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185-230
1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Friday, March 15, 2024 8:46 AM To:Regg, James B (OGC) Subject:FW: [EXTERNAL] FW: Nabors CDR2 BOPE Test Report Attachments:Nabors CDR2-AC 01-31-2024.xlsx Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Tom Kavanagh ‐ (C) <Tom.Kavanagh@hilcorp.com> Sent: Tuesday, February 27, 2024 5:30 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] FW: Nabors CDR2 BOPE Test Report Hi Phoebe, I have corrected as requested below, both items. This is iniƟal Workover for MPU B‐19. Thank you, Tom Tom Kavanagh CTD Drillsite Manager – CDR2 Rig 907 670 3097 Cell 907 841 2410 H4169 From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Tuesday, February 27, 2024 8:18 AM To: Tom Kavanagh ‐ (C) <Tom.Kavanagh@hilcorp.com> Subject: [EXTERNAL] FW: Nabors CDR2 BOPE Test Report Tom, I was following up on this email. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Milne Point Unit B-19PTD 1852300 2 Thanks, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Tuesday, February 20, 2024 11:30 AM To: Tom Kavanagh ‐ (C) <Tom.Kavanagh@hilcorp.com> Subject: RE: Nabors CDR2 BOPE Test Report Tom, The # of Nitrogen boƩles were missing; please advise. Also, should this be the iniƟal workover for MPU B‐19 or iniƟal drilling for MPU B‐19A? Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Tom Kavanagh ‐ (C) <Tom.Kavanagh@hilcorp.com> Sent: Thursday, February 1, 2024 5:35 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS ‐ CTD DSM <AlaskaNS‐CTD‐DSM@hilcorp.com> Subject: Nabors CDR2 BOPE Test Report Hello, Here is the iniƟal BOP test on well MPB‐19A. Thank you, 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. 3 Tom Kavanagh Tom Kavanagh CTD Drillsite Manager – CDR2 Rig 907 670 3097 Cell 907 841 2410 H4169 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:1/31/24 Rig Rep.:Coyne / Coyne Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1852300 Sundry #323-673 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2800 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank P P Annular Preventer 1 7 1/16" 5K P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator P P #2 Rams 1 2-3/8" Pipe/Slips P Meth Gas Detector P P #3 Rams 1 3" Pipe/Slips P H2S Gas Detector P P #4 Rams 1 2-3/8" Pipe/Slips P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)2960 P Kill Line Valves 2 2-1/16"P Pressure After Closure (psi)2250 P Check Valve 0 NA 200 psi Attained (sec)20 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)63 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1114 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 @ 1985 P No. Valves 12 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 4 P #1 Rams 3 P Coiled Tubing Only:#2 Rams 1 P Inside Reel valves 1 P #3 Rams 1 P #4 Rams 1 P Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/30/24 01:14 Waived By Test Start Date/Time:1/31/2024 8:30 (date)(time)Witness Test Finish Date/Time:1/31/2024 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Nabors Initial BOP Test, no failures Igtanloc / Kavanagh Hilcorp Alaska, LLC MPU B-19 Test Pressure (psi): greg.coyne@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2024-0131_BOP_Nabors_CDR2AC_MPU_B-19 J. Regg; 4/5/2024 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. Some people who received this message don't often get email from michael.heinzbrown@hilcorp.com. Learn why this is important From:Brooks, Phoebe L (OGC) To:Michael Heinz-Brown - (C) Cc:Regg, James B (OGC) Subject:RE: MPB-19 | Annular BOP Test, CMIT-TxIA Date:Friday, March 15, 2024 2:57:59 PM Attachments:MIT MPU B-19 01-20-24 Revised.xlsx Mike, Attached is a revised report removing the inspector’s name from the AOGCC Rep since witness was waived. