt,. 11 2015 Spacing Exception Required? Yes ❑ No � Subsequent Form Required: /C (� � APPROVED BY Approved by: 7""-'------ COMMISSIONER THE COMMISSION Date:l//'Q-�/S R OR ef�pplIN1A1.._ t id for 1Pita it f}�oryt the date of approval.Is '�JA / / Submit Form and Form 10-403 Revised 5/z 15� ' / Attachments in Duplicate • • 3N-12 Production Packer Seal Repair — WeIlLock Resin Permit to Drill #186-079 Kuparuk River Unit (KRU) injector well 3N-12 failed a tubing mechanical integrity test (MIT-T) to 3000-psi on May 24, 2015; a liquid leak rate of 0.041-gpm was observed at 3000-psi. On July 4, 2015, the Halliburton ACX leak detection tool located the leak in the packer at 7,541-ft. The objective of this procedure is to seal off the minor leak at this packer usincUWellLock Resin in order to continue to utilize this water injector until such time as a rig workover is necessary and can be scheduled. WeIlLock Resin Packer Seal Procedure Summary Digital Slickline (DSL)— Dummy Valve Change Out 1) RU DSL & support equipment. 2) RIH and pull dummy valve from side pocket @ 7484' and POOH. 3) RIH and install one way check valve (from tubing to inner annulus) in side pocket mandrel © 7484'. 4) RIH with wireline retrievable plug and set 1 foot below side pocket mandrel @ 7484' or as close as possible. Pump— Resin Treatment 5) Rig up pump and support equipment. Prepare to take returns from tubing annulus (7" production casing). Open tubing annulus. a. Circulate in freeze-protect, corrosion-inhibited water lead, and 2.5-bbl of 10.0-PPG �. WeIlLock Resin Seal. s— b. Circulate 5-bbl corrosion-inhibited water and 12-bbl Musol Resin Inhibitor. I Z. �kreaches check valve at end o�vo ume corrosion-inhibited water tail less 12-bbl; resin just Z�-- c. Circulate tubingvolume 36-bbl sof l ' 3e1Z Zy g+�— �y5 1 "\/C14./ft- i. Shutdown pump j d. As slow as possible, circulate 2.5-bbl corrosion-inhibited water which will pump resin Vv through check valve into the IA above the packer. S�' i. After pumping, shut down for minimum of 15 minutes to let resin settle in tk IA onto packer. e. Circulate 12-bbl corrosion-inhibited water which will pump 7-bbl of Musol through the CV and into the IA, and leave 5-bbl Musol in the tubing atop the WRP. i. Shut down f. Shut in tubing annulus (7" production casing) Slickline— Normal Up Well for Injection 6) Immediately following resin pumping, RIH with brush and tag WRP. Brush over check valve in side pocket mandrel 7,484' multiple times, each time tagging WRP. This also helps mix Musol ( (resin inhibitor)with any remnant resin left in wellbore. POOH. ( k 7) Retrieve WRP from 7495'. 8) Retrieve check valve in side pocket mandrel from 7484'. 9) RIH with dummy valve and set in side pocket mandrel © 7484'. 10) Retrieve catcher sub from 7638'. 11) Retrieve 2.75"WRP from 7640'. 12) Shut in well and let resin set for 7 days. DSL & Pump: (Pressure Test, Caliper, CBL) 13) Set plug in D-Nipple © 7751'. 14) Perform MIT-IA to confirm WeIlLock resin seal at packer. 15) Run caliper from 7751' (plug in D-nipple) to surface. 16) Run CBL from 7579' to surface. 17) Retrieve plug from 7751'. 18) Turn well over to operations for injection. ._ �� KUP INJ • 3N-12 ConocoPhillips Well Attributes Max Angle&MD 7D Alaska.Il1c. Wellbore API/UW Field Name Wellbore Status ncI(°) MD(ftKB) Act Btm(ftKB) c,.,, ,n,,,,,r 500292158200 KUPARUK RIVER UNIT INJ 49.37 3,500.00 8,115.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-12,4/520152:09:56 PM SSSV:TRDP Last WO: 39.49 4/21/1986 Vertical schematic(actuab Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,830.0 1/6/2015 Rev Reason:SET WRP 8 CATCHER,GLV C/O hipshkf 4/5/2015 i, Casfng ctrl .s$ HANGER,35.0 Casing Description OD in ID in TopftKB Set Depth ftKB Set Depth(TVD)... Wt/Len { ( 1 ( 1 (ftKB) P (ftKB) P (I...Grade Top Thread CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED sem. ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.0 4,087.8 3,552.2 36.00 J-55 BTC I, N C ing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread �I '. �'� ff 19 tKIT5 0 Seng 7 6.276 350 81017 6,699.4 26.00J55 BTC CONDUCTOR 380-110.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(. Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 35.0 7,757.9 6,411.9 6.50 J-55 EUE8rdABMod SAFETY VLV,1.780.7 I!'' Completion Details -i.. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 35.0 35.0 0.10 HANGER FMC TUBING HANGER 2.441 I 1,780.7 1,777.0 13.95 SAFETY VLV BAKER FVL SAFETY VALVE w/6'PUP 2.310 7,523.3 6,2172 34.42 PBR BROWN PBR 2500 7,541.0 5231.8 34.32 PACKER BROWN HB PACKER 2.875 SURFACE;370-40878 7,684.9 6,351.1 33.76 BLAST RING BTC w/ROCKET BLAST RING(7687-7714) 2.441 7,733.4 6,3915 33.64 SEAL ASSY BROWN SEAL ASSEMBLYw/LOCATOR 2.441 GAS Ur., FT;7,483.9 7,734.9 6,392.7 33.64 PACKER BROWN IB PACKER 3.250 7,751.9 6,406.9 33.60 NIPPLE CAMCO D NIPPLE 2250 11 g‘ PBR;7,523.3 7,7569 6,411.1 3358 SOS BROWN SHEAR OUT SUB 2441 D5 1 PACKER:7,5410 •" Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) J �� s Top(ND) Top Incl s Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,638.0 6,312.2 33.89 CATCHER 2.25"x24"CATCHER SUB 3/25/2015 GAS LIFT,7.579.0 7,640.0 63138 33.89 PLUG 2.75"WEATHERFORD WRP 3/25/2015 0.000 Perforations&Slots CATCHER:7.638.0 I_ Shot Dens PLUG,7,640.0 � Top(ND) Btm(ND) (shots5 al Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,6920 7,709.0 6,357.0 6,371.2 A-2,3N-12 7/14/1986 12.0 IPERF 5"SEQ Csg Gun,120 deg phase GAS LIFT;7,647.4 7,815.0 7,817.0 6,459.5 6,461.2 A-2,3N-12 9/24/1988 4.0 RPERF 21/8"EnerJet II,0 deg phase l 7,815.0 7,816.0 6,459.5 6,460.3 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg phase (PERF;7,692.0.7,709.0 7,817.0 7,819.0 6,461.2 6,462.8 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,817.0 7,818.0 6,461.2 6,462.0 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg phase GAS LIFT,7.718.7 7,819.0 7,824.0 6,462.8 6,467.0 A-2,3N-12 9/24/1988 4.0 RPERF 2 1/8"EnerJet II,0 deg 11. phase 7,819.0 7,820.0 6,462.8 6,463.7 A-2,3N-12 9/24/1988 5.0 RPERF 2 1/8"EnerJet II,0 deg i. SEAL ASSY,7,733.4 _ phase PACKER;77349 --.•• 7,832.0 7,844.0 6,473.7 6,483.7 A-2,3N-12 11/13/1991 4.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,844.0 7,846.0 6,483.7 6,485.4 A-2,3N-12 11/13/1991 6.0 RPERF 261/8"e EnerJet II,0 deg NIPPLE,7,751 9phase I 7,846.0 7,850.0 6,485.4 6,488.7 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg phase SOS;7.7569 7,850.0 7,854.0 6,488.7 6,492.1 A-2,3N-12 11/13/1991 6.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,854.0 7,855.0 6,492.1 6,492.9 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,855.0 7,857.0 6,492.9 6,494.6 A-2,3N-12 11/13/1991 6.0 RPERF 2 hase1/8"EnerJet II,0 deg RPERF;7.8150-7,816.0- p RPERF,7,8150-7,617.0- - 7,857.0 7,862.0 6,494.6 6,498.7 A-2,3N-12 11/13/1991 7.0 RPERF 2 1/8"EnerJet II,0 deg phase 7,862.0 7,870.0 6,498.7 6,505.4 A-2,3N-12 11/13/1991 1.0 RPERF 4"Jumbo Jet II Csg gun; RPERF;7,81.0-78180- 120 deg phase RPERF,7,817 0-7819 0- Mandrel Inserts St RPERF;7,8190.7,820.0- ati RPERF:7,819.0.7.824.0- N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 7,483.9 6,184.7 MMH FMHO 1 1/2 GAS LIFT DMY RK 0.000 0.0 2/12/1994 2 7,579.0 6,263.2 Merle TMPD 1 INJ DMY BK 0.000 0.0 3/25/2015 RPERF,7832.0-7.844.0 3 7,647.4 6,320.0 Merle TMPD 1 INJ DMY BKP 0.000 0.0 6/18/2002 4 7,718.7 6,379.3 Merle TMPD 1 INJ HFCV BKP 0.000 0.0 2/24/2010 RPERF,7,8440-7,846 0- Notes:General&Safety RPERF;7,8460-7,850.0- End Date Annotation - RPERF;7,8500-7,854.0- 6/12/1994 NOTE:WAIVERED WELL:T x IA COMMUNICATION - 1/18/2011 NOTE:View Schematic w/Alaska Schematic9.0 RPERF;7.8540-7,855.0- RPERF,7.855.0-7,857.0- RPERF,7.857.0-7862.0- RPERF;7,862.0-78700 I PRODUCTION;35 0-8.101.7 • 0 ......- --- HAUL/MUTON t.1 1•rnp OW ammo kw Avosisiac Pery 1 $port.vii USN loi 23 73 T1.4* I 44 137 , r 131.1.3 144.141 40 12,46F •• -...• 4111 ,........_r___• 17 30 = ElligiMirrial. imm=mm... .. 17 32 •• low•oftwwww•moot ..1 Temperature ----- Pial location log '-. 17 34 . 41111BWMI momerim• tr. ea:let a'.., -- starm showing --..........,--- 1733 '1 the leak_,t.-, 110.101111111111•••••••11M 1.111•1111111111•111 activity'2"from r .e - J 17 37 I annulate d- 4.01111111110111•111111•1 ................. stimulation 17 si - .............---- .................... --- -'—MI Mi.4111111011111...... 2'7" i r- 1741 ......1111.11•MIIIMIMIDINIMINI MINIIIMEMI .1•Mt•MIN• MN .....: „. 171 ... ..........ps "'" •ammoViram•••••••mom IIIIMINIONNI 1.11.1111.111 1744 ..a ..........a...a...a...a.... -............ Mb 1111110111.6a16101.3.111111111110111•111a 01•11kaliia, oa.a Ia.1111.00111111111.00 1110011•1111•11 an!.Malmo.,ser me." ' 1 i -,ti ...'';.,===""'" '"''=,..7–""" ...' .,'",,,""•-7-'• ,Z= - 1'AS 411014111111111111 $0.11111~MIN mar MI miottimmarealamaralair, _Atom / ...... 17 47 =...Imimr==---"..ini.i"."- ="--""".......7.7,_........................... 0.• . - =.'1==:.:................'=="T= -=:"....' I. - / , 1343 ....,aul•MB MN 0.1.••••• •••••••••••••••••11..--V.I.!AM IMS IIM1111111111111MINIM=11==111■11=f-ANIIIIMAIIIIIII 1 alde MN Wolaina aa a ocaar Zarapixam ...—..,1 17 53 11=1.1112/11•11111••••••••1111•011s ....MMIMMI 1172211E=MMEIT —— MEM 11 -2 _ -1 Acoustic amplitude ------- =t el and spectra:euixgy - = 17 33 mcrewie as the]eak dio ,i. got stimulred. ..._ rr. 17 57 .,.tar -.. . , .I la ati aniummammorra tnn-----marrmaramem _. a 16 44 313.1..M.1111111111111111111W MiaiNIMINIIIIIIIIP-1=11111 • .. ................ num === IIMINIMMI11,111•11111•••111••••11•1•010, 111•111011111/111MNIMI ‘1, Gonna limp 44444 lei 73 v m, raft 41 ,I.IINIIIIIIiiinel. ..6 in WINO Al NSF me Trp .t I., 'tcf HAULM Li n ToN Figure 5: Stationary log at top of packer(75411[Sins waveform' • 0 1-1A LLIEI Li R TON pi -ue4.”1.14 011m4.401314,1145 573441 0)00,1u1.13 10k07;311 Baal appin_12_79.',"1,4*n• At4F4 4.1.4.9W_41_004ftwolDikv4voroll IIIIIIEMIIIIIIIIIIIIIIIIIIIIIIIIIIII Tam ...OA 1.11A 1 ME 1. A,c...tr.Amp *moo Lae 5 4, .........,. 17:20 33 __ _:7____________' 2:q,,-.1,19`.:.-• -- 17 30.33 ...:.........,..._......=.::........,:.....,....t....:....,,......L-..±..,...!.._......_.-...L..._.... 17:31:30 --===--- --------- -----=-===== 1732'30 Temperature _ - ...„ =—...-------- — 17-35.30 M7R-1."-- the:eaks gets """'""'s Radial Loudon ktg 17:30:30 -- stimulatedrn slic 'wing ,9,.........,.......... activity--r from -=-_-=- t0,3 i 3333 post leak 17 30 33 ___________ ______ ..,, mulati El 1T:00:30 ----------- — 17 4130 "Z-11 ....,-7.7.-.=^a,...-r ..................., 17 42,0 _ _, _=---___ C 2=20120;85521:M.--:="21MEMICEM,,lotti its-am ,...earre,„.... gsr4asnmmtao....mssoeom...4..mmam_. . 17:45 30 =r==== :F.. ll 4010 21-?-e=1.1....4.1" 111Eitiriii 17;4730 - -- ". ----=-- 17 4440 --------,,.:-----=- 1749111 :.------__--:=.-_ ...-L.33.1-.-..c amphtude _ -.....:===.17.00 • - - —17.31.30 innease as tt2e:eak 919.......1 ...-2:..3.-: - ....- . ..,, ,... =,.-.1-..:.-1====:7 17.5430 _ - -175530 F- .,...........; ....,:.....,.. SIIIMISIMMS II 1119.11.60911111.10.1163.3491090N6 16.6.1....I 73D . 46:1,...,m,-/3 mow WMIP.T.T.M•m*, .....--. ..:77-..:.....—.7,-.......7...11 57 30 17.58:30 17 50 30 '71t%.7 rtigitehlrialtattHeilE'' -- _ ----------141.00:30 —= 141.01 30 le"gitg4530=0303171Waaram" __ •===._:.__ -=IF=,7,7:::..:L=ilvD2,30 - : 1003-30 01.01i40=0...ffi00=====1001.11a ., - ===-===.1841 SO 13U30 =111.1=1 4911011.90.1==.................,........—..a................* = 1000301 4411911•1 9011p 'CC 1.:C.,, :1 11111111r1111.1 Do99 11111111111111. EMU—MURTON P1411101'11-0111,10 13:40111 0..0 0540.10 171041 N.0041.11.41511k07141 Bala:cop3n 19 J9,11511en• Pkel.,Irz Igoe ir IS,`911,1,1411„%trdieNee Figure 6 Stationary log at top of packer(7541)[180rns waveform] • • HALLIESUPTON Pi time 234,4+-313:20 SO Mat Mange_74/9.17 it to IWO If DAM.vap3a_12_754O0111 LOOT_PLYCIhort lima(ethical* Maria datilli_eaastajkatatidelutaeloph CCL DO temp 0 7:11103 11 25 0 25 volts Dee Gamma Temperature Acoustic Amp Spactrain Radial Lac 0 BO DMA. 1?•',... ,:',t, D 25 0 50 kkz 1 5 tet " h 60i DaliF ......,..... ,- ' 74100 , " 75C0 .. Mereased acoustic Radkai lacauon 7510 - ,--"---- amplitude and indicates possible L ' ' - ' - ' spectral enerEv at -, beaks at miser 7520 packet.depth mating surface of 7._, Isaileillin MIIIIIt- 211111111=Mll padter withtubing ----numisemimmas and outer mating .....apiaminas surface with the iumniammummet production casing 7540 CD .... ........._ 7550 , I , -- "--.--• '' ,.. , Gamma Temperature *caustic Amp Spectrum Radial Lar 0 63 Dapati lt,, -it 11 2D 0 50 kks 1 ' ft add DegF + ,- CCL 00'HMI D 710051 1L25 025 volts DehF 1-4ALLIBURTC3N Met Rem 2341me-13011:30 02 PIM Renee 7479 17 it to 7576 at DM.eep3n,12,..7510801{MOT PLTtallett RUA riblefie mink irw,:_n_wsimacinnothotekiocrt, Figure 7: Up-it:tg from 7600 to 7500"past the Packer and PBR 17523')[5ms waveform] S • *4 ALLI.taLi n TON 1.1014 kit.0.4 PI ,.' All.t.tro Int2 MAXI ial4T PLTISWIn Saltier Mbar Mar& C CU Cif Twmp , .=...,• vats D.Ir . '..'*•+,1,. lo...nsfut. Ig....d.s.Arts .) Zo,.' Cineh '' ....." ="' ,.. , .,` 11.1111111 _ ''.g..-7. ...." •i three.......-........................,,6,0, =r....-................, . . „ 1.1%.31119MME 5.IE.1 . shm................ . . . . , ,...................... .........-................ al16-IMENOMI , MOW 41111111.1111N 5":' - ;..............: .........*...... ..„*.....,„„,,„...„, NM 180/2/1•11/ ,, ,. '"""`"`............. ' '',1' 111X,....•'7-7-4,,,,,,v0...,.d.;Am 7 --- '''1.- .- -s... ....... ' h ‘ . "= 0,... ...................-...SALIC ............... i . t 1111111.41/MOSNO/i ;4, .........--......-... ----------- . _........ .. , 1"All'-'-r--MIME-1 4•11111=111111.1111111111111111111111/111 :OVINIMIIIIIIIII:.'aill1111111111111111.1111111111M11111111 . „.„,,==............ ' ti1111111W11.111NIMIMONn ....... , woo ...wt. +Not D7Da .........off.'".7":".."""'"•....... 0..............,...e..rmiem. . =....a-....... =...= :,................. . . i...... .... ......1"rrlattglitant ........ 4951 1 i. ,. ===3. '....".".... _._ ....._. -- Increased a... ...-4.., aimmeni:. ——- —=--:,.....--=-•,... ,2 0,1 - i1,-- , ,,,,„„ amplitude and M',.trrn....I m. , 1-, ....................—. —I+ . , —,=-.....-.......—......... ,, : : ...../...........x.-- 1 . , .......................= . -- .......14.4.,-;,..- ,,,,,,,,t;2_,...4.....i:..,J, ..,,r —_ --..... -.mammy,. ...011111111/111r. -..... ' - _11111111.1111111.111 Or --.... .IiilliiiiilhollIO =-- = finiWiliila.:. .... .. U AO CCL air T/441 row D./1g 1 /.4ALLIBLItITCIN Pkv TA",,I.s..04S1f.0.1 S. AlArit...v.MO i It IV,NIS TS II .a.u.“a30.2..3110:191,111)TPC Triharr ftscIrr4,14.. KIM Figure 9: Up-log from 7.1390to 4900° • 0 HALueuRyaN Plot Time 21.Sep4S IS 46 31 Piot Ramp, 746127 It to 7677 64 ft Dots copart_12_751..*V4one Pry t..341:5JestUB,C4,Mletate*MaYAMI — it ne Tens4ort CCL DPI l'oono 400 10.412000 22000 0 2 0 25 lbs volts 0.6F Gamma TempertyAcoustic Amp Spocttuan Radial Loc 0 i 20 Devil i 60 0 ID It 0 SO kft2 1 aro --- — 4-- ..-:t ip MN MI 1111111111111511111111111/1 0 untimuM - . AIIIIIIIIIIIIIIIIIIIIMIIIMIMIN all .101111 I -----t MO ----- 751)0 =1116" _ _,_ ,;:,__ — - '4 --- i--- ,:.,LI , 111111111111111•1111M111111111111.1111111111111111.1111111 rainnhaMM 1 AMINISMINIS MCB1 ,111 _ IIMENIMMI i 1111111111rallit AMEN ..- 7520 illialmaillIMIIIMIIIIIIIM ..- . .91111111111111111111111111111111111011 ___ niamim ,_ "- -- AMMIIIMMUI INN=rim ; -.-.- IIIIIIIIIIItPJIIIIIIIIIIIIIIIIIIIIIIIIIIP 7A,,, -.......- RMMIIIIIOMIIIMIIIIIMIIINIIIIMIMIIIIIMIIMINIIIIIIIMIII Radial location Mil 411.11110111111MMINUT + -- ' matmates leak is at . •1 ... iimillcli _ •-2"from tool ans NEL 41111111111111111111111111111* '\. momni.nommommor- I .11811111111.11111111111MMAIIMUMI MOSIPteaMPENNEEN... AllI11111111111011111111111•1111 amirlinsisurussiams 111111,_ 111111111111111m711111111111111111F: , - 4 MIMINIMIPPnAMIIIIIIIIIIIIML. 