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Michael Heinz-Brown - (C) <Michael.HeinzBrown@hilcorp.com> Sent: Saturday, January 20, 2024 10:10 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Subject: MPB-19 | Annular BOP Test, CMIT-TxIA Please find attachments and advise if anything further is needed for the two tests. Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 Milne Point Unit B-19 PTD 1852300 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852300 Type Inj N Tubing 0 2800 2775 2775 Type Test P Packer TVD 6845 BBL Pump 4.0 IA 350 3100 3050 3050 Interval I Test psi 3000 BBL Return 4.0 OA 0 0 0 0 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 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 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 Notes: Notes: Notes: HILCORP ALASKA, LLC MILNE POINT UNIT A.Haberthur / M.Heinz-Brown 01/20/24 Notes:Witnessed waived by Kam StJohn Notes: Notes: Notes: B-19 Form 10-426 (Revised 01/2017)2024-0120_MIT_MPU_B-19 Plug Verification - P&A of water injector J. Regg; 4/3/2024 By Grace Christianson at 1:27 pm, Mar 06, 2024 Abandoned 2/2/2024 JSB RBDMS JSB 032824 xGDSR-4/12/24 Drilling Manager 03/01/24 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.01 13:57:08 - 09'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 2/29/2024 SCHEMATIC Milne Point Unit Well: MPU B-19 Last Completed: 1/19/2024 PTD: 185-230 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 115’ 0.1571 9-5/8" Surface 36 / K-55 / BTRC 8.921” Surface 6,113’ 0.0773 7” Production 26 / L-80 / BTRC 6.276” Surface 5,121’ 0.0383 7” Production 29 / L-80 / BTRC 6.184” 5,121’ 10,684’ 0.0371 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP BTC 3.958” Surface 9,988’ 0.0152 JEWELRY DETAIL No Depth Item 1 2,451’ GLM #5, 4-1/2" BXP W/1" DK DUMMY & BK-2 LATCHES 2 4,294’ GLM #4, 4-1/2" BXP W/1" DK DUMMY & BK-2 LATCHES 3 6,159’ GLM #3, 4-1/2" BXP W/1" DK DUMMY & BK-2 LATCHES 4 7,322’ GLM #2, 4-1/2" BXP W/1" DK DUMMY & BK-2 LATCHES 5 8,403’ GLM #1, 4-1/2" BXP W/1" DK DUMMY & BK-2 LATCHES 6 9,826’ X Sliding Sleeve – VXD Profile 3.813” 7 9,881’ 7” x 4-1/2” Tri-Point Perm Packer LTC BxP 8 9,940’ X-Nipple - 3.813” 9 9,949’ Mule Shoe – Btm @ 9,988’ PERFORATION DETAIL Sand Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kup 10,102’ 10,119’ 7,116’ 7,127’ 17’ 10/20/1985 Open 5” 10,390’ 10,409’ 7,306’ 7,319’ 19’ 5/1/1991 Squeezed 5” WELL INCLINATION DETAIL Max Angle is 59 deg. @ 4,500’ OPEN HOLE / CEMENT DETAIL 17-1/2” 100 cf Permafrost Cement 12-1/4” 552 bbls Perm E, 56 Bbls Class G 8-1/2” 300 sx Class G TD =10,710’(MD) / TD =7,506’(TVD) Initial KB Elev.: 59.0’ / GL Elev.: 24.0’ 7” 8 13-3/8” 6 7 PBTD =10,123’ (MD) / PBTD =7,142’(TVD) 9 9-5/8” Whipstock set @ 10,123’ (2/1/24) 1 2 3 4 5 TREE & WELLHEAD Tree 5M FMC 4-1/2” Wellhead 11” 5M FMC w/ 4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-021451-00-00 Initial Completion by Nabors 27E- 10/19/1985 Install 4.5” Completion by ASR#1 – 1/19/2024 ACTIVITYDATE SUMMARY 12/31/2023 T/I/O=565/1225/300 (Welll Kill) Pumped 5 bbls 60/40 and 15 bbls 90* diesel followed by 420 bbls of 9.7 ppg NaCl with 1% 776 & lo-torq down TBG up IA taking returns to tank. (378 bbls returned) Freeze protected surface lines with 5 bbls diesel. BPV set. Final Whps=0/0/400 12/31/2023 WELLHEAD: LRS well kill complete, verify well on a vac and set 4 1/2 CTS Bpv with T bar. Pre RWO. 1/1/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, Run 4-1/2" Completion. Continue RDMO on MPF-65. Move camps, vac out Pits, disconnect BOP hydraulics. Disconnect Guy lines, lay over Mast. Move Rig to tent for maintenance and replace Kerr pump hydraulic pump. Lift Rig Floor from Cellar, stow stairs, HCR hoses and fill line. NU Tree & test void 500/5000psi. Pull BPV. Lift heaters from behind Cellar. Stow Koomey lines. Lift Cellar out. Clean up around location. ***CONT WSR ON 01/02/2024*** 1/2/2024 WELLHEAD: Bled CL and Hgr void to 0 psi, ND tree/adapter, clean hgr void, install CTS plug, new RX54 gasket, plug CL port and check lift threads 3 1/2 Eue. NU BOP. 1/2/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Continue NU BOP, torque bolts to spec. Lift Rig Floor onto Cellar, Mobilize ASR-1 to location and RU. Route and connect electrical, communications, Koomey, Kill, and Choke lines. Phase III called, suspend normal operations. ***CONT WSR ON 01/03/2024*** 1/3/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. WEATHER STBY ***CONT WSR ON 01/04/2024*** 1/4/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. WEATHER STBY 1/5/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Continue clearing snow from pad. Spot in pipe shed. Work on rig acceptance checklist. Winterize lines. Take on fresh water for the BOP test. Continue rig up Koomey lines. Continue working on rig acceptance checklist. Perform Fire & Gas alarm test. Run heated glycol lines & insulate pump lines. Rig acceptance checklist complete. Accept rig at 19:00 on 1-5-2024 P/U & M/U test joint w/ TIW. Begin BOPE testing as per approved sundry. All tests preform to 250 psi low & 3,000 psi high f/ 5/5 charted mins. *** Cont. WSR on 1-6-2024 *** 1/6/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Complete BOPE testing & accumulator drawdown test. Line up for well operations. Fill gas buster. Pull BPV, Pull hanger to rig floor. Circulate a bottoms up. For 290 bbls. No losses while pumping. L/D hanger. POOH w/ 2-7/8" 6.5# L-80 EUE GLM completion *** Cont. WSR on 1-7-2024 *** Daily Report of Well Operations PBU MPB-19 Daily Report of Well Operations PBU MPB-19 1/7/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. POOH w/ 2-7/8" 6.5# L-80 EUE GLM completion F/ 9,414' P/U wt = 12K. Pump single displacement, L/D BHA & Inspect. Otis " ratch latch " not present with SBR. Discission made to retrieve prior to PKR mill out. Mobilize overshot grapple from Deadhorse. Remove BHA & GLMs ( X 9 ) from pipe shed. Change over handling equipment to 3-1/2" Install wear bushing, 6.875" ID. Rack & tally 3-1/2" DP Load fishing BHA into Pipe shed & tally. Begin picking up fishing BHA; P/U overshot install 4.75" grapple, BS, & JAR *** Cont. WSR on 1-8-2024 *** 1/8/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Cont. picking up overshot fishing BHA; P/U 5x Drill collars, intensifier & XO to 3-1/2" DP RIH w/ overshot fishing BHA on 3-1/2" DP T/ 9800'. Kelly up and wash down to the top of the fish at 9874' DPM. Washed down at 1 BPM w/ 145 PSI. Engage fish, and verified with pump pressure spike and slack off wt. Set down 10K. Shut dw pumps. P/U & find neutral, and put 5K overpull in the string. Rotate 30 right hand turns to observe the ratch latch come free, and verify with pump pressure and up weight staying at 80K. Pump pressure remains 145psi. Brine 9.7 PPG - 40 Visc Monitor the well - static. POOH w/ overshot & fish, Laying down 3-1/2" DP to pipe shed F/ 9,874' T/ 5,395' Pump single displacement for trip. P/U wt = 44K No S/O wt due to fish *** Cont. WSR on 1/9/2024 *** 1/9/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. POOH w/ overshot & fish, Laying down 3-1/2" DP to pipe shed F/ 5,395' Breakout & lay down overshot assembly, observing No Fish in the overshot. Grapple pulled off. M/U BHA #2 - 5 7/8'' short catch overshot with 4' extension and basket grapple, LBS, jars & 5 DC', Intensifier. RIH w/ overshot fishing BHA on 3-1/2" DP T/ 6,322' Monitor displacement via isolated pits. Rig service, check equip. Change elevator spring & lock latch. *** Cont. WSR on 1-10-2024 *** Daily Report of