7550 111 411111111.1111= 0 ingliLtollIMIII/1111111111111111. ma I- ti:, - --, i * = = -75e0 ' 111111111e '".1.101—* VVV : 11=111111 7570 fa 111 Ootaell Tpmperatop Aeotic Amp Spectmat KAPtotl Luc 0 120 Depth 150 150 0 ,0 0 5,1 kHz 1 5 in a LI ne Tervsmn COL 22,303,12S °4 ll 76n9 (3 24 It A NCO We volts De, HAI-L.1E31,-MT°N Pint ti...al-up-Ism 44 101 Plot Ramp748127 11 Al 7877.eift LJ$ V cop3p_12_760"."%lone PIPItIr 0116_13itontkikktEMOtOSMOorae0 Figure 8:Up-log from 7600'to 7500'past the Packer and PBR ii0Orns waveform] ^079 • 2 70`t- WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 0 8 2016 RE: Plug Setting Record: 3N-12 Run Date: 6/3/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21582-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 12`1 Signed: 1164-' MEMORANDUM To: Jim Regg ~~~c ~.~~ 6~i~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 13, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-12 KUPARUK RIV UNIT 3N-12 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv.-.~~ Comm Well Name: KUPARUK RIV UNIT 3N-12 API Well Number: 50-029-21582-00-00 Insp Num: mitJCr100411230507 permit Number: 186-079-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 4/9/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3N-1z i P.T.D 1860790 Type Inj. ~' TypeTeSt ~ SPT TVD Test ps ~ 6231 ' j ~lss7 ~ ! OA 2810 3410 340 ' ~ 410 3380 410 3380 410 Interval REQvAR p/F P ~ Tubing 2sao 2sao ~ 2sao 2sao Notes: MITIA per AIO 2B.034 '~~,~~~~ ,~~rl .x;' 1t~ ~U~ Tuesday, April 13, 2010 Page 1 of I f - Maunder, Thomas E (DOA) From: NSK Problem Well Supv [nl617 @conocophillips.com] Sent: Saturda Y, Ap ril 10 2010 8:53 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: 3N -12 MIT test form Attachments: KRU 3N -12 04- 09- 10.xls All, Attached is the MITIA performed on 3N -12 per AIO 213.034 on 04/09/10. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ®� ConocoPhillips Alaska, Inc., Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD t UNIT / PAD: Kuparuk / KRU / 3N DATE: 04 /09/10 OPERATOR REP: Ives / Hurley - AES AOGCC REP: John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 3N -12 I Type In . W TVD 6,237 Tubing 2,840 2,840 2,840 2,840 Interval V P.T.D. 1860790 T test P Test i 3000 2,810 3,410 3,380 3,380 P/F P Notes: MITIA per AIO 213.034 340 1 410 410 1 410 Weill I Type In'. I Tubing Interval P.T.D. T test Test Casi P/F Notes: OA Weill I Type In'. I TVD I Tubing Interval P.T.D. T test Test . P/F Notes: Weill I Type In'. TVD EE1 j90A Interval P.T.D. T test Test P/F Notes: Welli Type In. I TVD Tubi Interval P.T.D. I Type test I I Test psi I Casi P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3N-12 Run Date: 3/19/2010 April 1, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21582-00 Injection Profile Log ~~'.°•~~ ,.~~ ti ,~ ~;-t ~ `~, ~ Ij ~ 50-029-21582-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com ~~> ~~!9 Date: ,~ c ~ ~ :~ ? ~1' ..,-' . - ~ al ~~ Signed: • y/ • • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ti$~~~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 19, 2008 and the corrosion inhibitor/sealant;_was pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions, ;. Sincerely, ~% MG~~ ~~!?i~l~l~~'1 r~~~~ ~ ~~ 20~ ,~~ MJ La eland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~~e 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 MEMORANDUM • Toy Jim Regg ~% J Q P.I. Supervisor (1~d~ j~l ~ (w FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 01, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-12 KUPARUK RIV iJNIT 3N-12 Src: Inspector NON-CONFIDENTIAL Reviewed By: ~C P.I. Suprv Comm Well Name: KuPARUx RN UNIT 3N-12 API Well Number: 50-029-21582-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080930094652 Permit Number: 186-079-0 Inspection Date: 9/282008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-tz Type Inj. ~' I TVD 6232 IA 200o z99o z97o ~ z97o i P.T. 1860790 TypCTeSt SPT Test psi ~ 2990 OA i 360 390 ~ 390 ~ 390 ~ ~ Interval R1:QVAR p/F P - Tubing ~ zzoo zzoo i zzoo zzoo Notes' MIT-IA to max anticipated injection pressure ~- ~ 034 Z~ r ~ . ~ ~ a ~~ ;r r~~n~- Wednesday, October O1, 2008 Page 1 of 1 • STATE OF ALASKA ~~ ~ •.. ALASKA OIL AND GAS CONSE~ATtQN•CONJMISSION REPORT OF SUNDRY WELL OPERATIO#~JS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^ close 10-403 Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ '~,, 186-079 ' 3. Address: Strati ra hic Service ~ g p ^ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 `~. 50-029-21582-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' °`~ `~ 3N-12 8. Property Designation: 10. Field/Pool(s): ~ ADL 25520 ALK 2556 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured ~~~/~~ feet true vertical ~~t''I' ' ~i~7 , feet Plugs (measured) Effective Depth measured 7980 feet Junk (measured) true vertical 6596 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 4020' 9-5/8" 4088' 3552' PRODUCTION 7999' 7" 8067' 6670' Perforation depth: Measured depth: Depth frm 7692-7709, 7806-7824, 7832-7870' true vertical depth: Depths frm 6387-6371, 6452-6467, 6474-6505' Tubing (size, grade, and measured depth) 2-7/g", J-55, 7758' MD. Packers &SSSV (type & measured depth) pkr= BROWN 'HB' ; BROWN '1 B' pkr= 7541' ; 7735' SSSV= Baker FL SSSV SSSV= 1781' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: 9-659 contact MJ Loveland/ferry K in Printed Name MJ I~ovelan Title WI project Supervisor ~\~~~~ ~ Signature Phone 659-7043 Date 8/2/2008 ,~' ,~~ Form 10-4 4 Revised 04/2004 ~ ~ ~ ~ ~ ~ ~ Submit Origina~O~nl~ ~~~ 3N-12 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/01/89 Received Sundry 9-659 to inject water in well "as is" with TxIA ANN COM 07/02/08 Apply for AA for continued Water injection with known TxIA communication 07/24/08 Received AA AIO 26.034 for continued WI with know TxIA ANN COM 08/02/08 Send in 10-404 to Close Sundry 9-659 to inject "as is" with known TxIA ANN COM • • /E} KRU 3N-12 (~~ ConocoPhillips Alaska, Inc. Page 1 of 2 `~ Re James B DOA 99, ~ ) From: NSK Problem Well Supv [n1617@conocophillips.com] ~ Sent: Monday, July 21, 2008 6:37 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; Downey, Allison; Allsup-Drake, Sharon K; Charyna, Alexander Z (GSI); McMains, Stephen E (DOA) Subject: RE: KRU 3N-12 and KRU 1 G-01 Admin Approval Requests Jim, The preliminary answers to your questions are provided below in red fon#. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Gell 907-943-1720 / 1999 Pager 907-659-7000 #909 `~~~~~ AUC ~=~ 201 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 5:09 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: KRU 3N-12 and KRU 1G-01 Admin Approval Requests KRU 3N-12 - noticed the request included a provision for CPAI to install auto well shut in capability on OA; what is the reason for 90 day timeline for installation? (past approvals have required installation within 30 days) The 90 day timeline is to give us some flexibility around current activity level and parts availability. GPF3 started a plant turnaround on July 14th which is scheduled to end on August 30th. The parts have not been ordered yet and are considered long lead items with at least a 30 day delivery time. The well is currently shut-in and will likely remain so after August 30th until the OA F~IPP and accessories can be installed unless more than a 30 day grace period is granted. KRU 1 G-01 - request is for T and IA pressures to equalize, but that has rarely occurred in the past 2 years; since December 2007 the IA has been significantly higher than tubing and the increase in IA pressure appears to be coincident to a sharp decrease in injection pressure; do you anticipate operating at the higher injection pressure (between 2000 and 2500 psi as done in 2007)? Why the significantly increased injection rate since beginning of 2008? The 1 G- 01 records indicate that the well was shut-in from March 14, 2007 until December 5th, 2007. As a result of being shut-in, pressure data during this time does not accurately reflect actual well perForance due to the wellhead pressure transducer being isolated from the wellhead and in communication with the injection header. The significant increase in injection rate in December 2007 occurred when the well was returned to injection. In the course of investigating this well, I also discovered some SetCim inconsistencies between wells regarding the capturing and display of injection header and wellhead pressures, lam working with our Automation Group to understand the nature of the issue and a solution. At this time l believe this is the cause ~` ~~~°~ ;anomaly in reported injection pressures that occurred when we converted to a new method of generat ~~~ the Monthly Failed MIT report, - we will need a 10-404 to cancel sundry 9-659. A thorough search of well records at Kuparu and Anchorage revealed no sign of Sundry 9-659 for 1 G-01. Please forward a copy of the sundry to me sea that I can adequately 7/22/2008 Page 2 of 2 ~ ~ address your request. Assuming appropriate, the 10-404 will be forthcoming upon AA approval. - attached is the injection volume comparison 1 mentioned by phone today -note highlighted discrepancies between your SetSim Data and what has been officially provided to the Commission in monthly injection report (Form 10-406). l~ue to the 1 G-01 being shut-in for the entire months of April through November 2007, the data during this time should reflect no water injection. The CPAI Recounting Group reviewed the submitted 10-406 text files and 1 reviewed the submitted Monthly Failed MIT Reports and both appear to match the `'RBDM~ Water" column in the attached file. This also includes the slight variation in March 2008. With the data I have access to, I cannot explain how you acquired the "CPAB Water" numbers. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/22/2008 c,v -v.Y kt I" to- rt.»v) OLatc wt ivltt Yct 1 /- "-VI -r Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MA ©P %1YP AA # 2C -07 7" 26 ppf K-56 4980 3000 60% AIO 2B.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 2B.014 3A -06 7" 26 ppf J -55 4980 3000 60% AIO 28.008 3A -11 7" 26 ppf J -55 4980 3000 60% AIO 28.022 3A -14 7" 26 ppf J -55 4980 3000 60% AIO 26.026 3H -09 7" 26 ppf J -55 4980 3000 60% AIO 28.009 \%-fl 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 26.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor &L WL) NGV 1 7 2010 ConocoPhillips Alaska, Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 213.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 11J IU'71J7VJ Oi.aw Vry1Lm,3a%u ivui F%'l Div Z.L.vi -r i vi • • The AIO 2B.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. I You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AID 26.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 2B.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 -659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 L,kJ lr Iii I"IJ7V) JLaIG W1L11GJSGU 1vUIkilA pr'l tylV Gi7.Vl - t ragc J Vl J 0 0 Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 213.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 26.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xls>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 tsu~ai un lii~c~uvu VV Gll t\G~JVl Llll~ . Yage 1 OT 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ,~ Sent: Tuesday, February 19, 2008 1:34 PM ~ ~~~ z~ ~~~~ ~U~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk Injection Well Reporting Jim, Per our phone conversation, here is a list of injection wells that we are in the process of pursuing AA's for A1026. Each of these wells have been waivered under ConocoPhillips Well Operating Guidelines and reported to the State as a group on a spreadsheet in June 2007. They also may have been reported individually at the time of the waiver or in the first group report submitted 10/08/03. Up until this time ConocoPhillips has assumed that we had implied AOGCC consent to continue water injection in each well in its current condition. The purpose of this email is to ensure that we do indeed have consent for water injection and to notify the State that AA applications are in progress. 1A-12 - 181-178 - IAxOA communication ~, ~ ~ ZOu~ ~~~3~i~~ S~? ~, 2V-02 - 18 -161 -Minor IAxOA commun~tion 3N- - 186-079 - ow 3N-13 - 186-081 -Slow xIA 1 C-10 - 182-193 - IAxOA communication Wells 1A-12, 2V-02, 3N-12, and 1C-10 were added to the Monthly injector report this month. 3N-13 is already on the report. Please let me know if you have any questions or if additional reporting or action (other than the AA applications) is required. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/13/2008 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Thursday, August 19, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-12 KUPARUK RIV UNIT 3N-12 TO: Jim Regg í?, $(7-4/04- P.I. Supervisor I)~ fi Src: Inspector Reviewed By: ...-./)~ P.I. Suprv ,..\C1¿..-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3N-12 API Well Number: 50-029-21582-00-00 Inspector Name: Jeff Jones Insp Num: mitJJO40818102340 Permit Number: 186-079-0 Inspection Date: 8/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-12 Type Inj. S TVD 6697 IA 2970 3450 3440 3420 3410 P.T. 1860790 TypeTest SPT Test psi 1558 OA 300 340 340 340 340 Interval INIT AL P/F P Tubing 2960 2960 2980 2980 2980 Notes: Test held additiona115 minutes to demonstrate integrity. .5 BBLS diesel pumped. Thursday, August 19,2004 Page 1 of] T NOV 0 rd, i995 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Metrical I~tegrity Test Gas Cons. Commission /mchorage OPERATOR: ARCO Alasle Ino.. FIELD ! UNIT 1 PAD: KPFt KRU, DATE: ! 1/$/95 ~~~-~ ~iii'''''~- -''- L--'~i.. 1~ M I DIESEL 7,8~ 7~ 2~. K-~ 3.S CO~EN~ ~'ESS ~D ', Z~40 ~0 ' COMMENTS WITNESS ~P .,. , . C~MENT8 ~NESS ~P , COMMEN~S: DISPO~L N DIE~L 28~ 7; 2~,~ ,F 2.875 J COMMEH~: q'U~ING INJECTION FLUIDt PRODUCED WATER INJ. 8ALT WATER 1NJ ,=,.J~C~O.SCANNED DEC 1 9 2002 ANNULAR FLUID: P.P,G. Grad. W~LL TEST: DIESEL 6. ~ 6,36 InilieJ GLYCOL i O. 00 4 - Ye~tr SALTWATER I O. 00 Worth,er DRILL1NG MUD [ 0,00 (:][h~ OTHER I Cj. 0 0 Dislribmior: mg- V~l File' c - Oi:rala' c-Tdp Rpt Ftc. AOGCC REP SI GNATURE OPERATOR REP $1GNAIU RE P~ge I WVD gY J. HERRING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stlmulale _ Change approved program _ Pull tubing_ Variance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 68 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 set, ce x Kuparuk Unit 4. Location of well at surface 8. Well number 3716' FNL, 128' FEL, Sec. 29, T13N, R9E, UM (asp's 518271, 6013799) 3N-12 At top of productive interval 9. Permit number / approval number 1719' FNL, 1557' FWL, Sec. 33, T13N, R9E, UM 186-079 At effective depth 10. APl number 50-029-21582 At total depth 11. Field / Pool 1939' FNL, 3584' FEL, Sec. 33, T13N, R9E, UM (asp's 520112, 6010303) KuParuk Oil Pool 12. Present well condition summary Total depth: measured 8115 feet Plugs (measured) true vertical 6711 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16" 247 sx cs iii 110' 110' SUR. CASING 4020' 9-5/8" 115o sxAS III & 300 sx Class G 4088' 3552' PROD. CASING 7999' 7' 3oo sx C~ass G & 178 sx AS ~ 8067' 6670' Perforation depth: measured 7692-7709; 7815-7815; 7817-7817; 7819-7819; 7844-7844; 7846-7846; 7~ii0~ 7854-7854; 7857-7870; 7806-7824; 7832-7862 ~i '~,. ~.. ~.,~.._.~' '{~: :;,.,I- !'!~. true vertical 6357-6371; 6459-6459; 6461-6461; 6463-6463; 6484-6184; 6485-6485; 648~6489; 6492-6492; 6495-6505; 6452-6467; 6474-6499 :Tubing (size, grade, and measured depth 2-7/8',6.5#, J-55 Tog e 7758' MD. AI~S!