Well Operations PBU MPB-19 1/10/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. RIH w/ overshot fishing BHA #2 on 3-1/2" DP F/ 6,322' T/ 9870' Make up Top Drive and establish parameters. Observed trouble codes on the rig transmission. Shut down fishing operations. Change out filters, add oil and reset trouble codes. Verify functioning as it should. Slack off and tag fish on depth at 9874', and continue swallow 4' of the overshot and grapple. Pull to verify catch. Pull over up to 130K to fire jars. Repeat firing jars 10 times verifying basket grapple catch. Pull to 8K over up weight and rotate workstring to the right 25 times while slowly pulling up. Observed weight fall off. Slack off again to full down weight and re-latch the ratch latch, verified by pump pressure increase to 1000 PSI, and overpull. Repeat 2 times, Monitor well f/ 30 mins - static. POOH w/ overshot & fish, Laying down 3-1/2" DP to pipe shed F/ 9874' Pump T/ 201¿ Begin Laying down BHA. L/D intensifier, 3x 4.75" Spiral DC's Fish Present. *** Cont. WSR on 1-11-2024 *** 1/11/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. L/D overshot BHA. Fish Present. M/U PKR milling & PRT BHA, RIH to 9890' Wash & ream to top of PKR. Obtain milling parameters. *** Cont. WSR on 1-12-2024 *** 1/12/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Mill PKR. Cont. milling w/ changing parameters & periods of dry milling. Packer fell free. Shut annular and circulate a total of 262 BBLs at 4.5 BPM w/ 1,000 psi. Observed light fluid and small amount of gas @ B/U Chase packer to 10,050' w/ 20K set down. Swivel out. Blow down all fluid lines. monitor well. Well static. Begin POOH POOH w/ PRT milling assy & fish, Laying down 3-1/2" DP to pipe shed F/ 10,050' T/ 652' *** Cont WST on 1-13-2024 *** 1/13/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. POOH w/ PRT milling assy., Laying down 3-1/2" DP to pipe shed F/ 652' T/ 201'. L/D PRT milling assy. * No PKR fish * Clean & clear rig floor. P/U test tools for BOPE testing. Test BOPE as per approved sundry T/ 3,000 PSI. Pull test plug. Install wear bushing. M/U Fishing BHA #4 w/ spear. RIH T/ 4,508' *** Cont. WSR on 1-14-2024 *** 1/14/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Cont. RIH w/ Fishing BHA #4. AT 10,050' Pump a BTU. Engage fish. POOH. L/D BHA #4 "Fish on" *** Cont. WSR on 1-15-2024 *** Daily Report of Well Operations PBU MPB-19 1/15/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. L/D BHA #4 & measure recovered fish. 54.1' of PKR & tail pipe recovered. Prep for clean out run, Change out handling equip. P/U & M/U clean out BHA. 6.125" junk mill, 7" csg scraper, 3x boot baskets, LBS. Simops; While clearing ice from around power cables, power cable was struck. Notifications were made. Electricians inspected cable. repair could not be made. Mobilize new cable Perform oil change on rig. Electricians finish making new cable. Continue M/U Clean out BHA. RIH w/ clean out BHA on 3-1/2" DP T/ 5,320'. Tag obstruction at 5,320' Kelly up & obtain rotating parameters. Dry ream w/ CSG scraper & clear obstruction. Cont RIH w/ clean out BHA on 3-1/2" DP T/ 6,170'. Displacement returning as calc. *** Cont. WSR on 1-16-2024 *** 1/16/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. RIH w/ clean out BHA on 3-1/2" DP T/ 8,611'. Displacement returning as calc. S/O wt = 47K P/U wt = 54K. Secure well rig having PLC issues. Cont. to trouble shoot PLC / comms issue. Repaired, all functions work with exception of elevator latch/ unlatch.Install manual elevators & continue RIH. RIH w/ clean out BHA on 3-1/2" DP to 10,010'. Rig up kelly hose to swivel, prior to tagging fill. Cont. RIH to 10,118¿ to tag fill/ sand. Line up to pump. Obtain parameters. Wash down T/ 10,124' Hard tag. Begin rotating