¢3 Packers & SSSV (type & measured depth) BROWN 'HB' ~ 7541' MD; BROWN '16' ~ 7735' MD; BAKER 'FVL' ~ 1781' MD. la. Attachments Description summary of proposal __X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: October 15, 2001 16. If proposal was verbally approved 10/12/01 Oil__ Gas ~ Suspended Name of approver Tom Maunder Date approved Service_X Water Injector on Temporary flowback(pressure reduction for drilling) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 'JeffA. Spencer ~ Title: Production Engineering Supervisor Date Prepared b~/ Robert Chdstensen 659-7535 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug inlegrily_ BOP Test __ Location clearance --I '~-~ '"'/¢')~'~"'~ Mechanical Integrily Test__ Subsequent form required 10- Approved by order of the Commission ,~ ~,/ ' Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3N-12 DESCRIPTION SUMMARY PROPOSAL R~ 3N-.QB &.3N-12 temp change in service~'*~ Subject: Re: 3N-08 & 3N-12 temp change in service 'Date: Fri, 12 Oct 2001 17:01:08-0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Ok, will do. Thanks! Jerry Tom Maunder <tom_maunder@admin.state.ak.us> 10/12/01 04:45 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 3N-08 & 3N-12 temp change in service Jerry, Looks like it is hoped that 1 month backflow will be enough, but that is unknown. I think in these cases you should likely go the full paper route. Sorry for the hassle. I will give you verbal approval to proceed as you have planned. Thanks. Tom NSK Problem Well Supv wrote: > Tom: Several months ago we had a discussion about temporary change of > service from injection to production for reservior pressure reduction prior > to drilling nearby wells. At that time you suggested for up to a month the > conversion notification could be done by email. For a month or more the > 10-403/10-404 process would be required. The following email is from one of > our PE's asking about temporary conversion of 3N-OSA and 3N-12 from > produced water injection to production for pressure reduction. These two > wells fall right about the break in that time interval. Would you please take a look and see if this is adaquate notification, or should we submit the 10-403/10-404 ? Thanks! Jerry Dethlefs Phillips Problem Well Supervisor --- Forwarded by NSK Problem Well Supv/PPCO on 10/12/01 03:45 PM .... CPF3 Prod Engrs 10/12/01 03:08 PM To: NSK Problem Well Supv/PPCO@Phillips cc: NSK Prod Engr Tech/PPCO@Phillips, R Tyler Senden/PPCO@Phillips, Guy > Schwartz/PPCO@Phillips, CPF3 DS Lead Techs/PPCO@Phillips > Subject; 3N-08 & 3N-12 temp change in service 1 of 2 4/26/02 3:23 PM Re~'-3N-08 &,3N-12 temp change in service > Jerry, > Please email Tom Maunder to notify him (in lieu of form f0-#03) we will be > backflowing PWI Wells 3N-O8A and 3N-12 temporarily for drilling pressure reduction of 3N- ~ 9. 3N-O8A and 3N- 12 are currently being hooked up for backflow of produced water injection to lower pressure for 3N-19 new well scheduled for Dec 2001. 3N-O8A has been SI since 9/13 and 3N-12 has been SI since 10/3. SBHPs have not dropped enough to allow drilling to safely drill 3N-19. We plan to backflow these 2 wells for about 4 weeks then SI to check > pressure. If the pressure is still high, the wells will continue to be on > backflow until the rig arrives in Dec. The wells will be SI when the rig > arrives and then BO/after 3N-19 is completed. > 3N-O8A is in the isolated fault block that 3N-1.9 will be drilled into. > There are no producers to draw the pressure down. SBHP measured 10/3 was > 3827 psi. > 3N- 12 is just on the other side of the fault from 3N- 19's proposed > location. Drilling requires the pressure reduction due to safety concerns > in case there is communication across the fault. SBHP measured 10/3 was > 5368 psi. > Thanks, > Marie (See attached file: tom_maunder, vcf) Tom Maunder <tom-maunder@admin.state.ak. us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 4/26/02 3:23 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of OPerator PI'fillips Alaska, Inc. 3. Address P_ O. Box 100360 Ar~chorage, AK 99510-0360 Operation shutdown_ Plugging _ Pull tubing _ Repair well _ 4. Location of well at surface 3716' FNL, 128' FEL, Sec. 29, T13N, RgE, UM stimulate _ Alter casing _ 5. Type of Well: Develeprnenl _ Exploratory _ Stratigraphic _ Service__X (asp ' s 518271, 6013799) Perforate _ Other _X Temp Prod to WAG 6. Datum elevation (DF or KB feet) RKB 68 feet 7. unit or Property name Kuparuk Unit 8. Well number 3N-12 At top of productive interval 1719' FNL, 1557' FWL, Sec. 33, T13N, RgE, UM At effective depth At total depth 1939' FNL, 3584' FEL, Sec. 33, T13N, RgE, UM (asp's 520112, 6010303) 12_ Present well condition summary -Total depth: measured true vertical 8115 feet Plugs (measured) 6 711 feet 9. Permit number / approval number 186-079 / 10. APl number 50-029-21582 11. Field / Pool Kuparuk Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth CONDUCTOR 110' 16" 247 sx cs ,I 110' SUR. CASING 4020' 9-5/8" 115o sx AS III & 300 sx Class G 4088' PROD. CASING 7999' 7" 300 sx c~ass G & ~75 sx AS I 8067' True vertical Depth 110' 3552' 6670' Perforation depth: measured 7692-7709; 7815-7815; 7817-7817; 7819-7819; 7844-7844; 7846-7846; 7850- 7850; 7854-7854; 7857-7870; 7806-7824; 7832-7862 true vertical 6357-6371; 6459-6459; 6461-6461; 6463-6463; 6484-6184; 6485-6485; 6489-6489;, 6492-6492; 6495-6505; 6452-6467; 6474-6499 Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 7758' MD. Packers & SSSV (type & measured depth) BROWN 'HB' @ 7541' MD; BROWN 'lB' @ 7735' MD; BAKER 'FVL' @ 1781' MD. 13. Stimulation or cement squeeZe summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Waler-Bbl 933 Casing Pressure Tubing Pressure 2150 131 1799 2150 1301 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well OperalJons Oil __ Gas __ Suspended __ Service _X WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. $iSn ed'J~' ~' s¢~ ~r~ ]~~;~' '' ¢ Title Production Engineering Supervi sot Questions? Call Jeff Spencer 659- 7226 To: Tom Maunder, AOGCC From: Rowland Lawson, Marathon Oil Compm~y, Tel¢ 907-252-1913, Fax 907-2~ Date: 12-18,2001 Subject: Weekly BOP test. 2~6700 Tom .......My weekly BOP test is due 12-19-2001 12:00hrs. I mn currently on th~ Susan Dimme workover. I will be ,m,~,ning 4.5" casing and cementing tomorrow. The 4~" easing is being run inside 9 5/8 casing with no open hole seeti0n. Because I am ~o near the end of the well I would like to ask for an exemption on my weekly BOP test. | Sincerely, Rowland C. Lawson ~-/t- ~OYd .~d~':~ ~O-B~-O~O .~00/..@ ~ !O~g J.~F'U~$¥9 dH :AS STATE OF ALASKA ALASKAOIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Aller casing _ Hepa~r Well _ ~ugglng _ I line exqensmn _ ~[~mu~ale _ Change approved program _X Pull tubing _ Variance _ Perlorale _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) .Phillips Alaska, inc. Development__X RKB 68 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 ser~__ Kuparuk Unit 4. Location of well at surface V~ ,~ .,./ 8. Well number 3716' FNL, t28' FEL, Sec. 29, T13N, RgE, UM (asp's 518271, 6013799) ~,3N'12 ,At top of productive interval 9. Permit numb~ ~pproval number 1719' FNL, 1557' FWL, Sec. 33, T13N, RgE, UM 186-079 ,v ,At effective depth 10. APl number 50-029-21582 ,At total depth 11. Field / Pool 1939'-FNL, 3584' FEL, Sec. 33, T13N, RgE, UM (asp's 520112, 6010303) Kuparuk Oil Pool 12_ Present well condition summary -I'otal depth: measured 8115 feet Plugs (measured) true vertical 6711 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 16' 247 sx cs m 110' 110' SUR. CASING 4020' 9-5/8' ~lso sx AS m &.300 sx Class G 4088' 3552' PROD. CASING 7999' 7' 300 sx Class G & 175 sx AS I 8067' 6670' Perforation depth: measured 7692-7709; 7815-7815; 7817-7817; 7819-7819; 7844-7844; 7846-7846; 7850-7850, 7854-7854; 7857-7870; 7806-7824; 7832-7862 true vertical 6357-6371- 6459-6459; 6461-6461- 6463-6463; 6484-6184; 6485-6485; 6489-648~, 6492-6492; 6495-6505; 6452-6467; 6474-6499 Tubing(size, grade, and measured depth 2-7/8",6.5#, J-55 -rbg O 7758~ MD. RECEIVED :Packers & SSSV (type & measured depth) BROWN 'HB' ~ 754~' MD; BROWN 'lB' ~ 7735' MD; DEC 1 0 2001 , 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: ~ 0~l & January 1, 2002 16. I f proposal was verbally approved Oil __ Gas __ Suspended _ Name of approver Date. approved Service_X Water. Injection " 17. I hereby certtty that the toregoing Is-true and correct to the best ct my knowledge. Questions? Call Jell Spencer 659-7226 : r-roouc~on ~:ng~neenng 5upervmor Date ~/f A. spencer Prepared b? Robe~ Christensen 659-7535 FOR COMMISSION USE ONLY Plug integrity __ BOP Test _ Location clearance _ - . Mechanical tntegrily Test-~. ~!;~ Subsequent form required 10- Approved by order of the Commission Original Signed By ....... ~__~._,: Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE 3N-12 DESCRIPTION SUMMARY PROPOSAL Phitlipas Alaska Inc. is requesting approVal to convert 3N,12 from temporary oil production to Water injection .service.' 3N~12 was put on :backflow in .November 2001 for reservoir pressure reduction in Support of new well drilling operations:for 3N"t . 3N-12 will be turned to Water injection service after 3N, 19 is cased. Tom, Here's a short summary regarding the status of 3N-08A and 3N-12. Both wells were temporarily converted to production to reduce reservoir pressure in the area so that drilling operations could safely commence on 3N-19. Because the wells were expected to be produced longer than 4 weeks, PAI filled out Sundry Form 10-403 and 10-404's for the temporary conversion of these wells. Sundry Form 10-403's were recently filled out to return the wells to water injection service once 3N-19 drilling operations are completed (approx. the first week in January). Once the P-to-I conversions are actually completed, Sundry Form 10-404's will be generated and forwarded to the AOGCC. ·" I-tb-P I-to-P P-to-I P-to-I '1'0-'403 ' 10-404 10-403 10-404 3N-08A ''WI 09/07/91 10/14/01 10/29/01 " 12/09/01' Jan. '02 '. 3~:~2... WI 04/01/87 " 10/'i4/01 .... i'0/29/01 12/09/01' Jan. '02 Let me know if you need anything else. Jeffrey A. Spencer Production Engineering & Offiake Supervisor Phillips Alaska, Inc. 907-659-7226 Slope jspencer~ppco.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 68 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 3716' FNL, 128' FEL, Sec. 29, T13N, R9E, UM (asp's 518271, 6013799) 3N-12 At top of productive interval 9. Permit number / approval number 1719' FNL, 1557' FWL, Sec. 33, T13N, R9E, UM 186-079/ At effective depth 10. APl number 50-029-21582 At total depth 11. Field / Pool 1939' FNL, 3584' FEL, Sec. 33, T13N, R9E, UM (asp's 520112, 6010303) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8115 feet Plugs (measured) true vertical 6711 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 11 O' 16" 247 sx cs m 11 O' 11 O' SUR. CASING 4020' 9-5/8" 4450 sx AS m & 300 sx C~ass G 4088' 3552' PROD. CASING 7999' 7" 3o0 sx C~ass G & 475 sx AS ~ 8067' 6670' Perforation depth: measured 7692-7709; 7815-7815; 7817-7817; 7819-7819; 7844-7844; 7846-7846; 7850-7850; 7854-7854; 7857-7870; 7806-7824; 7832-7862 true vertical 6357-6371;6459-6459; 6461-6461;6463-6463; 6484-6184; 6485-6485; 6489-6489; 6492-6492; 6495-6505; 6452-6467; 6474-6499RECEIVED Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 7758' MD. Packers& SSSV (type & measured depth) BROWN'HB' @ 7541' MD; BROWN'IB' @ 7735'MD; U0V 0 (~ 2001 BAKER 'FVL' @ 1781' MD. 13. Stimulation or cement squeeze summary Alaska 0il & Gas Cons. C0mmissi0[~ Intervals treated (measured) N/A Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci' Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 624 390 2885 Subsequent to operation 2680 390 150 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __ Gas _ Suspended __ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed "~ "~.~--~~" Title Production Engineering Supervisor Date //-os-o/ Jeff A. Spencer-- ~ Prepared by Robert Christensen Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE ~'~ 3N-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1.0/20/01.1 !njection Well put,on tempera~ flowback to production for reservoir pressure reduction · I .. MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF AI.ASKA ' ~ ~ OIL AND GAS ~VATION CCMM~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator 15. I ARCO A!a.~ka. Inc. 3. Address P. O. Box 100360, Anchora~le, AK 99510 4. Location of well at surface 1561' FSL, 130' FEL, SEC.29, T13N, R9E, UM At top of productive interval 1719' FNL, 1557' FWL, SEC.33, T13N, R9E, UM At effective depth 1870' FNL, 1657' FWL, SEC.33, T13N, R9E, UM At total depth 1933' FNL~ 1699' FWL~ SEC.33~ T13N~ R9E~ UM 12. Present well condition summary Total Depth: measured 81 0 0' fe~t true vertical 6697' feet Stimulate Plugging . Perforate ~ Repair well Other X Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 68' 7. Unit or Property name Kuparuk River Unit 8. Well number I3N-12 9. Permit numbe, r/a_pproval number 86-79 / fi- (~5'c~ I ' 10. APl number 50-029-2158200 I11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 7 9 8 0' feet true vertical 6 5 9 6' feet Casing Length Structural 80' Conductor 4 0 5 1 ' Surface Intermediate Production 8 0 3 0' Liner Perforation depth: measured 7692'-7709', true vertical 6355'-6370', Junk (measured) Size Cemented Measured depth True vertical depth 1 6" 247 SX AS II 110' 110' 9-5/8" 1150 SX AS III & 4088' 3552' 300 SX CLASS G 7" 300 SX CLASS G & 8067' 6670' 175 SX AS I 7806'-7824', 7844', 7846', 7850', 7854', 7857-7870' 6452'-6467', 6483', 6484', 6488', 6491', 6493'-6504' Tubing (size, grade, and measured depth) Packers ~d SSSV (~ ~d ~ured depth) BROWN lB PKR ~ 7735, BROWN HB PKR ~ 7541'/BAKER FVL ~SV ~ 1781' 13. Stimulation or ~ment squ~ze summary CONTINUED INJECTI~ 'AS IS'. Inte~als treated (me,urn) Alaska Treatment ~scription incl~ing volumes us~ and final pr~sure 14. Reoresentative Daily Averaae Production or In!action Data OiI,Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1667 2900 2499 Subsecluent to operation 0 0 1362 15. Attachments [ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector __ Daily Report of Well Operations Oil c.~ S~J_~r_nended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2900 2487 U Form 10-404 Rev 09/12/90 Title Petroleum Engineer SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CC~SERVA~N COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ 2. Name of Operator AR(~O Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing _ Variance _ Perforate _ Other X 5. Type of Well: Development Exploratory Stratigraphic Service Sec. 29, T13N, R9E, UM 4. Location of well at surface 1561' FSL, 130' FEL, At top of productive interval 1719' FNL, 1557' FWL, At effective depth 1870' FNL, 1657' FWL, At total depth 1933' FNL~ 1699' FWL~ Sec. 33~ T13N, R9E, UM 12. Present well condition summary Total Depth: measured 81 0 0' feet true vertical 6697' feet Sec. 33, T13N, R9E, UM Sec. 33, T13N, R9E, UM Plugs (measured) Effective depth: measured true vertical 7980' feet Junk (measured) 6596' feet Casiog Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 4051' Size 16" 9-5/8" 803O' 7" measured 7692'-7709' @ 12 SPF; 7854'. (all single shots); true vertical 6355'-6370', Cemented 6. Datum elevation (DF or KB) 68' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-12 / /J :~ ~ c F o /z. -- 9. Permit number 86-79 feet 10. APl number 50-029-21582 11. Field/Pool Kuparuk River Field .Kuparu~.,.,River Oil Pool '-i . ~1 .i i Measured depth True vertical depth 247 Sx CS II 1 1 0' 1 1 0' 1150 Sx AS III & 4088' 3552' 300 Sx Class "G" 300 Sx Class "G" 8 0 6 7' 6 6 7 0' 175 Sx AS I 7806'-7824' @ 4 SPF; 7857'-7870' @ I SPF 6452'-6467', 6483', 6484', 6488', 7844°, 7846', 7850', and 6491', and 6493'-6504' Tubing (size, grade, and measured depth 2 7/8", 6.54t J-55 AB mod. tubing set at 7758" Packers and SSSV (type and measured depth) Brown lB pkr ~ 7735'~ Brown HB pkr. ~ 7541'~ Baker FVL SSSV ~ 1781' 13. Attachments Description summary of proposal ~ Detailed operation program _ Request sundry approval to continue water injection "as is" 14. Estimated date for commencing operation 115. Status of well classification as: July. 1989 I Oil __ Gas __ 16.If proposal was verbally approved Name of aPProver Date approved Service Water In!action Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~//_.4./~ ,~ ,~~. ~,l,/~l~ ~,c,,~.~"~Title Sr. Operations Engr. Date ' ~1" -' FOR COMMISSION USE ONLY Conditions Of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- ~) Approved by the order of the Commission Form 1D-403 Rev 5/03/89 Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH BOP sketch Suspended _ IApproval No. Approved Copy Returned SUBMIT IN TRIPLICATE Application for Sundry Approval Kuparuk Well 3N-12 July 10, 1989 Kuparuk Well 3N-12 has a suspected leak between the tubing and the 7" casing. Sundry approval is requested in order to continue water injection into this well "as is". As described in the attached well history, the 7" casing pressure has been above 2000 psi since January of this year. The well passed a state witnessed M.I.T. on April 1, 1987 and an in-house M.I.T. on June 19, 1989, and there is no indication that the casing to formation integrity has deteriorated. Kuparuk Well 3N-12 Well History April 1986' July 1986: September 1986: April 1987: April 1988: November 1988: January 1989' March 1989: June 1989' Began drilling well. Completed well. Placed well on production. Well passed state witnessed M.I.T and was converted to water injection. 7" casing pressure = 1000 psi. 7" casing pressure = 1500 psi. 7" casing pressure = 1800 psi. 7" casing pressure = 2000 to 2300 psi. The 7" was bled down to approximately 1000 psi several times during February, and built back up to 2000 to 2300 psi within 2 or 3 days. Decreased allowable header pressure to 2000 psi. 7" casing pressure = 2000 psi. Increased allowable header pressure to 2500 psi. 7" casing pressure = 2500 psi. Well passed an in- house M.I.T. ARCO Alaska, In~.., Sul:)slcliary of Atlantic Ricflfiel(~ Comp WELL jPBDT '7~80 FIELD - DISTRICT- STATE CONTRACTOR OPERATION AT REPORT TIME REMARKS ~.,30 O.~ 'q~, J~/~.. WELL SERVICE REPORT JDAY~ DATE ~-~- 073° "7" xzl'~v'v'~ '...~ o9 O0, Olt'3 o . "1'~,1o, v (,, '- " - ZO ~ro /o "- ~'oc, ~j~' ~,0,"- coo p~,,[. CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather. i Temp. * Chill Factor ' Visibility Report i °F! °F: miles Wind Vel. knotsI ~ ~ ALASKA OIL AND GAS ASERVATION CI'I~D4ISSION .HEOIANICAI. IDflTgRI'FY TEST ....... PP, kt~f' b'rART 15 ~flN 30 ~ .... *P *~ TYP~: OF Ptm c.~smc T~ ~,~ T~ TIaa.: ~.Y~n;.-~ T~--- ~ ,s --- ~ ~ S~Z£1~4rI(.itAD£ SlZg ~'£ CSG T~G 'rUG ~'1'1 ~1 }~lJ 1 D ~ PRESS PLIES S USC. CSG CSG PRESS PR .15.qS PRESS 0~o o ] _ . , ~ ~ ~ ~ . ~ ,,,n . ~ , ,, ],., , s, , ,, ~ , ~ k ~ .... , . . k ,., ,,, ~ ~, ~ . _ _ ~ ,, ,, t ,, ,,, ,,,,, . ,,, ,,, , . , ,,, ~ ,, . ,, ; ,, ,, ,, ,,, ,,, _ , , , ,,, , , ..,,,, ., . , ,, ,,, ~ ., . ,,, ..... i i i mil iii ii iii · i , ,= ,= i *TUBI~ IRIELTIEIq FUJID: S ' SALT Ilallffi INA N - NISCIBLE INJECTION · · .. D.I~IS.06 AOGCC ~IINI~S SIGNA~ 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 2.5.252 (d) KUPARUK WELL 3N-12 APl #: 500292158200 SPUD DATE: 04/14/86 ADL LEASE: 25520 PERMIT #: COMPLETION DATE: 07/15/86 WORKOVER DATE: 86-79 · ORIGINAL RKB: SURFACE LOCATION: 1561 'FSL,130'FEL,SEC29,T13N,RgE TOP OF KUPARUK: 1719'FNL,1557'FWL, SEC33,T13N,R9E TD LOCATION: 1933'FNL,1699'FWL, SEC33,T13N,RgE All deplt~ are MD-RKB to 1=p of equil=merit unlea~ olhenvbe noled 68 TUBING SPOOL: 35 PAD ELEVATION: WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 110 9.625' 35~ ~55 40~8 7' 26a J~S 8d67 2.875 6.5~ &55 ABMOD 7758 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER FVL 2.31 · 1781 SBR BROWN PBR 7523 PKR BROWN HB 7541 PKR BROWN lB 7735 NOGO CAMCO 'O' NIPPLE 2~5' 7753 MISC. DATA' DESCRIPTION KICK OFF POINT: MAX HOLE, ANGLE: 49 HOLE ANGLE THRU KUP: 34 LAST TAG DATE: 09/24/88 RATHOLE: 24 RS~UCTION: degI DEPTH GA~ UFT and FLOW INFORMATION VALVE 1 7484 2 7579 4 7719 PORT MANDREL SIZE SIZE MCMURRY HUGHES 1.5" DV MERLATMPO 1.0" CV MEFU_~ 114P0 1.0" CV MERLATMPD 1.0" CV PERFORATION DATA INTERVAL ZONE FT SPF PHASE COMMENTS 7692-7709 C204 17 12 120 780~-7824 A3 18 4 REPERF 7844-7844 A2 0 SS 7846-7846 A2 0 SS 7~50-7580 A2 0 SS 7854-7854 A2 0 SS 7857-7870 A2 13 1 . REVISION DATE: REASON: 05/19/89 NEW SCHEMATIC ARCO Alaska, Inc. Post Office BG ..... 00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 3N-12, 3N- 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 ,Fractures and Stimulations · 3K-14, 3C-16, 3K-17, 3N-11, 3F-11 and 3N-8A I E-30 1E-14, 3N-17, 3F-16 and 2V-12 Perforations Failed MIT If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEI.VED NOV :1. 6 1988 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARCO Al~lska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1561' FSL, 130' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1719' FNL, 1557, FWL, Sec. 33, T13N, R9E, UM At effective depth 1870' FNL, 1657' FWL, Sec. 33, T13N, R9E, UM At total depth 1933' FNL, 1699' FWL, Sec. 33, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 8100' M D feet true vertical 6697' MD feet 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-12 l/~-~ 9. Permit number/approval number 7-206 10. APl number 50-029-21582 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) NONE Effective depth: measured 7980' MD feet true vertical 6596' MD feet Junk (measured) NONE Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 110° I 6" 247 Sx CSII 110' MD 110' TVD Surface 4049' 9-5/8" 1150 Sx ASIII 4088' MD 3551' TVD Intermediate & 300 SX Class G Production 8028' 7" 300 Sx Class G 8067' MD 6669' TVD Liner & 175 Sx ASI Perforation depth: measured 7692'-7709', 7815', 7817, 7819', 7844', 7846', 7850', 7854', 7587'-7870 13. true vertical6355'-6370', 6458', 6460', 6462', 6483', 6484', 6488', 6491 ', 6493'-6504' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, 7758' MD Packers and SSSV (type and measured depth) Brown HB Packer- 7541' MD; Brown lB Packer- 7735' MD; Baker "F. '~,.~,.,-~- ' D Stimulation or cement squeeze summary Intervals treated (measured) · & Gas G0ns. C0ma'tss~0n Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Iqjection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 258 128 0 250 130 , Subsequent to operation 0 0 911 1 1 00 1 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas Suspended Service W~ter Iniecti0n 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ARCO Alaska, In,~ ,S~l~idia~ ot Atlantic Richfield Comp& WELL IPBDT ,5~/- 12. CONTRACTOR ..... YE~O . FIELD- DISTRICT. STATE OPERATION AT REPORT TIME WELL SERVICE REPORT /p~,o-. ~/~ uP /~,e~5o-, /'40,~ ~0 ~ V'~CO., ~PeE55J~F_. OP' '7" ~knch0racJu I-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK '1 Weather ii Temp. Chill Fact I Visibility Wind Vel. Report i °F qFI milea I Signed knot~ J ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, I987 Transmittal Return to: Transmitted receipt and 3H-7 3H-6 3H-I1 3N-I2 3N-t0 3J-16 3J-15 1A-8 2Z-7 2Z-7 2Z-7 2Z-7 ARCO Alaska, Inc- Attn: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 'Anchorage, AK 99510-0360 herewith are the following items. Please acknowledge retUrn one signed copy of this transmittal. CET 4-1-86 6202-7597 CET' 4-1-86 6061-7583 . CET 4-22-86 7600-8675 CET 4-29-86 6396-7965 CET 4-14-86 7462-9130 CET 3-29-86 7704-8727 CET 3-29-86 7400-8398 CET 1-5-86 5755-6154 CET 4-14-87 8250-8491 CRT 4-12-87 8246-8595 Squeeze & Retainer Record 4-15-87 8250-8491 Squeeze, BP & Retainer Record 4-12-87 8290-8588 ~ Alast(a 0ii & .G~.nC0~~ Commission Receipt Acknowledged: DISTRIBUTIOH: NSK Drilling Chevron Hobil Date: 'iJState of Alaska (* sepia) SAPC Unocal Vault BPAE (film) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office _ , !00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 24, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are intent notices on Kuparuk Wells 1A-14, 3N-3, 3N-12 and 3N-13: We 11 Ac t i o n Anticipated Start Date 1A-14 Failed Test March 30, 1987 3N-3 Conversion April 1, 1987 3N-12 Conversion April 1, 1987 3N-13 Conversion April 1, 1987 If you have any questions, please call me at 265-6840. Sincerely, ._~.,:~/' .:~ ..~-~-~-~- G. B. Sma llwood Senior Operations Engineer GBS:pg:.O081 Attachments cc: File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~"'-'"' STATE OF ALASKA "'-"-'~ AL/'._,~A OIL AND GAS CONSERVATION COIv, n,,,dSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] Name of Operator ARCO Alaska, :[nc 3. Address PO Box 100360. AnchnragP_: Al( 4. Location of well at surface 99.510 }561' ):SL,. 1.20' FEL. Sec 29 T13N RDE, UM t top orprooucuve interval ' ' ' 5. Datum elevation (DF or KB) RKB 68 6. Unit or Property name KmJ,nnrm~k I~iv~r IIn~: 7. Well number 3N-12 8. Permit number feet 1719' FNL, 1557' At effective depth 1870' FNL, 1657' At total depth 1933' FNL: 1699' · Present well condition summary Total depth: measured 8100' [vID true vertical6697 ' ND FWL, Sec.33, T13N, RDE, UM FWL, Sec.33, T13N, R9E, UM FWL. Sec.33. T1RN. RqF. IIM feet feet Permit #86-79 9. APl number 50-- 029-21582 10. Pool K~_!,n_ar,_:~ [~!ver Oi! Pool Plugs (measuredN°ne", i: i:,"' :~,., ''" :'i,.,,~,. ~ ;~-~V !? T'5 Effective depth: Casing xxxxgX~~kxxxx Conductor measured 7980 ' feet vertical'---- MD feet true 6596 ' MD Length Size 110' 16" Junk (measured)None Cemented Measured dept~~' C~: '!!'' ~' True:V~'rfi~(~['~lePth · 247 SX CSII 110' MD 110' TVD Surface 4049' 9-5/8" Production 8028' 7" xxxx r xxxx Perforation depth: measured 7692'-7709' 7587'-7870' 1150 SX ASIII & 4088' MD 300 SX Class G 3551' TVD 300 SX Class G 8067' MD 6669' TVD & 175 SX ASI , 7815' 7817' 7819' 7844' 7846' 7850' 7854' true vertical6355, -6370' 6493'-6504' Tubing (size, grade and measured depth) 2-7/8", 6.5#, 7758' MD , 6458' 6460' 6462' 6483' 6484' 6488' 6491' Packers and SSSV (type and measured depth) RY'nwn HR PRrl~r - 7RZtl' Mn. Rv.n,.,n 1R D-.~-[,.-.v._ 77q1::;' Mn. D~b.-.,.. ,mEtll ,, ccc~/ 1-/o1! ~n ............... ~ ~, ~..,. ~ · ,.,,~,.,..., d'llJ 12.Attachments Description summary of proposal [] D;9{a~edoperahons'"'' ~' ........ program [-I'""'1~(~15 s'~et~h'"' Converting a prnducer t.n a water inj~r+!on we~! 13. Estimated date for commencing operation April 1, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-?.~.~/ ~,./y~,,/¢~ ~r ~ ..F-m,oI~,,,,~,~/~r' Operations Engineer Commission Use Only Date 3~24/87 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI "~ ----~/L~ 'Mechanical Approved by Form 10-403 Rev 12-1-85 by order of the commission Date Submit in triplicate ARCO Alaska, Inc. Post Office B~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 · DATE 10-01-86 TRANSMITTAL ~ 5783 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hot~ Logs: One * of each 3N-11 3N-12 5" DIL/SFL-GR 2"'DIL/SFL-GR 5" Den/Neu-GR (poro) 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) 2" Den/Neu-GR (raw) Cyberlook 5" DIL/SFL-GR 2" DIL/SFL-GR 5'! Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlo0k (poro) (poro) (raw) (raw) 04-12-86 Run #1 04-12-86 Run 91 04-12-86 Run 91 04-12-86 Run 91 04-12-86 Run #1 04-12-86 Run 91 04-12-86 Run 91 04-20-86 Run 91 04-20-86 Run 91 04-20-86 Run 91 04-20-86 Run #1 04-20-86 Run 91 04-20-86 Run #1 04-20-86 Run #1 4558-8768 4558-8768 7250-8742. 7250-8742 7250-8742 7250-8742 8250-8760 4084-8079 4084-8079 6400-8049 6400-8049 6400-8049 6400-8049 7500-8000 Receipt Acknowledged ..' ~State of~bl~se > NSK Files*bl Aa throe 11~/ ~a~ ~i ~[:~. Cons. Anchorage Drilling*bi Vault*films ..,..., .,_.~. ,.. ,. ,~ e,,~,,..4i.,rv n! AllmnticRtchlieldCompen¥ ~"~; · STATE Of ALASKA '~'"~ ALASK~ OIL AND GAS CONSERVATION b~JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,, · , , 2.ANRacr~e/~ Op. erator. 7. Permit Number asKa· ~ nc. 86-79 3 Address 8. APl Number 'P. O. Box 100360, Anchorage, AK 99510 50- 029-21582 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 130' FEL, Sec.29, T13N, R9E, UN Kuparuk River Unit At Top Producin_q Interval 10. Well Number 1719' FNL, 1557' FWL, Sec.33, T13N, R9E, UM 3N-12 At Total Depth 11. Field and Pool 1933' FNI-, 1699' FWL, Sec.33, T13N, R9E, UM Kuparuk River Field 5.6~va~(oBn in feet (indicate KB, DF, etc.) I 6.ADLLease25520DesignationALK and2556SeriaI No. Kupaurk River 0il Pool I 12~j4/1Date4/86Spudded 13.04/1Date9/86T.D. Reached 14.08/1Dates/86,Comp., Susp. or Aband. I 15.N/AWater Depth, if feet°ffsh°reMs L 116. No. l°f Completions I I 17. Total Depth (MD+TVD) 18.~IugBackDepth(MD+TVD) l'9. DirectionalSurvey I 20. Depthwl~ereSSSVset I 21.Thickness of Permafrost 8100'MD,6697'TVD 7980'MD,6596'TVD Y.EsY~ NO [] 1781 feet MD 1700' (approx) 2~ Type Electric or 0th'er Logs Run I L/SFL/SP/CAL/GR/FDC/CNL, CET/CCL/GR, Gyro(GCT), Temp Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i 6:; 62.5# H-40 Surf.....i 10 ~ 24" 247 sx CS I I "' ~-~)/i5" 36.0# J-55 Surf '4'088' ' '12-1/4" 1150 sx A~; Ill & 300 sx'Class G /" 26.0# J-55 Surf 8067' 8-1/2" 300 sx Class G & 175 sx AS I . 24. Perforations open to Production iMD+'TVD of Top and Bottom and 25. TUBING RECORD , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See Attached 2-7/8,, 7758, 7541, & 7735' . ~6. ' ACID, FRACTURE, CEMENT SQUEEZE, ET~." . DEPTH INTERVAL (MD) AMOUNT& KIN~) OF MATERIAL USED · See attached'addemum, dated 9/02/86, for fracture data 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Te'sted PRODUCTION FOR OI'L:BI~L " '~AS-I~C~:" '~AT'ER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ ...... Fi0w Tubing " Casing Pressure ' ' CALCULATED OIL-BBL GAS-M(~F WATER-BB'I" OIL GRAVITY-APl (c'orr) Press. 24-HOUR RATE ~ 28. "' ' CORE DATA Brief description of lithotogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None k CEIVF 1 9 1986 Al ~,,. ~. ~ ', * NOTE: Drilled RR 4/21/86 Perf'd well & ran tubing 7/15/86. WC1/111 Form 10-407 ' Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ J 29. ' 30; MARKERSJ' · , GEoLOGIc FORMATION TESTS · j' . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 763~+~ 6308~ NA Base Kuparuk C 7710' 6371 ' Top Kuparuk A 779~+~ Ga, z+1' Base Kuparuk A '7936' 6560' 31. LIST OF ATTACHMENTS Addendum (dated 9-02-86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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- lng 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG (Cont'd) 3N-12 Item 24: MD TVD SPF 7692' - 7709' 6355' - 6370' 12 Phasin~ 120° 7815' 6458' 1 90° 781 7 ' 6460' I 90° 7819' 6462' I 90° 7844' 7846' 6483 ' 1 90° 6484 ' 1 90° 7850' 6488 ' 1 90° 7854' 6491' 1 90° 7857' - 7870' 6493' - 6504' I 90° WCl:lllb:dmr 9-15-86 ADDENDUM WELL: 4/30/86 8/15/86 3N-12 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. Frac'd Kuparuk "A" sand perfs 7815', 7817', 7819', 7844', . 7846', 7850' & 7857'-7870' in 7 stages per 7/28/86 procedure using gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann to 2690 psi w/diesel. Tst ins to 8900 psi; OK. Stage 1: Pmp'd 17 bbls gelled diesel pre-pad @ 5 BPM 3160 psi Stage 2: 10 bbls gelled diesel w/1 ppg, 100 mesh @ 5 BPM, 3160-2860 psi Stage 3: 20 bbls gelled diesel pad @ 5 BPM, 2860-4430 psi Stage 4: 40 bbls gelled diesel pad @ 20 BPM, 4430-4160 psi Stage 5: 7 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM, 4160-4120 psi Stage 6: 26 bbls gelled diesel w/8 ppg 20/40 mesh @ 20 BPM, 4120-5160 psi Stage 7: 44 bblS gelled diesel flush @ 20 B?M, 5160-4440 psi Pmp'd 420# 100 mesh & 8883 20/40 in formation leaving 735# 20/40 mesh in csg above top perfs. Job underflushed by 3 bbls per procedure. Left top cup off treesaver in hole. Load to recover 164 bbls of diesel. Job complete @ 1010 hrs, 8/15/86. 