w/ 60 RPM w/ 2.2 K ft/lbs TQ, seeing torque spikes to 3.4K while attempt to work past. Set up to 12K on obstruction. NO progress. Cont. attempting to work pass 10,124', with vary parameters. Set dw 20k "dry" with no movement. No overpull seen at any time pulling off obstruction with or without rotation. *** Cont. WSR on 1-17-2023 *** 1/17/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Cont. attempting to work pass 10,124', with vary parameters. Set dw 20k "dry" with no movement. No overpull seen at any time pulling off obstruction with or without rotation. Set dw 10K w/ 5 BPM 1,100 psi. No pressure change setting dw. Wash for 30 min with weight applied. No progress. POOH w/ clean out BHA F/ 10,124' , laying dw 3-1/2" DP to pipe shed. Well taking correct displacement. Break out and LD BHA. Attempted to retrieve Wear Bushing and found the Element for the Annular protruding into the BOP I.D. Cycle Annular without success. Call Yellow Jacket Rep. to replace. Inform OE, AOGCC Kam St. John. RD Spools and Risers,replace Element. ***CONT WSR ON 01/18/2024*** Daily Report of Well Operations PBU MPB-19 1/18/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Annular Preventor element replaced. NU Spool and Risers. Torque all bolts. Pull Wear Ring, install test plug. Pressure test new annular element w/ 4-1/2" test joint. 250/3000psi - Good. Witness waived by AOGCC. RIH w/ 4-1/2",12.6#,L, TXP-BTC completion T/ 4,070'. ***CONT WSR ON 01/19/2024*** 1/19/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. FINAL PUW=92k SOW=65K. Land TBG Hanger placing EOT at 9975.48' MD. Reverse circulate 130 BBLS of 9.7ppg Nacl w/ 1% Corrosion Inhibitor. Work up to 1.9BPM @ 290psi followed by 52 BBLS Diesel FP - 2 BPM @ 500psi . Attempt to Bullhead FP TBG, T/IA tracking w/ 1075psi @ 2 BBLS away . Shut down pump and bleed back. Ensure TBG is static, open Blinds, install Landing Joint. Drop STD B&R = 1-3/8" F.Neck, 1-7/8" Ball, 6.55' OAL. ***CONT WSR ON 01/20/2024*** 1/19/2024 Freeze Protect for ASR, Pumped 52 bbls diesel down IA, Pumped 2 bbls diesel down Tubing, Pressured up, Bleed back 1/20/2024 RWO Scope: Pre-CTD - Pull 2-7/8" Completion, RIH w/ overshot & retrieve "ratch latch". Mill & Retrieve Otis MHR Packer, 7" Scraper Clean Out, Run 4-1/2" Completion. Communication found during initial setting of Packer (see log for details) Perform successful CMIT-TxIA to 3000psi. Begin RDMO ***RIG RELEASED 12:00 END WSR*** 1/21/2024 ***WELL S/I ON ARRIVAL*** POLLARD #58 RIG UP ***WSR CONT ON 1/22*** 1/21/2024 WELLHEAD: M/U hanger to string then landed to RKB of 18.50' (final tally corrected to original RKB of 59', tubing hanger 31') verify land out, RILDS S/B for pump and test, Set BPV S/B for RDMO, clean up hanger/void, changed out all LDS 1 at a time torqued new ones to 450 ft-lb, set CTS plug N/U tree/adapter, test void 500low 5000 high 5/10 min good test, tested tree 500low 5000 high good test, M/U Tbar pulled CTS plug and BPV no pressure, secured well 1/22/2024 ***WSR CONT FROM 1/21*** PULL BALL AND ROD FROM RHC @ 9928' MD PULL BK-DGLV FROM @ 2446' MD PUMP FP DOWN IA, UP TUBING SET BK-DGLV @ 2446' MD PULL RHC FROM 9928' MD TO OBSTRUCTION @ 160' SLM PUSH RHC DOWN TO 500' SLM PUMP 60/40 AND BRUSH OBSTRUCTION @ 160' SLM RAN 3.77 SWAGE TO 300' SLM' RAN 3.80 SWAGE TO 160' SLM, BEAT FOR 1 HOUR, UNABLE TO MAKE IT THROUGH ***WSR CONT ON 1/23*** 1/22/2024 Freeze Protect Tubing Post RWO, Pumped 40 bbls diesel down IA up Tubing to tank, U-Tube TxIA for one hour Daily Report of Well Operations PBU MPB-19 1/23/2024 ***WSR CONT FROM1/22*** WEATHER HOLD ***WSR CONT ON 1/24*** 1/24/2024 ***WSR CONT FROM 1/23/24*** ATTEMPT TO SWEDGE TIGHT SPOTS FROM TUBING @ 122' & 160' SLM (3.80" BIGGEST SIZE ABLE TO WORK THROUGH 160' SLM, FEELS PRETTY