1 9 1986 Drilling Supervisor $UB.$URFACE DIRECTIONAM sURvEY [~]UIDANCE r~ONTINUOUS ~-~ OOL RECEIVED AUG- 1 1986 Naslm 011 & Gas Cons. Commission Anchorage Company Well Name ARCO ALASKA, INC. SURFACE: 3N-12(l§61'FSL & 130'FEL, SEC.29,T13N,R9E,UM) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71499 T.WEST Date 4/30/86 Computed By; KRUWELL GCT DZRECTI~)NAL SUR~/E¥ ~USTaHER LZSTZN~ FOR ARC) ALASKA! INC.. 3N-1Z KUP~RUK NORTH SLOPEtALASKA SURVEY DATE~ 30-APR-86 ENGIMEER~ T.' M'EST RETHDDS OF C~RPUTATIO~ T3OL LOCATION: TANSENTIAL- AVERAGED DEVIAT[D#'AND:AZIHUTH INTERPOLATZgN~ LINEAR VERTICAL SECTZ3N~ HORZZo DZST',PROJECTED D~?O &:TA~GET~AZ!~UTH'OF SOUTH'25 DE~ 19 ~Z#'EAST .. . ARCO ALASKA~ I~C. 3M-12 KUPARUK NgRTH SLOPE~ALA$~A. COMPUTATIBN DATE: 29,-Hk¥-85 TRUE SUB-SEA C'DJRSE ..REASLIRED. VERTZCkL VERTZ:AL 3E¥ZATXgN AZIMUTH DEPTH DEPT~I**' DEPTH BEG qZN DEG M[N I)~GE 1 · DATE DF SURVEY: 3B-APR-B6' KELLY BUSHZNG ELEVATZON:. ENGXNEER: T- WEST: XNTERPOLATED VALUES FOR EVEN 100 FEET:DF MEASURED DEPTH VERTZCAL DOGLEG ~ECT'ZON SEVERITY FEET OE~IOO N 0 0 E S 72 16 E S 76 15 E S 78 37 E S 76 28 E S'66 3 E S 59 55 E S 39 52 E S 29:: 30 E S 7 56 E 0°30 0.00 -68.00 0 0 100.00 100.00 32.00 0 17 200.00 200.00 132-0-0 0 19 300.30~ 300.00 23 2.0.0 0 20 400000~ 399.99 331.99 0 22 500.00 499.99 431.99 0 27 ~00.00- 599.99 531.99 0 28 700.00' 699098 631.98 0 34 800.00 799.98 731.98 0 36 900.00 899.97 831.97 0 33 S 1-37 W S 3 13 ~i S 21 8 E S~ 21- 11 E S 19 59 E S 24. 7 E $' 26 56 E S 25 10 E S 24 20 E S 23 26 E 0.00 0.00 0.15 0.12 O.SO: 0.1! 0.85 0,04 1.22 0.07 1.75 0.07 2.39 0.08 3.21 0'13 4.22 O. 13 5.24 0-18 6.04 0.07 6.81 0.15 7.60 0.15 8.89 1-08 11-70 16.07 1'92 24.~.41 3.78 39.48 5.28 61.76 4.19 90.01 1-90 122.60 3.1~ 159.87 3.23 201~67 Z.77 247.88 2,86 297.71 Z.22 351.63 3.86 411.25 5.53 476.53 2o61 1.73 1.18 2.1'2 0.7~. Z.50 0087 1-83 0.68 1-24 2.60 0'34 0,83 S 22 2f, E S 22 17 E S 23 7 E S 22 31E S 21 38 E S' Zl 33 E S 21 52 E S 22 12 E 1030..00 999.97 931.97 0 28 1100.00 1099.97 1031.97 0 30 1200o00 1199.96 1131,96 0 32 1300. DO 1299.95 1231,95 I 6 1400-o00 1399.91 1331.91 2 5 1500.00 1499082 14,31.82 3 13 1600000 1599.44 1531.~4 6 11P00.. 00 1698.28 1630.28 10 50 1800-0 0:) 1795.. 75 1727.75' 14 ~.2 1900.-00 1891.66 1823.66 17 37 S 22 19 E' 545.18 S 21 37 E 616.09 2000000 1986.18 1918.18 20 2100o00 2078095 Z010.95 23 2 2200000 2169.75 2101.75 26 19 2300000. 2258.40 2190.40 28 2400.00~ 2345.~)5 2277,.05 30 58 2500.00 2429.15 2361.15 34 58 2600.00 2509.32 2~½1'32 38 53 2700.00. 258¢.J8 2515.98 ;,2 5 2800-00 2657.58 2589.$8 44 35 2900.00: 2727. :~7 2659.97 45 S 21. 3 E 688000 S 20 36 E 759.25 S 23 34 E 831.15 S 24 17 E 903.62 S 23~29 E 9~7.18 S 22 3S E 1052.53 S 23 S~;E 1127.05 S 2& 39 E 1199060. 5'25 19 E 1270.19 S 25 37. E 1340.35 3000.00 2797.27 2729.27. 45 54 3100-00' 2867.21 2799.21 45 50 3200. O0 2936.54 2868.5~ 46 13 3330.00 3005.~4 2937.4,4 46 ~4 3400.00, 3073.16 3005.16 48 12 3500.00 3138.82 3070082 49 22 3600-00. 3205.~3 313r,&3 47 1 3700. ~' 3274.22 3205.22 45 28 30~' 33~5.05 3277.05 44 44 3416.31 334~.31 44 ZO 68.00 F RE:TANGULAR CDDRD. ZMATES'H:)RXZ. OE'P&RTURE ~i~TI"I/'SOLFT'H EAST/.klEST;.: D'XST'.:~;., AZZ.qlJTId FEET' FEET:: .: FEET':. DEG':..M z# .. 0-00 1~ O. O0 E 0.05 S 0.26 E 0.1.8 S 0.78 E 0.31 S 1'35 E 0.~3 S 1,96 E 0.68 S 2.65 E 1.05 S 3.38 E 1.63 S 4.07 E 2.~1'? $' 4-64 E 3.~ S 4.98 E 4,31 S 5.01~E 5.18 S 4.97 E 6.0! S 5.0.7. E 7°Z0 S 5.57 E 9*85 S 6.'54 E 13.90 S 8.19 E 21.39 $ 11.85 E 34.95 S' 18.44 E 55.21 S 270 70 E 81.04 S 39.Z0 E . .. o,,oo. . o s I?-38 '- S :' ,Z*:O0.: S 77 3~ 2.~3' S 75 32 E 3.53 S 72.46 E 4'38 $ 68 S. 26 S 6.05 S 55 24 E 6.62' S' 49 17 7.18 S* 43 49 E 7,86 S 40: I0" 9.10 S 37"42 E 11.83 5" 35-35 E 16.13 S 31)::30 E. 24.46 $ 28 5.9 E 39.51 S 27 4.9 E 61.77 S 2&.:'38 E 90.02 S 25~48 E 111.09 $ 51.88 E~ 122.61 5:25 I'E 145.62 S' 66.02'E 159.89 S';:24 23 E' 184019~ $ 82.25 E 201.72 S 24 3 E Z26.80~S 100.24 E 247.96 S 23 50 ' \ 273.02.S 119'0~ E 297.85 S~'Z3 39 ) 323.32 S' 138.82 E 351.86 S' 23 1~, E 378.89 S' 160.77:E 411.59 S 22 59 E- 439.40 $ 185.52 E 476..96~ S: 22 S3 E 502,99 S 211.63 E 545.Y0 S*22 49 E 568*85 S* 238.24 E S16.~2 S 22.43 E 635.99 S 264.48. E' $86.79 S 2Z'*34 E 1107.27 S 46;,~62 E 1200.80 $ 22.4~;'-E: 1171.23 S 494.49'E. 1271-34 S 22 53' 1234.55 S 524.69. E 1341.~2 S 23 I ARCO A~-ASKAtl ]:~dC.~ 3~-12 K~PAR;JK.~ N*3~TH;$LDPEtALASKA: CO~PUTATZ~' DAre: 29-HAY-86 PIGE DATE OF SURVEY: 30~AaRo86 KELLY BUSHZNG ELEVATXDN: "ENGZNEERI-T. WEST~ ZNTE~POLATEO VALJE$ FOR EVEN 100 FEET OF MEASUREO OEPTH .. 65°00 FT TRUE SJB-SEA COURSE VERTXCAL DOGLEG RE:TAM;'ULAR C. ODID:~ATE$' HDRXZ. DEPARTURE NEASURED VERTZCAL VERT.X:AL DEVZATZON AZZNUT.H 5ECTZON SEVERZTY NORTH/SOUTH EAST./MEST DZSTo,;. AZ:ZNUTH · DEPTH' DEPTH DEPTH ~EG'NIN' DEG MI.M FEET' DEG/lOO FEET: FEET' ~FEET.: DEG,HX#; &lO0.O0 3560°11 3692.11' 43 18 $ 26.15 E 147903& ~200.00 3633.09 3565.09.. ~3 9 ~300°00 3705.zZ 3638012 &2:58 S 26 36'E ~615.95 &&O0oO0 3779.&2 3711o&2 ~Z ~? S~Z7 7 E t683o98 &500DO0 3852.86 378~o86 ¢2 3~ S' 27 19 E 1751-82: ~&O0oOO 3926o8~ 3858o8~ &l 59 S 26'57;E 1819.06 ~?00.00 k001035 3933.35 &l ~2. S 27 ll, E 1885.73' &800.'O0 &076o18 &008,18 ~1 19 S 26 5~ E 1952.03 4900e00~ ~151.&6 k083.~6 41' O' S'"26 2! E Z017.83 SO00*00 4227.21 4159.21 40 34 5100.00 ~303036 4235.36 40 16 5200.00 ¢379.83 ~311.83 ~0 0 5300.00 ~56066 ~388.66 39 39 5400 03: 4533.66 4~65.66 39 32 5500:00 ~610.78 4542'18 39 38 5600000 ~687.72 ~$19.72 '39 36 5700.00 ~764-71 4.69&.71 3.9 33 S 27 ~3 E 2531.08 5800°00 ~8~1.82 ~775-82. 3~ 30 S 27 56 E 25~.6~ saao-oo ~915.11 ~851.11 35 12 s 2~ 3~ E 2658.06 S 26 S4 E 2083*11~ S 27 /,2 E 2147,88 S 28 23 E .2212.25 $' 28 21 E 2276.15' S* 27 24.' E 2339.89 S' 27 45 E' 2403.51 S 27 45: E Z~67o33 6000~,00 4.996077 4.928.77 38 55 S 29 14 E ZTZO.BS 6100'00. 5074..71 5006.71 38 3. S 30 8 E 2783.42 6200.00 5153.11 5085.11 38 L1 $ 30 42 E 2845.25 6300'00 5231.93 5163.93 37 4.6 S 31 19 E 2906.&9 S* 31 56 E 2967.28 S 32 43 E 3027.60 S 33 11~ E 3087052 5 33 16 E ~147.27 S 33 35 E 3206.96 S 33 45 E 3266.47 33 58 E 3325.27 S'33 59 E 3383068 33 58 E 34.41o76 3~ 19*E 34.99.10 34. 16 E 3555.9~ 34. ~- E 3612.31 33 51~E 3667.97 6400.00 5311.05 5243.05 37 34 6500.00 539004.5 5322.&5 37 21 6600.00~ 5470.10 54.02.10 37 3 6700.00 5549.86 5¢81.86 37 7 6800000. 5629055 5561065 37' 5 6900-001 5709.54 5641.54 36 $6 0.65 0.97 0.08 0.35 0.31 0,50 0,35 0.35 1.32 0.65 0,82 O* 75 1,03 O. 41 0.41 0.18 004,0 0.. 35 0*39 0065 0'75 0.52 0.53 0.87 0.41 0.25 0.35 0.12 0o70 0.13 0.31 .0075 0.19 0.12 0.36 0,49 0'65 0.64 7000000. 5789.93 5721.93 36 22 7100.00. 5870.61 5802.61 36 4 7200000 5951054. 5883.54 35 4.8 7300.03'. 6032.97 5964..97 35 17 74.t)0o00 S114. J%: 6045-74, 35 0 TSDO.O0 6196.88 5128.88 34 33 7500, 31) ~ 6279.50 6211,50 34 0 7700.00 6362.4.9' 6294049 33 4.3 S 33 10 E 3723.20 7800.00 5~4.5.80 6377.80 33 29 S 33 34. E 3777.98 79~0°00 6529.37 64.61.37 33 9 S 33 39 E 3832.31 1297.33 S 555.05 E 14.11,08 S 23~ '9'E 1359.55 S 585.4.9 E 14.80,.26. $,23 1T~E. 1~,20.77 S 615.91 E 154~.8.53 S"23' 26:~t:: ¢81.91 S 6¢6.39 E 1$16.,~TS S".' 23'~ 33 E 15~2.59 S' 677.1.2 E 1584..66 S.,: 23.4:1 E 1602.94 S 708'19 E 175.2.~1 $,' 23::50 E 1562.81 S 738.87; E 1819.58 1722.18 5 769~26 E 1885,18 S 2~:~ '~ E 1181.13 S 799.68 E 18b0.04 S 829*04 E 2018.18 1898.4.0 S 858.32 E Z083.~2 $ 24~19:; 1955.98 S' 888.06 E 21.48.1& S 2012o84..S 918.40 E 2212..&6... S 24 31 2069.05 S 94.9.00 E 2276.31.: S'2~38 2125.57 S 978.59 E 2'340.0.2 S 24.43. 2182.00 S 1008,09 E 2403.61 S 2238.~9 S 1037',90 E 24.67-.60 S 24 2294.95 S 1067.63;E 2531.13.~. 2351.29 S 1097o31E 2.S94.,.~3 S 2407,19 S 1127.~31-E 2658:~08 S 25' 5 24.62.38 S' 1157.71 E 2.720'L95 ~':25 'lO'E 251&..82 S 1188.71. E 2783o~2 SS 25 16 E 2570.35 S-1220,1, E 28¢5.2S 25 23 2623.10 S 1251.85 E 2906.51 SS. 25 33~[ - 2675.17 S 1283.92 E 2967~33 25 2726.52 S 1315,44 E 3027.Y.0 ~ 22~ &6 E. 27t'1.21 S 134.9,41 E 3087.&9 S4 E 2827.69 S 13~2.¢2 E 3147.53 S'Z6 3. E ~87~..01 ~ 14 S.63 E 3207.83 S 26 11 E 297704.4 S 1¢82.13 E 3325.94' 5' 26 27 E 3026.4.1 S 1515.19 E 3384~52 S 26 35 3075.15 S 154.7o97 E 34.4~2o3'8 S 26~3 3123017 S 1580.55 E 3500.3.4 S 26 50 E 3170.72 S 1613.02 E 3557.43 S ZS 57 E 3217.86 S 1645.12 E 361&a01 S 326~.~9 S 1676.73 E 3669.92 S 2~:1~* E:' · 3311.03 S 1707.&9 E 3725.38 S 3357.29 S 1737.82 E 3780.~0 S 27 22 E 3&02.99 S 1768.2S E*:383~.98 S' 21 27 E CO~PUTATI3N DATE: ARCO ACASKA,, I~Co: 3M'12' K~PARUKi N3RTH.$LOPEtALASKA I#TERPOL~TED VALUES ~OR TRUE.i $3'B-SEA' COURSE ~EASURED VERTICAL VERTI:AL DEVIATIOM'AZIHUT~' DEPTH:. DEPTH: ·DEPTH. OEG:~IN OE~:HIH~ 8000o00~ 6613ell $$45'o1! 33 9 S*~33 8100".00~ 6696°83 &~28.83 33 9.. S 33 ZO-M~,¥-86 EVEN 100 FEET VERTI:AL SECTION FEET 3886.40 3940,S0: PAGE DATE OF SURVEY: 30~A.PR~8$ KELLY 8UsHING.!EL'EfATZDM: ENG~MEERJ~:,T~ NEST; OF MEASURED OEPTH DOGLEG RECTAN&~LAR. CDDRDI~AT.ESD~3RZZ° SEVERITY ND. RTH/SOUT~ EAST/.~EST DEG/IO0 FEET FEET. FEE[J~ '0.00 3~8.~7 S' 1798o59 E 38.89~33 0.00! 3~93.97 S 1828.93 E 3;943,.~1 ~ ' -.~ ~ ,~ . DEPARTURE A.Z Z IqUTH.. - S Z7:.37 E .) 3~12 K ~J P A R U g ~ NOR, TI'Ir · ~EkSURE~.VERTZC&L V~RTZ~ D.EPTH DEPTH~ DEPI' . OoOO 0'00 -68' 1000.00.i. 999.9T 931, 2000.00 1986.18 1918. 3000- O0.i 2797.27 2729. ,O00. Ol) i 3,81'.99. 3,19. 5000.00 4227.21 r~159. 6000.00 ,996.??' ,928. 7000:000' 51'89.93 5721. 8000.00 6613.11 65;,5. CDRPUTATZ3~ DATE:.Zg'-HAY-86 NTERPOLATED VALUES PAGE DATE OF SURVEY: 30~APR-86 KELLY 9USHZNG ELEVITION'~' ENGZ~EER: T~ WES*T: FOR EVEN 1003 FEET OF HEkSURED OEPT' A CO~RSE AL DEVZATIO.M'AZZMUrH H DEG ~[N" DEG, MZN O0 0 0 N 0 0 E 97. O. Z8 S I37 W~ 18 20 ~6 $ 22 2~ E 27 ~5 54 S'21 3 E 99 ,, I S Z5 56. E 21.- ,0 34. S'26 5, E 77 38 55 $ 29 1, E 93 36 ZZ S 33 58:E 11 33 9 S'33 ~ E VERTICAL SECTION FEET 0.00 6.0, 122.60 68.8.00 1,10.08 Z083.11 Z720.95 3325.27. 38.86.~0 DOGLEG RECTANaULAR COORDINATES'H]RZZo SEVE~ZT¥ NDRTH/SDUTH EAST/NEST OEG/I.00 FEET. FEET, . FE~T.~ 0o00 0.00 N 0o00 E 0.'00 0.07 ,.31 S- 5.01 E 6.62 ~:~11, 111.09 ~ 51088 E- 122,61.,. Z 635.99 26,.,8 E 688.1'9 0.65 1297.33-S 555.05 E 1'~11-08 0.82 1898.~,0 S 858.32 E 20-83.6,2. (~.$S 2462.38 S 1157-71 E 2720,95 913 29770~,, S"1682'13 E 3325~9, 0.00' 34~8.4,7 S 1798.59~'E 3889.33 68~00 FTc DEPARTURE .AZ ! DEG-" o o S' 4,91 11' S 25 S~ 2Z~ 3' E S 2.3, gE $' Z~' 19.., E S~'ZT 32 E 3H-12 KUPAR,JK NORTH, SLOPEtALASKA COMPUTATION DA~E: Zg-NAY-8$' TRUE SUB-SEA ' -COYRSE ~E&SURED V'ERTZ~L VERTZ~AL,~EVZATZ~N AZZ~U?H DEPTH DEPT~' DEPTH '3EG ~ZN DEG~HZ~' PAGE~ 5 DATE DF SURVEY: 309APR-86 KELLY BUSHZNG ELEVATION: EN;ZNEER:..T. gEST- ZNTERPOLATED VALUES FOR EY'EN'ZO0 FEET"QF~'SgB-SEA DEPTH VERTZCAL DOGLEG RECTANSULAR CODRDZ~ATES H~RXZ.' DEPARTURE- SECTZO.N SEVERZT~'NDRTH/SOUTH EAST/~ES'T D~$T. ail AZZRUTH .:~ FEET DEG/IOD FEEF~ FEET: FEE~' ' D.EG',#ZN 0000 0.00 68o00~ 68.00 168.00 168.00 268~00 2.6800.0 368.01 368.00 468.01~ 468,00 568.01 568.00 668.0~; 668.00 768002 768'00 868.0-3 868.00 -68.00 . 0 0 N 0 0000' 0 13 S 73 14 E 100,00 0. 18 $'T5 6.E ZO0.O0 0 20 S 76 $9 E 400.00 0 26 5'68 20 E 500'00 0 28 S' 61'.38 E 600-00 0 32 S 44 26 E 700'00 0 35 S 32 800;00 0 34 $~lZ 8'E 0 29 0 46 968.93 968.00 10~8.03 1068000 10 · 1168.0~, 1168.00 1100.00 1268.04.~ 1268.00 1200.00 1368.07 1368.00 1468.14~ 1468'00 1400.00 1568.37~ 1568.00 1500'00 S'11 3 E S 2233 E S 20' 9 E S 23:12 E $ 2621' E S 25 33 E S' 2423 E S 23~45 E 0.00 0,00 0.05 0.43 0.39 0'04 0074 0.*03 1,09 0.15 1.56 0.01 2.17. 0.12 2.91 0'37r 3.89 0.09 5-8.0 6.55 8.38 10.61 14o.44 21-03 '34,10~ 54.78 82061 S ZZ 35 E 115.79 S 22I~:E 155029 S 23 7 E 200.82 S 2227 E 253.22 S 2126. E 311.62 S 2129 E 379056 S ZZ 16. E 461.37 S 2215 E 555o51 S 2118 E 657L56 S ZO 37, E 760.07 1669,24~ 1668.00 1600.00 9 24 1771,38 1768.00 1700.00 13 38 1875021 1868.00 1800,00 17 8 S 2424 E 864.06 S 2334 E 971,~5 S ZZ 52 E 1086.16 S 2434 E 1193.29 S~Z5 ZG'E 1292,89 S 2553 E 1393o72 S 2618 E 1486~74 S 2629 E 1580.~1 S 27 3 E 1673040 S 2717 E 1765.74- 1980.59 1968.00 1900.00 20 6 20~8.14- Z068.00 Z000000 22 ~Z 2198.05: 2168.00 2100~00 26 L5 2310.98 2268000 ZZO0.O0 29 3 2426.85 2368.00 2303.00 31 ~0 25~7.88 2468.00 2400.00 36 30 2677.23 2568.00 2500.00 41 35 2814068 2668000 2600.00 ,4 ~8 2957.71. 2768.00 2700.00 4613 3101.1,.. Z868.00 2800*00 45 51 0'15 0.06 0,82 0.59 1,1T 1o24 4-20 4.04 3.26 2.09 3.94 Z.46 2.81 Z. SD 3007 3,15 1.86 1.51 0.38 0,75 0079 :00 N 0.00 E 01 N 0.12 E.: 0.14 S 0.61 E 0.26 S 1.16 E 0.38 $ 1.75 E 0.59 S 2,4.2 E 0'92 S 3.1~ E 1.39 S 3,86 E.. 2.19 S 4'47 E 3.12 S 4'93 U 4.05~ S 4,89 S 5.74 $ 6.73 S 8.82 S 12o 41 $ I :o, 48.85 S 74o15 S 10.4o79 S 141038 S 5.02 E 4699 E 4098 E $.38 E 6.17 E 7.53 E 68-00 FT. S 551 35 E 6.o9~ S 4 7.59 S' 40 56:E. 8.61 S'3839 E' 10~.~6 S 36 58. E 14,52 S' 31 15 E 10,33 E. 21,0.8... S 29 20'.i E 16-14 E 34,15 $ 24082 E 54.80 $ 2656"E- 36,23 E 82..62 S 26 0 E 49,28 E 1150~9 $ 25 11 E 64,28 E 155.31 S 24 27':E 31 S 102.29 E 253.30 $ 48 E z$ 286°00 S 124015 E 311.~8 S 23 Z7%E ) 349.36 5 149009 E 379.84 S 23 6.:*E 425.34 S 179,78 E 461i. 78 S 22 S4-E 512.56 S 215.55 E 556o.04 S 2248 E* S07,54 S 253.~3 E ~58.28 S 22" 83 703,62 S 290.04 E ~61,05 S 22.24 E~ 799081 S 329.88 E 865.17 S ZZ 24-E 10~1 897.82 S 373.82 E ~72.54 S'22':~6 E 3.4.Z. 2003.58 S 418'53 e 1087.35 S"22 38 E 0.55 1191.74 S 504.22 E lZ94.01 S Z~ 55 E 0.69 1279-92 S 546059 E 1391074 S 23~ T E O*T~ 1366.18 S 588.77 E~148~,65 S 0~42 1~50.08 S 630.48 E 1581.21 S 0.34 1533.16 S 672-30 E 167~-69 0.97~ 15~5.3~ s 714.60 E 1766.31 S 23 . ,.. 3245.53 2968.00 Z~OO.O0 46 25 3392.29' 3068000 3000.00 48 4 3544.55 3168.00 3100.00 48 25 369101~. 3268.00 3200.00 45 ~2 3832.28 3368.00 3300.00 44 37 3972.16 3468.00 3400.00 44 11 4110.82 3568.00 3500.00 4314 424~o85 3668.00 3600.00 43 5 4384.42 3768000 3700.00 42 ~8 4520.57 3868.00 3800.00 42 30 0,12 .M"'87':-1 : 0,63 "$.',..77.. '9 E - 1~i'9' S'T!;' 7 r ~ 1,Tg':~. $. 7:7~. 44 '~ - / 2.&9'" $ 76 20.. E'.: 3~.27 S 73'4~ E' 4010..,'I'70! 8 E 4. o97: 63:53 E" 5.84 $"~?!39':E ARCO AI.A. SKAt ]:~C°.: 3N-1Z KUPAR~dK, NORTH · SLOPEtALASKA' CONPUTATZDM DATE: 29-~AY-86 XNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA'DEPTH PAGE DIT'E OF SURV'E¥~ 30. eA?Ro86 KELLY BUSHZN$ ELEVATION:, 68.00 FT': TRUE $~8-SEA COURSE REASURED'V'.ERTZCAL VERTZ:AL ~EV~ATZON AZZ#UT~ DEPTH' DEPT~; DEPTH OE.G 45S5o29 3968000 ]900o00 ,799009 ~068.00 ~O00.O0 ,122 5053-59 ~268.00 ~ZOO~O0. 4022 518,.55 ,368.00 4300.00 ,0 3 5574.41 46.68.00 4600,00 39 5704.26 4768000 4700.00 39 33 5833.92 4868.00 4800,00 39 26 5963.01~ ~968.00 4900.00 39 1 6091o,0 5068.00 5000.00 38 36 6218.9~.. 5168.00 5100,00 38 7 6345.59. 5268.00: 5200.0.O 37 64~1.7~ 5368°00 5300'00 37 24 6597.3F 5,68.00 6722.75 5568.00 5500.00 37 5 68~8.05 5668.00 5600,00 36 58 6972.76 5768.00 5700.*00 36 22 7096.77 5868.00 5800'00~ 36 7220°28 5068.00 5900.00 35 39 73,2090 6068.00 SO00.O0 35 11 7~64.92 6168000 S100.00 34 41 VERTZCAL DOGLEG RECTANGULAR COORDZNATES'H3RZZ, DEPARTURE SECTION SEVERZT~.MDRTH/SD~TH EAST/MEST DZ$'T,~ AZZRUTH' FEET DEG/IO0 FEET~ FEET- ~ FEE~ 'DEG HZM~ $ 21 7 E 1855.97 S 2r 3 E 194~082 $ 2631 E Z032.19 S'Z721'E 2117085 S 2817 E 2202.32 $"28 $ E Z285.55 S 27 3~ E 2368018 S 27'46 E 2451~0¢ S 27 4~ E 2533076 S 28 6 E Z&16'2' S 28 5~ E 2697.74 S 30 2 E 2778007 S 30 49 E 2856.90 S 31 36 E 2934.22 S 32 31 E 3010.59- S 33 12 E 3085095 S 33 ZO E 3X60.86 S 33 37 E 3235.60 S 33.57 E 3309.30.. S 33 59 E 3381.80 S 3, 2 E 3453.,6 S 34 21 E 3523056 S 34 14 E 3592.62 7586,13 6268.00 6200.00 34 3 S 3W 2 E 3660.30 7706°62 6368.00 $300.00 33 ~1: $ 33 9 E 3726.84 7826o6[ $468.00 6,00.00 33 21 S 33 41E 3792o,9 7946.12 6568.00 6500.00 33 9 S 33 ,2 E 3857.25 8065o57:&668.00 6600.00 33 9 $ 33:,2 E 3921.87 8100000 6696.~3 6628.83 33 9 $ 33.42 E 0042 1.15 0.77 0,49 004.8 1.19 0.33 0*75 0*59 0.77 0-52 0.50 0.27 0040 0.2.6 0.10 0.31 1595.70 S 755.64 E 1856.~5 S 2~,: 1' E 1'774.1'1 S 796.¢'0 E 1345-21 S 2~-1'0 E 1852.69 S 8'350,5 E 2032,53:_ ~.24~16 E 1929-335 8T~,1'8 E 2118..1.~..~ 200.4.09 S 913.67 E 2202,.6~.: S 2~ 30 E 2077.35 S 953.45 E 228.5.,0 S 2224.06 S 10~0,30 E 2~51..12 S'24~51 E 2370.32. S 110.7-4~ E 2S16027 25. ' 2~42.06.. S 1146,~1-E 2597~76 525 8 E 2512.17: ~ 118~.02 E 2778007 52516 E 2580.&2 S 1226012 E 2856.91 S 252~ 2546.~9 S 1266.,0 E 2934.2~' 2712.08 S 1307019 E 30101:67 525 21T5.89 S 1348-54 E 3086,12 S 25 S4 E 2839.1~ S 1389.95 E 31.61.~ S 26.~. 5 E 2902012 S' 1431.66 E 3236.0.~ 'S 26' 296~.04 S 1473.10 E 3309.91 ~' 332~.84.S 1514'12 E 3382.63 ~ 2635 E.. 0.76 0046 0.38 0.66 0.,6 0.53 0.00 O.O0~ 0.00 3143.62 1594053; E 352~.90~ 2.6 . 3201'383258.06. '1672.38 E 3662.22 ARCO ALASKAD:: INCo KUPARUK: NOR:TH SLOPE,ALASKA MARKER ?DP' KUPARUK BASE KUPARUK C TOP KUPARUK BASE · KUPARUK A ~BTO tO. CDMPUTATZ3N DATE: ZD-MAY-8$ [NTEEPOLATEO VALUES FOR :HOSEN HORZZ3NS O~IGIN= 1561 ~IEAS~JRED DE~TH TVO BELON KB FROM K8 S~B-SEA 753%o80 6307.69 6Z39.69 7710. 0 6370.81 6302.81 7194°00 64~0,80 6372080 7980.00 6596.36 65.28.36 8100o00 6696083 6628.83 PAGE 7. DATE DF SURVEYI 30eAPR-86 KELLY 8USHZNG ELEVATION: 58-00 FT ENGIMEER: T. SURFACE LDCA. T'I'ON REC'T ANGULAR'; COORDINATES NO RTH/S OUT'H.: .~.'E a ST ttJST 3ZBO, Z9 S &687~Z~ E 33~5,68 S ~7~O~SZ E 3Ss~.SZ S' 3~93.9~~ $ 18Z8~93 E A~CO ALASKA~ INC. KUPAR~JK. NORTH 5LOPE,ALASKA HARKER TOP KUPARUK!C ~ASE.KUPARUK C TOP KUPARUK ~! 6ASE:KUPARUK A PBTD'. CO~PUTATZ3N"OATE: ~~&O00 STRATISRAPHZC qEASURED DEPTH BELO~K8 7634.00: 7710.00 1794,00 7936.80 7gSO,OO 8100,0.0 zg-HAY-B5 SUMMARY PAGE DATE OF SURVEY: 30~APR-8$ KELLY BUSHZNG~ELEVAT[ON: 'ENGINEER: To #EST' OR~G[M=TV 1561 FSLt FROH KB SS'B-SEA 6307.69 6239.$9 6370.81 6302.81 6440.80 S372.80 6559.52 S~9.1.SZ SS96o36 $5Z8°36 6696,83 6628.83 8~ 68.00 FT. L-- S~.FACE ~OCATZO~' N.O R TH/$ ~UT.~: EAS.T/# E.S T 1587~29 E 11'10~.5 Z E 17'35.'9 9 E 1792,5Z. E 1828o93 E ~2B0,29-S 3315,6B S 3aS¢.SZ S 3.419,36 S 3439.37 S. 3493,97'i~S FI:NAL,: tdELL,~: LOCATI:)N A'T'," TRdE SUB-SEA' ,qEASJRED VERTICAL VERTICAL DEPTH DEPTH, DEPTH 8100.00 6696.83 6628.83 HORIZONTAL. DEPARTURE DISTANCE. AZZNUTH FEET. ~EG .HIM" 3943,71 S 27' 37 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3N- 12 F I ELD KUPARUK COUNTRy USA RUN DATE LOOOED ONE -) 30- APR- 86 REFERENCE 000071499 RECEIVED AUG- 1 1986 Naska 011 & Gas Cons. ~ommlssion Anchorage WELL: 3n-12 (SURFACE: 1561'FSL & 130'FEL, SEC.29,T13N,R9E,UM) HORIZONTAL PRQJE~TTON 5000 REF 00007!499 $CP, L.E -- 1 / 1000 ! N/FT 2000 1000 - 1000 -2000 -9000 -4000 ,~,Ot,,/T H -~000 -9000 14EST -2000 - 1 oo0 0 1000 2000 9000 4000 ~ooo WELL: 3N-12 (SURFACE: 1561'FSL & 130'FEL, SEC.29,T13N,R9E,UM) VERTICAL PROJECTION -2000 - 1000 0 0 1000 Z000 3000 4000 5000 RO00 1 ~4. PROJECTION ON VERTICAL PLANE IE;4. - 334. ,~::ALED I N VERT I CI~_ DEPTHS o o HORIZ SCALE = 1/1000 IN/FT STATE OF ALASKA '~"~ ALASKA OIL AND GAS CONSERVATION COMN,..~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] Complete 2. Name of Operator ARCO Alaska, inco 3. Address P,O. Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 1561'FSL, 130'FEL, Sec.29, T13N, R9E, UM At top of productive interval 1719' FNL, 1557'FWL, Sec.33, T13N, RgE, UM At effective depth 1878'FNL, 1663'FWL, Sec.33, T13N, R9E, UN At t~)9t~½'c~q[:~t,h 1699'FWL, 5ec.33, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 68' 6. Unit or Property name i(ugaruk River Unit 7. Well number 3N-12 8. Approval number 85 9. APl number 50-- 029-21582 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8100 true vertical 6697 Effective depth: measured 7980 true vertical 6596 Casine Cond~uctor Surface Length 80~ 4051' 8067' Production Size 16" 9-5/8" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 247 sx CS II 1150 sx AS III & 300 sx Class C 300 sx Class G & 175 sx A5 I None None Measured depth ll0'MD 4088'MD 8067'MD ~ueVertical depth ll0'TVD 3551'TVD 6669'TVD ' Perforation depth: measured true vertical (see attachment) (see attachment) Tubing (size, grade and measured dePth) 2-7/8", J-55, tbg W/tail (~ 7758' Pa~e~sr SS§V (.txpe. an~d measured depth an/ 7735', & FVI' S$SV ~ 1781 ~) p (~ 5-41 , ID-pKr La ' RECEIVED AUG- 1 ]986 Alaska t311 & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volUmes used and final pressure 13. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Subsequent to operation 14. Attachments [completion Well History) Daily Report of Well Operations Copies of Logs and Surveys Run ~ Tubing Pressure Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-8 Title Associate Engineer (DAM) SWO/078 Date Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS 3N-12 (cont'd) Perforati on Depths: MD TVD 7692' - 7709' 6355' - 6370' 7815' 6458' 7817' 6460' 7819' 6462' 7844' 6483' 7846' 6484' 7850' 6488' 7854 ' 6491 ' 7857' - 7870' 6493' - 6504' RECEIVED SWO/O78a:tw AUG- 1 1986 Naska 011 & 6as Cons, Commission Anchorage ARCO Oil and Gas ComPany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not · required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska Field Lease or Unit Kuparuk River Auth. or W.O. no. ~ Title AFE AK1215 Nordic #4 North Slope Borough ADL 25520 Completion IAccounttng state coat center code Alaska IWell no. 3N-12 API 50-029-21582 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 7/15/86 cost center prior to plugging and I 56 · 24~ abandonment of this well I Date Hour Prior status if a W.O, 7/14/86 0600 hfs, Date and depth as of 8:00 a.m. 7/16/86 Complete record for each day reported 7" @ 8067' Diesel Accept rig @ 0600 hrs, 7/14/86. ND tree, NU & tst BOPE. RU DA, perf 7857'-7870', 7844', 7846', 7850', 7854', 7815', 7817' & 7819' @ 1SPF. Perf 7692'-7709' @ 12 SPF, 120° phasing. Make JB/gage ring run to 7800', POOH. RIH, set lB pkr @ 7735'. RU & rn 246 jts, 2-7/8" tbg & ind. Set pkr, tst tbg, top pkr & SSSV. Instl BPV. ND BOPE, NU & tst tree. Displ well w/diesel. 7" @ 8067' Diesel Fin displ well to diesel. Set BPV. RR @ 0830 hfs, 7/15/86. (NOTE: Rn 245 jts, J-55, 6.5# EUE 8RD AB Mod tbg w/SSSV @ 1781' HB pkr @ 7541', lB pkr @ 7735, & TT @ 7758'.) RECEIVED AUG- 1 1986 Alaska 0il & 6as Cons, C0mmissi0n Anchorage Old TD Released rig New TD Date 0830 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 7/15/86 PB Depth Kind of rig Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day .... Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sign~ ~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE 05-13-86 TRANSMITTAL # 5658 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listings: Schl: One of each Please note: These tapes are both labeled as EDIT LIS Tapes--According to Schl. they are regular Open Hole tapes since we have received no previous tapes. "3N-12 04-20-86 Run f/1 1689.0-8131.5..~E:~.c2q/-/L<~-~--~27'- /~-~"~-~'~/~-~1 This tape is a standard Open Hole LIS plus listing. 3N-14 05-04'-86 Run ~/1 2557.5-7476.0~6? ~ ~~--5--~ Receipt Acknowledged: State of AK Date: ARCO Alllkl. Inc. il · Sul)lidiary of AlllnticRichfieldComl)·nY STATE OF ALASKA '"'" ALASK,. ,.)IL AND GAS CONSERVATION COMM,.~ION APPLICATION FOR' SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown )~ Re-enter suspended well ~' Alter casing ~ Time extension ~ Change approved program © Plugging FI stimulate ,~. Pull tubing ~ Amend order ~_; Perforate F_; Other 2. Name of Operator ARCO Alaska_, Inc. 3. Address P. O. Box 100360 Anchorage- AK 4. Location of well at surface 99510 5. Datum elevation (DF or KB) 68 ' RKB 6. Unit or Property name Kuparuk Riv~F Unit 7. Well number 1561'FSL, 130'FEL, Sec.29, T13N, RgE, UM 3N-12 At top of productive interval 8. Permit number 1828'FNL, 1474'FWL, Sec.33, T13N, R9E, UM (approx.) 86-79 At effective depth 9. APl number 1851'FNL, 1695'FWL, Sec.33, T13N, RgE, UM (approx.) 50--029-21582 At total depth 10. Pool 1904'FNL, 1731'FWL, Sec.33, T13N, RgE, UM (approx.) Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 8100 true vertical 6697 feet Plugs (measured) N o n e feet Effective depth: measured 7980 true vertical 6596 Casing Length Size Conductor 80 ' 1 6" Surface 4051 ' 9-5/8" Producti on 8067 ' 7" feet Junk (measured) None feet Cemented Measured depth Conductor report 110'MD not available. 1150 sx AS I I I & 4088 'MD 300 sx Class G 300 sx Class G & 8067'MD 175 sx AS I ~ueVerticaldepth 110'TVD 3556'TVD 6669'TVD Perforation dePth: measured Non e true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Well H~story~ Addendum (dated .~/2/86) 13. Estimated date for commencing operation July, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby.certify that the foregoing is true and correct to the best of my knowledge Signed (~,~,0~ ~ Title Associ ate Engineer Commission Use Only ( DAM ) SA/038 Date Conditions of approval Approved by ~I [[~J~J[ JJ, S~JJJ'JJ . Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval [] Plug integrity [] E~3r~j d~,tocation clearancel Commissioner by order of ~.~_.-~- the commission Date ~ ~/~ ~- Submit in triplicate feet Inetruotiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District ~ County or Parish Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ]Title I AFE AKl193 North Slope Borough ADL 25520 Drill IState Alaska no. 3N-12 Doyen 9 AP1 50-029-21582 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spudded Date and depth a8 of 8:00 a.m. Complete record for each day reported I Hour 4/14/86 0430 hrs. A.R.Co's W.I. 56.24% Prior status If a W,O, 4/13/86 thru 4/14/86 16" @ 110' 223', (113'), Drlg Wt. 8.9, PV 16, YP 18, PH 8.5, WL 14.4, 5ol 4 Accept tiS= @ 2330 hfs, 4/13/86. NIl dtverter eye. 4/14/86'. D{l'i2~" hole to 223'. Spud well @ 0430 hfs, 16" @ 110' 2804', (2581'), Drlg Wt. 9.6, PV 22, YP 18, PM8.5, WL 13.6, $ol 9 Drl, Nevi-Dr1 & surv 12~" hole to 2804'. 439', .4o, S55.7g, 439 TVD, 1.32 VS, .865, 1.27g '1238', .7°, S 1.2g, 1237.97 TVD, 7.10 VS, 5.685, 4.60g 1521', 3.4°, S23.5g, 1520.78 TVI), 16.58 rS, 14.835, 7.42g 1866', 16.5°, S24.0~, 1859.85 TVD, 76.03 rS, 69.31S, 31.28M 2525', 35.5°, S21.2g, 2451.92 TVD, 357.56 rS, 330.36S, 137.80g 4/16./86 16" @ Il0' 4187', (1383'), Prep to rn csg Wt. 9.1, PV 18, YP 14, PH 8.5, WL 10.9, Sol 6 Drl & surv to 4187', 10 std short trip, CBU, POOH f/9-5/8" csg. 2682', 41.[*, S22,4g, 2575.08 TVD, 454.64'VS, 420.67S, 173.92g 3088', 45.5°, 519'.7g, 2826.74 TVD, 737.00 VS, 685.53S, 274.34g 3627', 46,9°~, S23.2g, 3231.29 TVD, .1132.30 VS, 1052.49S, 423.04g 4131', 43,9°, S26.1g, 3586.89 TVD, 1489.31VS, 1376.59S, 572.79g 4/17/86 9-5/8" @ 4088~ 4255', (68'), Turb/ne drlg Wt. 8.4, PV 3, YP 2, PH 10, WL 14.6, Sol 2 Fin POOH. RU & rn 102 its, 9-5/8", 36~, J-55 BTC csg w/FC @ 4007', FS @ 4088'. Cmt w/llS0 sx AS III w/100#/sx Gilsonite. Tail in w/300 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. ND divert,r, NU & tst BOPE to 3000 psi. TIH w/BHA to FC, tat csg to 2000 psi. DO fit equip & cmt + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 4255' e 4131', 43.9°, S26.1E, 3586.89 TVD, 1489.31VS, 1376.59, 572.79 4/18/86 9-5/8" @ 4088' 6640', (2385'), Drlg Wt. 9.3, PV 4, YP 2, PH 9.0, WL 7.8, Sol 7 Drl& surv 8½" hole 6640'. ~.G[17~4~~ 4683', 42.0°, S28.1E, 3990.91TVD, 1865.21VS, 5466', 39.8o, s29.3E, 4585.27 TW, 2373.85 vs, 2157.60s, 990.29 6156', 38.4°, S32.3E, 5119.72 TVD, 2808.56 VS, The above is correct For for~ preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report"' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District I County or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE AK1193 Doyon #9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 4/19186 thru 4/21186 4/22/86 Date and depth as of 8:00 a.m. Old TD 0830 hrs. Released rig Classifications (o11, gas, etc.) Oil Producing method Flowing Potential test data North Slope Borough ADL 25520 Drill IAccounting cost center code State Alaska I Well no. 3N-12 API 50-029-21582 56 24% Cost center prior to plugging and I iabandonment of this well I I Date Hour Prior status If a W.O. 4/14/86 0430 hrs. Complete record for each day reported 7" @ 8067' 8100', (1460'), ND BOPE 9.8 ppg Brine. Drl & surv 8~' hole to 8100', short trip, CBU, POOH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL, RD Schl. Make cond'g rn, POOH. Cbs rams to 7", RU & rn 198 Its + 1 mkr It, 7", 26#, J-55 BTC csg w/FC @ 7980', FS @ 8067', mkr It @ 7742'. Cmt w/100 sx 50/50 C1 "G" w/81 9-20, .2I 9-46, .51 D-65 & .5% 9-112', followed by 200 sx C1 "G" w/3I ICl, .9I 9-127, .31 D-13 & .21 D-46. Displ w/brine wtr, bump plug. ND BOPE. 6626', 37.2°, S34.8g,5491.09 TVD,3093.63 VS, 2774.49S,1369.46E 7524', 34.6*, S35.9~,6216.89 TVD,3614.57 VS, 3203.91S,1679.90~ 8050', 32.8*, S34.0E,6654.68 TVD,3902.07 rS, 3443.16S,1846.47g '8100', 32.6°, S33.9E,6696.75 TVD,3928.78 VS, 3465.56S,1861.56g * Projected 7" @ 8067' 8100', (0'), RR 9.8 ppg Brine Fin ND BOPE. RR @ 0830 hfs, 4/21/86. New TO Date 4/21/86 MAY i 4 LoS° . ?980 Kind of rig Type completion (single, dual, etc.) Single ] Official rese~oir name(s) Kuparuk Sands Rotary Well no. Date i Reservoir Producing Inter'al OII or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected , The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 4/30/86 3N-12 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. D~illing Supervisor ~Da~e MEMORAN JM' TH RU: FR OM: State -o? f Alaska ALAS~ iOtL ~D GAS CONSERVATION COMMISSluN Commtseioner Edgar W. Sipple Petroleum Inspector DATE: April 25, 1986 F! LE NO.: TELEPHONE NO.: D.EWS. 10 SUBJECT: BOP Test l1 ARCO KRU 3N-2~Y Permit No. 86=77 Kuparuk River Field Wednesday, April 16, 1986: I traveled this date from Sohio's M-28, subject of' a~0ther' ~~t, to ARCO's KRU 3N-12 to witness a BOP test. The BOP test co~nced at 9:00 p.m. and was concluded at 1.0:30 p.m. this date. There were no failures. I filled out the-A,O.G.C.C. BOP inspection report which is attached to this report. In summary, I witnessed the BOP test on ARCO's KRU 3N-12. :02-001 A ( Rev 10.84) " ~ ~ .ALAS .'KA, .0'IL'i &'.'GAS :'CONSERVATION: CO~4ISSION · ::?:.f'-t~ ' "i _..- " B..O.'P.'E. Inspection Report . .:... ~....->:-.. - ~ -:':..--:.: '.'-'":: Date '-" -- ~n "~~m ' '"' ..... ~ · LOcati°~!: Sec Drilling Contractor Location, General "' General HoUsekeepinE ~ RiE . ~ ~ . Reserve Pit Mud Systems. '- Visual Audio Trip Tank Ri Pit Gauge Flow Monitor Gas Detectors BOPE Stack AnC~r~~event er ~ Blind Rams Choke~J~ine Valves ~[. C. Rj Valv~ , '~ "(9 c~.f-~' Kill Line Valves z.o.O'w~ Test Results: Failur'es Test Pressure : ,, Permit '# ~"77.' .... ACCUMULATOR SYSTEM Full Charge Pressure ~~ Pressure After Closure ~...~ o Pump incr. clos., pres. 200 psis 0 psis' I ~o o ~' rain' ~ sec'. · 3. _=in ~ o sec. Full Charge ~resslj~re ~t~ined: N~,, ~ (~ ~C- (~,~~ -, .&~,~.lf~,~ ,-/~,~, /~0 pSis . ~ ~ ,- ~-- ~ ~~ - Kelly and Floor Safety Valves Upper Kelly" ~~s~ pressure ~.~ Lower Kelly ~~est Pressure Ball Type ~ ~est Pressure ~.~ Inside BOP ~ ~st Pressure Choke Manifold' ~k'~t Pressure ~e~,~ No. ValVes ~ ~0. ~~s' 3 ~ Adjustable Chokes .~ ~ ' Hydrauically operated choke - Test T~e J hrs. ~ O ~ Repair or Replacement of failed equipment to be made within Commission office notified. days and Inspector/ Remarks: Distribution orig. --AO&GCC cc - Operator cc - Supervisor Inspecto April 14, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. .P.O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3N-12 rev. ARCO Alaska, Inc-. Permit No. 86-79 Sur. Loc. 1561:FSL, 130'FEL, Sec. 29, T13N, R9E, UM. Btmhole Loc. 2038'FNL, 1573'FWL, Sec. 33, T13N, RgE, UM. Dear Mr. Kewtn: EnClosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated April 11, 1986, accompanying the original approved permit are in effect for this revision. V. t 1. uts ~ Chairman of Alaska Oil and Gas Conservation Commission BY O~DE.R OF TME COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 14, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3N-12 Dear Mr. Chatterton' Enclosed is the Revised Permit to Drill application for Kuparuk 3N-12. This application reflects the new bottomhole location that was verbally approved by Lonnie Smith on April 11, 1986. We are requesting a variance for this Kuparuk well using the attached diverter diagram. A modification has been planned and should be completed in approximately 3 weeks. The modified system will be operationally equivalent to the new requirements.. If you have any questions, please call me at 263-4970. ~R~~~Bona1 ~rill ing Engineer JBK/LWK/tw PD/L04 Enclosures RECEIVED APR1 Alaska OJi & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA· ALASKA .. ,L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 r la. Typeof work Dr,',,/~' Redri,', ~1 lb. Typeof well. Exploratory [] Stratigraphic Test [] Development O,1~;~1~ Re. Entry..[:3 Deepen_~ Service [] Developement Gas [] Single Zone li~ Multiple Zone 2. Name of Operator - (REVISED) 5. Datum Elevation (DF or KB) 10. Field and Pool ~,RC0 Alaska, Inc. RKB 68t s PAD 3~r' feet Kuparuk River Field 3. AddreSs 6. Prope~y Designation Kuparuk River 0tl Pool ~.0. Box 100360 Anchorage~ AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or prope~y Name 11. Type Bond(~. ~ A~c ~.o25) 561'FSLs 130'FEL~ Sec.29s T13N, R9E, UN Kuparuk River Unit Statewide At top of productive inte~al 8. Well number Number 828'FNL, 1474'FWL, Sec.33, T13N, RgE, UN 3N-12 ~8088-26-27 At total'depth 9. Approximate spud date Amount Z038'FNL, 1573'FWL, Sec~33~ T13N,.R9E' UM 0~/14/86 $500~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prope~y 15. Proposed depth(Mo ~na property line 8117 ~ ND 130' ~ surface, feet 3N-11 25'e surface feet 25~0 (;R~K,TVDi feet 16. To be' completed for deviated wells 17. Anticipated pressure <..~ AAC 2e.~ Kickoff dePth1500 feet Maximum hole angle~2 ~ Maximumsu~ace 291 8 p.igAttotllde~t~D) ~0 18. Casing program . setting Depth ' size Specifications Top Bottom Quantity of cement Hole Casing ' Weight Grade Coupling ~ngth MD TVD MD ~D (include stage data) ~' ?' 26.0~ J-55 BTC 8083~ A~~ 3~~ 8117~ ~ 30~ ~x ~la~ HF-ER~ 19. TO be completed for Redrill, Re-ent~, and Deepen Operations. Present well condition summa~ Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Ve~ical depth Structural Conductor p ~ "' ~ ~ V E D Surface IntermediateAPR 1 1986 Production Liner A~:~ ..,~ ~.~s. Perforation depth: measured tru® ve~lcal 20. Attachments Fiii~ fee ~ Prope~y plat ~ BOP Sketch~ Diverter Sketch ~ Drilling program ~ Drilling fluid prog~~ Time vs depth plot ~ Refraction analysis ~ Seabed repo~ ~ 20 AAC 25.050 requirements 21. I herebY ce~y th~ the foregoing is ~ue and correct to the best of mY knowledge ' " Regional DFi11~ng Eng~nee~ ~ --~ ~ ~ ~ Commission Use Only (LWK) PD/PD251 '/ Permit Number I AP.,umb. r I I S" cov"r'"tter 8 6 - 7 9 50-- 0 2 9- 2 15 8 2 0 4 / 11 / 8 6 for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures C Yes ~ No Directional su~ey required ~ Yes ~ No Required working~ssure for B~ ~2M; ~ 3M; ~ 5M; ~ 10M; ~ 15M by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1. ) Sul: :riplicate 1 i, I AORAh4 # I PS~' RSRRA B~ $'TAC:X: 3. I1' - 503C) !~! X 13--5/8' - 5000 PSI (~PAC~ 4. 13--5/8' - 5CX30 I~I PIP~ KILL LIhF_.S 6. 13-5/8' - 5DID PSI ~ RAM W/PIPE "/. ID-5/8' - 5CX::)O P~! ~ -AC~,ATO~ CAPAC)T,.Y TEST !. OEO( .AND FILL AOD.MJ_ATCR R~D~OIR TO'~ LEVEL WITH I-~C:P. AULIC FLUID. 2. ~SLRE-THAT AOD.M/_ATCR PRE~ IS 3033 PSI WITH )500' PSI ~TREAM CF ThE FEG. L~TCR. 3~ ~VF. TII~., Tt..EN O,0~ ALL LINI"I'S SIJ,4.JL. TA/',,ECI. J~Y ALL UNITS ARE O_OS~ WITH C~IhlS PUVP CFF. 4. RECC~ ON NACC REPCRTo T1-E AC~'rABLE LC)~ LIWI'r IS 45 SEC~ C3_OSIN0 TINE AN:) 12D0 PS! RE)V~ZN~NG 5 4 2 I RECE'IVr . · · · · APR1 lg G : 0ii & Gas cons. ~ ......... 7~nchorage ' · II. 13-5/8" BCP STACK T~.,~T !. FILL OCP STACX AND O-E]~ MANIFCL.D ~FITH ARCTIC OEO( THAT ALL LO0( EX)~ ~ IN N~L~ FULLY EE'rRA~. SEAT TEST PLUG IN WEL~ WITH RLINNING Jl' AhD ~ IN LCX:Xi:XI~ LIllE VALVES ~~ lO ~ STAO(. AI.J. OT)-E~ 4, PRESS~ UP TO 250 PSI AhD MOD FOR 10 MIN. IN- C~ PRES~ TO $000 PSI AhD HOLD FCR I0 WIN. B ~LEED PRES~ TO 0 PSI. LIhE VALVES. P_._OSE TCP PIPE P~ AhD MC~ VALVES CIN KILL AhD CHCKE LihES. 6.' TEST TO 250 PSI AhD 3~)00 PSI AS IN STEP '/. ODVTIIXlJE TESTING ALL VALVES, LZNF.~, AND WITH A P_50 PSI LON AND 3000 PSI HIOH. TEST AS IN STEP ~. DD NDT PI~'~ TE~T ANY O-1(3~T THAT _NOT A .F'U_L Q..C~NG PC)S]T]VE ~ O,,EDK~. ~Y . F'LIx~ICINI. 1F..$'I Q',I(XE5 'FMA1- DO NDl FL,L.LY CLX. 8. ~ TOD PII:~' ~ .AND O.0S~. BO'Fr~ PIPE TEST 'BOTrCh~. PIPE RAN~ TO 250 PSI AhD'~ PSI. ~ BOTT~ 'PIPE .R~,~, -'BACX ClJ"T RLN~N~ ,,rT AN:) O. OS~-BLIND RAMS AND TEST TO 250, PSIAND .3030 'ps!.. · .I~ANIFO_D AND, LIhES ARE. FLLL. CF 'FLUID. ~ ALL VALVES IN DRZLL~N3 TEST STANDPIPE VALVES, K~ I y, I~ l y CO.So D~ILL' PIPE SAFETY VALVE, AND INSIDE B(:P TO 2.50 PSI AND 3OOO 'PSI. 13. EEO:RD TEST IhF~TIO~I ~ BL~ ~ TEST F~o SION. AhD SEND TO C~:ILLING SUPERVISOR. 14. PER~O;~ ~E BCPE ~ ~ NZPPL]:NI~ UP AN::) WF_EKLY T~ER ~3:~LY C:PERATE ~ DAILY, ii l_ i i i llilll I! I I KUPARUK - VER UNIT 20" DI VE~TER SCHEMAT I C n u DE S CE I PT I ON - . ' . i. -16' C~CTOR, 2. TANi<O STARTER HCAD. 3. TAI~::O SAVER SUB. 4. TANI<O LO~E:R. QUICK-C~CT ASSY, 5. TANI<O UPPER QU ] CK-C~CT ASSY, 6. 20' 20,00 PSI DRILLING SPOOL W/I0' -OUTLETS. ?. I0' HCR BALL VALVES W/I O' DIVERTER LII~ESo VALVES OPEN AUT(::)MAT ! CALLY UPON CLOSURE CF A~AR PREVENTER, 8. 20' 20C~ PSI Aht~LAR PREVE~. . . - 5 1 RECEIVED APR 1 ~ ~986 Alaska Oil & G3s Cons. Commission Anchorage - MA]'NTENANCE & OPERATION I. UP-C~ INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. cLOSE AI~I~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 'CLOSE ANNULAR PREVENTER 'IN THE EVENT 'THAT AN I I~lUX CE' WELLB(:l~ FLU I DS OR GAS l S DETECTED. IF NECESSARY, MA~ALLY OVERRIDE AhD CLOSE APPROPRIATE VALVE TO ACHI EVE DO~I ND D! VERS I ON. DO NOT SHUT IN NELL UNC~R ANY C I RCUIVlSTANCE5. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2 Install Tankco diverter system. 3 Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run'and:cement 9-5/8" casing, .5. InStall and test.blOw out preventer. 'Test Casing to 2000 psig. 6. Drill'out cement and 10' new hole. Perf°rmleakOff test. 7. Drill 8½" hole to. logging point accOrding to. directional'Plan. 8.' Run,open hole l°gs. 9.' Continue drilling 8½" -hole to prOVide 100' between plug'back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. :Pressure test to 3500 psig.. 11. Downsqueeze Arctic Pack and cement in 7"' x 9-5/8" annulus. 12. Nipple down blow out preventer and .install temporary Xmas tree. 13. Secure well and release rig. 14. Run cas.ed hole'logs, 15. Move in workover rig. 'Nipple up' blow out preventer. 16. Pick up 7" casing scraper and tubing, trip~ in hole. to plug back total depth. Circulate hole With clean brine and trip out.of hole standing tubing back. 17. Perforate and run completion assembly. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to. diesel and set packer, 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. RECEIVED APR l 4 1986 Alaska ~", ' , LWK4 / ih $%'f K . .. CEHTR I Fu6F.. .'ryPIC,qL mud Sy$'l"~m $CHEm~T*IC DRILLING FLUID PROGRAM Spud to 9-5/8" surface. Casing Dens ity 9.6-9.8 PV. 15-30 Drill out ,t° Weight Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 . Filtrate AP1 20 pH 9-10 Solids 10_+ 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - T~ple Tandem Shale Shaker - 2-Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor · - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. / Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. L~5%5 / ih Rr CEIVED APR 1 z,, i986 ~aska Oil & Oas Cons. ~o,,. ..... Anchom~e ':RCo'.ALASKA. !NC. - ~AD 3N...WELL' NO, 12 REVI~ED PROPOSAL' . iUPARUK FIELD,- NORTH SLOPE. ALASKA --/_~,k,~ . . ; ....... ...... : .... ~ .... ; .__ ,. .............. ........... ,,:-3~ :. FROST -.'.-~TVD=l.71- =-17 =12 "- .... /..'.;'::_.. -~ .................. PER 100-FT ........ , ............... : ........... i .................. : ..... ............ 27 TOP UGNU SNDS 'TVD=2~67 T~D=251~ :DEP=263 ' ; ........ T ......... 39-'EOC ~TVD=2778 THD=2900 'DEP='490'- ............. : ................... ::::.:. :::.:_ - ........ :~_L;?/__.:~__,, SAK'_~SNDS, '} .TVD=:B.l_67:TM.D=~23 DEP=841 . ~ ......... .......... : . . . ..........................................2 THD~37~6. DEP~ 1 05Z ....... ~ ......... , ......... ._~....y._. __.. - _ : ..... TVD=3607 THD=4015 DEP=1237 : ................... ..... ~ .- . : ...... :...'A-VERAOE'._ANGLE ........... g~R1 ~, lSS~ '. .... ..... '~ 42 DEG , ...... ~,J, ~ GaS ............. : ' Alaska ."" : . . : ...... ~... . . ....... ~ .... K-5 TVD=5417 T~D=6451 DEP'2866 ; ....... -i ......... : ....... ~ ......... ' .-: -' ' T/ ZONE D TVD=6207 T~D-7514 DEP=357Z ..~_. :_~ .... '-'::.~_.'_:__:_~-~-:'.:-. _:::'-.~: .... :._~ ::' :,": ..... ~ .... '-.. x T/ ZONE C TVD 6260 TMD Z585.DEP 3625 :~:'. '-1 ' :' '~':-:':-[~ .....~-:_""~. -::::__~':_::~-_ .... ~-~ ','-' .T/ .ZONE A' TVD=6398 T~D-7771 :'DEP-~74 '000- t 7: :"~_': ::::: :::::::::::: : ::::: :::: .... ~T :::T: ._- .... :-: ~ /--- ~ . ':'-:-~:- TD :(LO9 PT) 'TVD=6656 TMD=8117 -. _.-' 0 ......... ~ooo:.~' ..;-:: tooo. '." '::;::: ~ooo --4ooo :'. :;',_.' ..... ;'?,:_.' .... " _. ~ .................. ~ - , : . ~ - ~ ~ . _~ ...... ,, - ~ ...... . . ...... -L.-i_.7~7_ -.-"-;-".;';-.-'_-_~-;;-_i: ....... __: ..... "-;-- SCALE 1_ i-'114 ;'-' ='" .1 000_' FEET . . ~ '" t , . .... ~ ...... . ....... ~--: :- ....... ~ ........ =:-7--: ...... ARCO.-Ak&SgAi: IHC.---= ,-~ ...... ~ .................... ~--~N---; ~~-~ - --~- ..... ~ ............. ~'-:- -:':--?--:=-" ...... ~:~ ...... :F-PAD 3N';',' :~ELL~-NO'--12 --': REV'I SED ', .............................. ; ............. ~' ~ ' ? i'~ ', ~ ~~-~'- ................ ~ ........................ ~ ....................... ; ........................... ; .................. ~ .................. ~ ....................... '-'- : --/::-::.: :'-.' :-:--': ..... 'ooo ' : ............. SBF&~ L~&~IB ~ ~ ........... ~ ........... ~ ......~-~-,--~ ........i ..... ---; ...... ....... ~C;-'29;-"Tl~N'."-R~ ; : / ......... ~ ..... ~ F~%1 !r :' ' [ ........................ [-: .... ¢' ~ - .............. ~ .... 4 .................. ~ ............% ................. ......... % ............ ~ ......... ~. , '; ....................... ; , - ..... .-~: --;-- .._ .F .......... ~ ............~ ........ ~ .............. ! .......... ~ ............ ~ ....... 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I . , i : : .... .. ~ -- , } ..... ~. ~ , . . { ~. . . . _., .:...1.~ ........... ~ ..... ;.~..: ...". -.,...?,+.~_~...:.l., ...... ..Il:....,._;.., ~.....~ ........ ~..:.~..~ ...... ~ ...... :..., ....... ,..~ .......... ~..."~ .... ~.l:._: ....... +.l~"__.~l..~..~ I ~ '...'l:,'".~:~'.~~~ ~ :;~,~ ~.; ~: ~-; ~, , :~ .l~: ~ . ~ . t.: ..... ~'. ; 1:',, I . . , . ] ,. , . . . ~ ~ . ~ .... , ~ .. -- .' .... ~ . .,.. .. , ., .... ~..:.-~ .... ~.~...,..,~ , ~. ~, ~ , ,. ,. t ~ ..... ...... ~ ~ , ' ~ I ' . .~ . .. : ....... l., .r: : . , ~ ~ - ~ : ~ j ' . , ~ _ _ ~ : ' , ~.. ,i~ '.-~ ~:..i-"?:-;:.~.~'f.~,'.~.~ ~ - ~-,[sos6~il. ;~~.~oo~'841 .... , ~ ~, ~. .:. ,..-~-.{ .~oo~eoJ .-~ ' ' ' ' ' " , ~ ~' ' ' ~ 'I ,~ ' · o'o , o : oo 2oo 3oo - I F.~ : , I [ .. ; . .. ARCO Alaska, Inc.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If RECEIVED - Alaska Oil & G:s L:3ns. u,.,i:,,~ .... ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany LOCATED IN PROTRACTED SEC', 28 & ~:9~TI3 N, R 9E,U.¥. LOCATED IN PROTRACTED LOCATED IN pROTR'A'CTED SEC. 29, T13N~ R9E, U.M. SEC. ag, TISN,RgE, U.M, 1 - Y = 6,013,799.67 LAT. 70026'55.9615" 10 - Y = 6,013,799.37 LAT. 70'26'55.9519" X = 517,946.19 LONG. 149~51'lZ.938" X = 518,aZ~.07 LON6,149~51'04.865" 454' FEL, 1562' FSL 06 - 28.2 PAD = 33.7 179' FEL, 1561' FSL 06 = 28.5 PAD = 34.0 2 - Y = 6,013,799.65 LAT. 70°Z6'55.9606" 11 - ~ = 6,013,799.3Z LAT. 70'Z6'55.9508" X = 517,971.Z1 LON6.149°51'12.203" X = 518,246.03 LON6.149~51 4Z9' EEL, 156Z' ESL Oi = ZS.Z PAD = 33.8 155' FEL, 1561' FSL 3 - Y = 6,013,799.54 LAT. 70°Z6'55.9590" 12 - Y = 6,013,799.45 LAT. 70°26'55.9515" X = 517,996.25 LONG. 149°51'll.468'' X = 518,270.89 LONG.149'51'03.403" 404' F[L, 156Z' ESL 06 = 28.4 PAD = 33.9 130' FEL, 1561' FSL 4 - Y = 6,013,799.50 LAT. 70~Z6' 55. 9580" 13 - Y = 6,013,799.41 Lit. 70~Z6' 55. 9505" X = 518,0Z1.16 LONG. 149°51' 10.736'' X = 518,295.97 LO, a. 149'51'0Z. 666" 379' EEL, 156Z' ESL 06 = 28.4 PAD = 33.7 .--~ 105' EEL, 1561' ESL 5 - ~ = 6,0~3,799.~ LAT. 70°26'55.9572" ~ 14 - Y = 6,013,799.33 LAT. 70'Z6 55.9491" X = 518,046.18 LON6.149°51'10.00Z" '~ X = 518,320.91 L~6.149'51'01.934" 354' FEL, 156Z' FSL 06 = Z8.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL ~ = 28.5 PAD = 34.0 6 - Y = 6,013,799.44 LAT. 70°26'55.9562" . ~ CO ~ 15 - Y = 6,0~3,799.28 LAT. 70°26'55.9480" X = 518,071.24 LONG. 149o51 09.266" X 518,345.77 LONG.149o51'01.204" 329' FEL, 1562' FSL 06 = 28.5 PAD = 33 9 ~ ~ ~ ~ ' . ~ ~ 55 FEL, 1561' FSL OG = 28.5 PAD = 34.0 7 Y 6,013,799.44 LAT. 70026'55.9556" ~ ~ ~ ~ - = o 16- Y = 6,013.799.25 LAT. 70"26'55.9471" X = 518,096.21 LONG' 149°51'08' 533" ~ O ~ ~ X = 518,370.74 LONG. 149'51'00. 470" 304' FEL, 1561' FSL OG = 28.5 PAD = 33.9 ~ ~ ~ ~ 30' FEL, 1561' FSL 06 ' 28.5 PAD = 34.1 8- Y - 6,013,799.45 LAT. 70°26'55.9551" ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70026'55.9466" X = 518,121.15 LONG. 149°51'07. 800" ~ X = 518,395.63 LONG. 149~50' 59.739" 279' FEL, 1561' FSL 0G = 28.6 PAD = 33.9 ~ ~ ~ 5' FEL, 1561' FSL 0G = 28.5 PAD = 34.1 g- y = 6,013,799.42 LAT. 70~26'55.954Z" ~ ~ SEC. 28,TI3N, R9E, U.M. x = 518,146.15 LONG. 149~51'07.066" 254' FEL, 1561' FSL 0G = 28.6 PAD ~ 34.0 ~ 18 - Y = 6,013,799.15 LAT. 70o26'55.g44g" x = s]8,,~o.8o L0,G. Z4~oS0'Sg.000" NOTES zo' FWL, 1561' FSL 0G = 28.5 PAD = 34.0 I. ALL COORDINITES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE TRUE, 3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD aASSOC. 4. VERTICAL POSITIONS BASED ON MODULE PILES ~JOl-B ~ ~JOI-4. 5.C.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3090 rev.~. ii i i iii i i , ii ]umm ,: w. . DRILL SITE 3N CONDUCTOR II¢°e~ i i'1" i J i ii April 11, 1986 Mr. J. B. Kewin Regional Drilling Engineer AR~O Alaska, Inc ~ P. O. Box 100360 Anchorage, Alaska 99510-0360 -Telecopy.. (907) 276-7542 Re .- 3N- 12 ARCO Alaska, Permit No. 86-79 Sur. Loc. 1561'FSL, 130'FEL, Sec. 29, T13N, R9E, UM. Btmhole Loc. 2038'FNL, 1573'FWL, Sec. 33, T13N, RgE, UM. Dear Mr. Kewin: Emclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional Permits required by law from other~ governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commen~lng 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. ~ t~Qur~, . . Chatterton ' Chairman of Alaska Oil'and. Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Es~.. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3N-12 Dear Mr. Chatterton- Enclosed is a Permit to Drill application for Kuparuk 3N-12. We estimate spudding this well on April 12, 1986. We propose to drill this well using the attached diverter diagram. We are therefore requesting a variance for this Kuparuk well. A modification has been planned and should be completed in approximately 3 weeks. The modified system will be operationally equivalent to the new requ i rements. If you have any questions, please call me at 263-4970. ~~al ~rilling Engineer JBK/LWK/tw PD/L03 Enclosures RECEIVED APR 2 2 986 Alaska Oil & 8as Cons. C0mm/ee/0~ AnChOrage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany I~Ek.r I V EIJ ~,,,-,,,. STATE OF ALASKA ALASKA L ~AND GAS CONSERVATION CO...:VllssI~IR ! ! ]986 P ER M IT TO D R I L L 0il & Gas Cons. C0mmissiml 20 AAC 25.005 Anchorage i la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenF-II, Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68' , PAD 34' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1561 'FSL, 130'FEL, Sec.29, T13N, RgE, UN Kuparuk River Unit 5tatewide At top of productive interval 8. Well nurpber Number i;.B.B-I.F, re~-L, %-%-f~.~-~"P~'t, Sec.33, T13N, RgE, UM 3N-12 #8088-26-27 ~.o'''Atoo to~a~ oe~th~..~f 9. Approximate spud date Amount t,,1,iI-~-'FNL, :¢..JL~'FWL, Sec.33, T13N, RgE, UPI 04/12/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 5~-8-e-e 3688' ~ TD feet 3N-11 25'~ surface feet 2560 (~'TVD)&~,~¢. feet 16. To be compu~e~d for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth.~ feet Maximum hole angle42 0 Maximum surface 291 8 psig At total depth ('rVD) 3~50 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ;~4" 16" 6~__5~ "-~0 Weld ~0' 35' 35' ~!5' !!5' ±200 cf 12~" ~-5/8" .~6 . O# .I-KK RT~. '~, fiqO ' qq' %q' R7?K~ RKO7~ 113913 HF-ERW :~,o gx Cl~.~.~ ~ hl~.nd 8~" 7" 26.0# J-55 BTC 7766' 34' 34' 7800' 6657' 300 sx Class G HF-ERW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface ~ L. Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch~ Diverter Sketch,J~ Drilling program Drilling fluid program ~1[ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby cert~at the foregoiQ.g is true and correct to the best of my knowledge Signed /~..~~~ TitleRegi°nal Drilling Engineer Date~/,~~ ""/'~' ~ ~' /" - Commission Use Only (LWK) PD/PD250 '' N umb"~r Permit ~b- ~7~ 50-- ~,'Z.,'~ - Z/~$t- 04/11/86 for other requirements Conditions of approval Samples required [] Yes .~.No Mud Icg required L---J Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No R equiredwor/~r.~..~~o/~~~~ ~5M; © 10M; [] 15M Other: by order of Approved by ~ .... ,~ ! /'~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit i~ triplicate : ~ ~ LI V LI./ STATE OF ALASKA ALASKA C~'~';AND GAS CONSERVATION APR ! 1 1986 P-ERMIT TO la. Type of work Drill ~ Redrill F-11 lb. Type of well. Exploratory [] Stratigraphi~"~t"~~ Development O"ii Re-Entry'~ DeepenE]I Service [] Developement Gas [] S!ngle Zone Jli¢ Multiple Zone [] 2.'Name of Operator ~: ' 5. Datum Elevation (DF or KB) 10. Field and Pool ::.. ~,RC0 Alaska, Inc. . :" RKB 68' , PAD 34' feet Kuparuk River Field -'3. Address ' - " - · 6. Property Designation Kuparuk River 0il Pool ~'.0 .Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 , 4..LoCation. of-'well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 561'FSL,. 130'FEL, 5ec.29, T13N, R9E, UM , Kuparuk River Unit 5tatewide At top of productive interval 8. Well nurpber Number ~)25'FSL, 1468'FWL, Sec.33, T13N, RgE, UM 3N-12 #8088-26-27 At total depth 9. Approximate spud date Amount · 118'FNL, 1592'FWL, Sec.33, T13N, RgE, UM 04/12/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7800 'MD :)688' ~ TD feet :)N-11 25'(~ surface feet 2560 (6657'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth2340 feet Maximum hole angle42 0 Maximum surface 291 8 pslgAttotaldel:)th('l'VD) 3350 psi{) '18. Casing program Settir{g Depth size Specifications Top Bottom Quantity of cement , , Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 193r," ~ _~/R" ~R.O~ .I-~ RTF! ~q¢l' ~' ~' ~77~' ~Rf)?' ll~n ~ ~q I I I HF-EI~t~ ?BO ~x Cla.~.~ ('l hl~nH 8~" ~7" 26.0# J-55 BTC 7766' 34' 34' 7800' 6657' 300 sx Class G .. HF-ER~/ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present welt condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee 1~ ProPerty plat ri., BOP Sketch ~1~ Diverter Sketch ~ Drilling program ,~ Drilling fluid program l~, Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAO 25.050 requirements [] 21. I hereby cert~at//,,,~~~,/.~~/the fore(join_j) is true and correctTitlet° theRegionalbeSt of my Drillingkn°wledge Engineer Date Signed - ~,~/y " ~ ( LWK ) PD/PD250 '' '~,// // Commission Use Only . lye§ I A,, numbe, I Approval date I See cover letter Permit Num 6_79 50-- 029-21582 04/11/86 for other requirements . Conditions of approval Samples required [] Yes [] No Mud log required E3 Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pr~..~sure for BCP-E ~4;;32M;.. l'q,,3M; [] 5M; [] 10M; [] 15M Other: b ~.'~/~_~~~~~ -- by order of Approved y Commissioner the commission Date , , Form 10-401 Rev. 12-1-85 ~ / ? Subr¢ triplicate ! I I L I ,> 5 4 3 /"-,, DIAGRAM #1 15-5/8" .CX20 PSI RSRRA BCP STA~K i. 16' - 2000 PSI TAN<CO STARTING 2. 11' - 3000 PSI CASING 3. I1' - 3000 PSI × 13--5/8' - 5000 PSI SPACE~ SPOCL 4. 13'-5/8' - 50CX3 PSI PIPE RAh~ 5. 13--5/8' - 5000 PSI I:::RILLING SP(:X~ W/Q-O~ AN:) KILL LIhES 6. ~3--5/~' - 5000 PSI DOJBLE RAM W/PIPE RA~ CN 7. 13--5/8' - 5000 PSI ACCLMJLATOR. CAPACITY TEST I. Q-EQ< AND FILL ACQ.M, LATCR R~,qE3~OIR TO '~ LEVEL WITH HYDRALLIC FLUID. 2. ASS~ THAT ACO.JvU_ATOR PR~S,,qLI:~E IS ~ PSI WITH I~_w~O_ PSI DO~NST~ CF l'l-E REGULATCR. 3, ~VE TI~4E, ll-EN CL__r~E ALL t,NITS SIIvU. TAh~Y ALL UNITS ARE CLOSED WITH Q-LARGING PtM= OFF. 4. RE~ ON NADC REPCRT, THE AO::E~T~ L~ LIMIT IS 45 SE~ CLOSING TIIVE AN:) 1200 PSI REI4AINING PRE~. RECEIVED APR 1 1 1986 Alaska Oil & Gas Cons, Oo;:~mission 13-5/8" BOP STACK TEST !. FILL BCP STACK AND CHCKE ~IF~ WI~ ~C DI~. 2.~ ~T ~ L~ ~ ~ IN ~Y ~RA~. ~T ~T ~ IN WI~ ~I~ ~ ~ ~ IN L~ S~. V~S ~ ~ ~~ ~. BL~ ~~ TO ~, 5. ~ ~ PE~~ ~ ~AL K~ LZ~ VALVES. ~ T~ PIPE ~ ~'~ VALVES ~ KALL ~ ~E L~~ 6. TES~ TO 2~ PSI ~~ ZN ST~ 4, 7. ~I~ TESTI~ AL~V~VES, LI~, ~ ~S WITH A ~ ~I L~ ~ 5~ PSI HI~. T~T AS TEST B~ PIPE ~ TO ~ ~I ~ ~ ~I. 9. ~ B~ PIPE R~, ~ ~ .!0. ~ ~I~ ~ ~ T~T TO ~ PSI. ~UID. ~ A~ VALV~ )N ~I~I~ TEST ST~I~ VALVES. ~_LY, ~Y ~S, 3~ PS]. .... r, i nn~.~,{3o I REV. i i i __ i i ii -- I, ,i , II KUPARUK RI VER UNIT 20" .DIVEF TER SCHEMATIC DE SCR I PT I ON I. 16' CO',,EXJCTO~. 2. TAhi<O STARTER I-.~AD. 3.. TANKO SAVER SUB. 4. TAha<O LO~R. CXJ! CK-C~,,I~CT ASSY. 5, TABOO UPPER (:~J]CK-C~CT ASSY. 6, 20' 2000 PSI DRILLING SPCX)L W/I O' .OUTLETS. 7. I0" NCR BALL VALVES W/lO' DIVERTER LIKES° VALVES OPEN AUTC~TICALLY UPON CLOSURE OF AhI~.JLAR PREVENTER. 8. 20' 2CX:X3 PSI AhX, IJLAR PREVENTER. moDIFIF...~ To BF. op~g'(toNAI.cY E6~uIVA£E~T 7'o NE~d Rr~UlREPIENTS. I · · --RECEIVED ' APR 1 1 1986 ' Ct/,q A~a ..... oii & Gas Cons. Commlsslon Anchorage MAINTENANCE & OPERAT. ION iii UP. ON INITIAL INSTALLATION. · PREVENTER AND VERIFY THAT HAVE OPENED' PROPERLY. CLOSE VALVES cLosE .A~LAR PREVENTER AND BLOW AIR .THROUGH DIVERTER LINES · EVERY 12 HOURS. CLOSE AhtCJLAR PREVENTER ' I N THE EVENT 'THAT AN Ih, FLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANtJALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE DO~I",,'WlND DIVERSION. DO NOT SHUT IN V~LL j ii UNDER ANY CIRCUMSTANCES. i i iii, iii GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point accordin$'to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill 8½" hole to logging point according to directional plan. 7. Run open hole logs. 8. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 9. Run and cement 7" casing. Pressure test to 3500 psig. 10. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 11. Nipple down blow out preventer and install temporary Xmas tree. 12. Secure well and release rig. 13. Run cased hole logs. 14. Move in workover rig. Nipple up blow out preventer. 15. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 16. Perforate and run completion assembly. 17. Nipple down blow out preventer and install Xmas tree. 18. Change over to diesel and set packer. 19. Flow well to tanks. Shut in. 20. Secure well and release rig. 21. Fracture stimulate. :~H,4/** E I CLE,4NF_..I~ I STIR. r~ cl D I STIR RECEIVED APR 1 I 1986 AI;~ska 0:,i & Gas Cons. Corn;:','::' A:;chorage LWK4/ih TYPIC/iL ~UD sy51'-~m SCHEmRTiC DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35 -45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. LWK5/ih .- ' ARCO ALASKA, INC. PAD 3N, ~ELL ~0~ 12 PKOPOSED ........... KUPARUK....~EI~ELD, _NOR~_H ..... S~'O~E~ .... 6L_ASKA EASTMAN ~HIPS/OCK. INC ~ ..... ~ . . .... .... BASE PERMAFROST- TVD=171Z ........... Alaska Oil KOP--- -TvD;2340 'T,D'2340 DEP=O - - ............... ~TOE~UONU_SNDS ....... TVD=2467 .THD=2467_ .DEP=4 .............. ~ ..... ~ 9 BUILD 3 ~G ,,,~ ]5 . PER 100 FT 2 ~ 33 K'12 TVD=3407 TMD=3472 DEP=326 ' ~ ~~' EOC (9 5/8'"CSO. PT) 'TVD=3607 T.D=3725 DEP-481 ~ _ .4ooo ................ x ................................................... ~ / X ' AVERAGE AN~LE =_ _l ..... _- ....... ._ ..._.~ ..... 41 DEO. 3S .... '~oo°:.: --[.::--x_:_~ ....... ::::.:: .......... :_ ....... ~ ................ ........ -_..: ................ ..' ...... ... _' -' :' ' T/ ZONE C TVD=6260 TMD-7270 DEP-2832 ' · ....... ~ .......... ~ -- ~- , ~ ,T/'ZONE.A TVD=6398 THD=7455 DEP=2955 ...... ~ .... ' ....~ ....... ~ ...... ~ · B/ KUP SNDS TVD=650Z TMD=7600 DEP=3051 ......... ..... ~ ~ ' -~ ....... ~ I' .... "' .TD (LO0 PT) .TVD=6657..THD=7800 DEP=318 . .......... : .... I I .......... ~ .... ~ ........ ; · ....... . : ."'. .... D ..... ~ooo":_' :~ooo.' ........ ~ooo" .ooo ". '..' . ' . : ......... - ................. ..... :---~--VE.~.C'"~--SECT~O. :~ .......... ' .................... :: .............. .............................. ., ~ ~ KUP ARUK-- F I ELD ,--:--NOR TH ;-'SL OPE.,----ALASKA- - - ~ ... ~-- -% ...... ~ ........... I ........................................... ....... 2000 _._ ' ................................. ..... . .......... . ..~000 ...... IAR~T. ~NTERZ-~ ................................. 0. O0:~ : : O' ,, · O0 1~' · thru (23 thru 28) (29 thru 31) Geology: Eng~eerimg: HWK_~_~_ LCS ~/~ reV.f 04/03/86 6.011 p roper; dis t aAC~:e, from ' property 'Line'... .......... Proper" disrobe fr°m` 'other wells ,..,..., ........ 5... Is: sufficient:,'undedicated at .:available in this pool ....... 3re plat inClUded .,. ........ ... ®.eeee®eee, · , ': ::::: '" I t DOes operator have bond ·., o::: .... :..: ....... :.. ::: :::: i,~!IO Is conservati or~er.[needed '. ......... · :' .. "a on: ' ' . t i i t i I i I I t t,I t t ltl · t I t t t I · ':: 11..'Is :administrative apProval' :needed 12 'Is 'the lease nUmber appropriate 13, Does the well' have a unique:name and nUmber 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. '25. 26. 27. 28. For 29. 30. 32. Is conductor string provided Ilttltlll'tllillllllltllllllllttllllllll Will surface casing protect fresh water ' zones ....................... Is enough cement used to circulate on conductor and surface ......... ~ " Will cement tie in surface and intermediate or production strings ... Will cement cover all known Productive horizons eoee®eeeeeoee®®eeeeoe 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 ' ooe'olOOOoo.o.oooooooooooooo · Is a diverter system required ..................................... ~ Is the drilling fluid program~schematic and list ~} equipment adequate ' Are.necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to~_~2_O_~pstg .. ~ ' th h k if ld ply /API RP 53 (F b 78) .... Does e c o e man o com w - e ................... Is the presence of H2S gas probable ~ o'------.....o......oe..o..o..... exploratory and Stratigraphic wells: Are data presented on potential overpressure Zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ' ''''oo~'o-oooo.~.o.o.oo..oo~.....oooooo.~o... INITIAL OEO. UNIT ON/OFF · POOL CLASS STATUS AREA NO. SHOKE Additional Remarks: ,, 7I.,~_ ~,,~-11 /~,,,y 1o~- 1'0o/o~ :~'~ -10 · ,.,.. (5 (4) Casg (14 ch{-u 22) (23 thru 28) (29 thru 31) Geology: Engineering: HWK LCS BEW rev: 04/03/86 6.0~ ~ /:!:!'-:i. ' '~ ,: :~, ~ ' .. :: . . :: i' : " " be lo~te~ a ~ed-pool t~OC d p 'o~h ate roper 'distace fr~ er we ............. ....... ~ ~dedica~ed acreage ava · be de~ated/~d ~ we~bo P~t ~Clud · ~e, ' ed ' ............ ... --, ,':' ~ . "t e o~y ~fec~ed par~y~ ..,~.., ...... . ................... . .... _ be approved 'b~ore t~-day' w~ ~ ~ .. ....................... , . . 9 :or have a bond in force ~ · o.e···· · 00.·0 · 0o~ 00-000000· 00-- oo.. orde~ needed '. ..... ......... - ....................... 1:1. _is approval needed .................................... 12 ' Is ~he lease n,-,ber appropriate - ' · ·oeoee. 00· ·...···eeeoeo..··- ·.00··000 13· Does i the well have a unique name and number ......................... 14. 15: 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ............. ;..~ ..... Will all casing give adequate s.afecy 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 ...; ........................ 23,¸ 24. 25.. 26. 27. 28. Is a.divercer system required ... .................... ....... . ......... Is the drilling fluid program~schemacic and liSt of equipment adequately, Are necessarydiagrams and descriptions of diverter and BOPE at.cached· Does BOPE have sufficient pressure racing - Test to ~ O~O pstg .. · 78) Does the choke manifold comply w/APl RP-53 (Feb ................... Is the presence of H2S gas probable ................................. For exploratory and stratigraphic wells: 29. Are data presented on potential overpressure zonesv. ................. 30. Are seismic, analysis data presented on shallow gas zones .., ......... 31. If an offshore loc., are survey results of seabed conditions presented 32 Additional requirements -:"~ · .o..eeoeeeooeeeeee·oe·eeeeeo®e·eeeoeo·oeoeoee POOL q oteo INITIAL CLASS-STATUS GEO. [ UNIT AREA NO. O~/OFF SHORE Additional Remarks: W~//-?~/ ~N-II~ ~- 700' ;' 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. ~/iA¥ ! c) 198l~ MIC O[ILMEI) LV~ OiO.H02 V£Ri=iCATI3~,i uiSTIN'3 ~.~%$ = 1 SERViC: N4'~ii :=iDiT DAT.~ ORiSiN : R~SL N~M~ :149502 C~TINUATi~N ~ :01 PREVIOJS REEL : COM~q~NT5 :LIBRARY T~P~ SERVICE NA'qE :~.3ZT DATE :,35/04/30 ORIGIN :0000 TAPE NA;~,E :143~ CONT'INUATi3N ~ :01 PR[VI~dS TAP~ : COMMENTS :LIBRARY TAPE FiL~ SERV VE R S OATr- MA X i PRF_V iLE HEADER :',:=:-' NA~qE :EDIT ICE NAME : iON m : MUM LENGTH : TYP~ : I 0 U S F I L ~ : .00i 1024 NF.ORMATION RECORDS <-' CONTENTS CN : ARCO ALASKA NN : 3N- 12 FN : KUPARUK RANG: 9E TOWN: 13N SECT: 29 COON: NORTH SL:OP~ STAT: ALASKA CTRY: USA ~N~M CONTENTS PRES: E U N ! T TYO: 000 000 000 000 000 000 000 000 CATE gO0 000 gO0 gO0 go0 000 000 000 0 O0 C~T~ 000 .SIZE 0t5 OOB 008 002 O04 002 012 005 S'tZE 00 1 CODE O 65 O65 065 0,65 O65 O65 065 06:5 O O ': 065 LVP 010.~02 V~i~iC~TiCN L!3TiN~ o~G~ ~ -~ .~L~SKA CSMP:JT~NG CENTS:~ =:~ COMPtNY = A~CD ALASKA !NC W~LL = 3N-i~ FIELD = <UPARUK COUNTY = NgRT~n SL3o5 5OR,UGH STATE = ~LASK~ JO3 NUM~3ER AT ACC: 71435 RUN ~1, 3ATE LOGGY3: Z3 AO~ 36 LDP: RICK KRUWELL CASING : 3.625" ~ 40~38' - ~IT SIZ= : ~.5" TO 8100' TYP~ FLUID = LSNO P~LY~E~ DENSITY : ~.9 LB/G RM : 4.07 ~ 75 DF VISCO.SITY : ~2 S RMF : 6.07 ~ 75 DF PH = ~).9 RMC = 3.55 D 75 D; FLJi3 LOSS = 5.4 23 RH AT 3'MT = 2.21 @ 144 DF MATRIX SANOSTON~ ~:~ THIS DATA HAS NOT 3EE~ OEPTH SHIFTED - OVERLAYS FiEL9 PRINTS LVP OlO.H02 VFRI:iC~,TZ]N LISTiN' ~"~$~ 3 SCHLUMEERSER LOGS INCLUDE9 W!T~ T'iiS M~,SNETiC TAPE: ;;-' ZNjUCTZDN SPH=RZCALL¥ $2CUS~3 DATA A:V~ZL~BLE: 3079' TJ ~08~' SDMP~SA'T~D N=UTRDN LgG (FDN) ~3RMATIDN D~NSZTY COMD':NSATED LOS ('JN) ::~ DAT~ AVAILABLE: 8049' Tg ,5~00' ~ DA'TA ~3RMAT ENTRY SLOCKS R ~CDRD-,- 15 0 :SIZE 1 1 4 1 1 CmDE 6:5 73 ~NTRY 0 $0 ,lin i 0 LVP OiO,MOZ V-RiFiCaTiO'~ LiSTiN3 ~:a3E ~ DATO{q So~CZFICgTION SL]CKS MN=_M SERVZ'E SERV"CE .J~,~IT SEPT SPLJ 3!L ILS DiL O-iMM ILM SP DIL GR DIL GR ; DN S .~ P i CALl ~H02 FON SfC3 DR~9 =DN G/C3 BRIT NPgi F~N PJ ~CNL =DM CPS FCNL ;R CSG G~Pi ~Pi ~PI 2nl AP? =iLl SiZ~ LOG TY?E CLASS q]S ~3. 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