SOLID WITH 3.81" SWEDGE) LAY DOWN FOR THE NIGHT *** CONTINUE ON 1/25/2024 *** 1/26/2024 ***CONTINUE FROM 1/25/24*** PULLED RHC PLUG BODY DRIFTED 20' X 3.70 DUMMY WHIPSTOCK DRIFT TO 10,115'SLM RAN READ CALIPER FROM 10,112'SLM TO SURFACE ***WELL S/I ON DEPARTUE*** 1 Tom Fouts From:Scott Pessetto Sent:Wednesday, December 6, 2023 2:44 PM To:Tom Fouts Subject:FW: [EXTERNAL] 20231206 1440: PTD: 185-230 MPB-19 Sundry 323-624 Attachments:MP B-19 PROPOSED_GLM 12-5-2023.pdf Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, December 6, 2023 2:42 PM To: Scott Pessetto <Scott.Pessetto@hilcorp.com> Cc: AOGCC Records (CED sponsored) <aogcc.records@alaska.gov> Subject: [EXTERNAL] 20231206 1440: PTD: 185-230 MPB-19 Sundry 323-624 - Be sure to include this approval email in the upcoming 10-404. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Records From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Wednesday, December 6, 2023 1:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD: 185-230 MPB-19 Sundry 323-624 Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 CAUTION:External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Rixse, Melvin G (OGC) To:Scott Pessetto Cc:AOGCC Records (CED sponsored) Subject:20240229 1123 APPROVAL MPB-19 PTD: 185-230 Sundry: 323-624 Date:Thursday, February 29, 2024 11:24:41 AM Scott, Hilcorp is approved to forego the witnessed MITs as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Thursday, February 29, 2024 11:07 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPB-19 PTD: 185-230 Sundry: 323-624 Mel, Per our phone conversation on MPB-19A. The well is a gas lift producer. We have obtained a passing MIT-IA to 3,000 psi for 30 minutes. We will not perform a witnessed MIT-IA or an MIT-T prior to bringing the well onto production. Thank you, Scott Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/2/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 213-26 50283201920000 223069 11/5/2023 AK E-LINE PERF KU 13-06A 50133207160000 223112 12/28/2023 AK E-LINE CBL MPU B-09 50029212970000 185034 1/26/2024 READ Caliper Survey MPU B-19 50029214510000 185230 1/26/2024 READ Caliper Survey PBU W-08A 50029219060100 202090 12/27/2023 HALLIBURTON WFL-TMD3D SRU 222-33 50133207150000 223100 12/16/2023 AK E-LINE CBL Please include current contact information if different from above. T38477 T38478 T38479 T38480 T38481 T38482 2/2/2024 MPU B-19 50029214510000 185230 1/26/2024 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.02 15:40:47 -09'00' 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:Michael Heinz-Brown - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:MPB-19 | Annular BOP Test, CMIT-TxIA Date:Saturday, January 20, 2024 10:11:03 PM Attachments:MPB-19 CMIT-TxIA_01-20-2024.xlsx MPU B-19 BOPE test report (Annular).xlsx Some people who received this message don't often get email from michael.heinzbrown@hilcorp.com. Learn why this is important Please find attachments and advise if anything further is needed for the two tests. Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW% 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 1/18/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1852300 Sundry #323-624 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: Bi-Weekly: Other: x Rams: Annular:250/3000 Valves:250/3000 MASP:2387 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators NA NA #1 Rams 0 2 7/8" x 5"NA Flow Indicator NA NA #2 Rams 0 Blinds NA Meth Gas Detector NA NA #3 Rams 0NAH2S Gas Detector NA NA #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 0 2 1/16"NA Time/Pressure Test Result HCR Valves 0 2 1/16"NA System Pressure (psi)NA Kill Line Valves 0 2 1/16"NA Pressure After Closure (psi)NA Check Valve 0NA200 psi Attained (sec)NA BOP Misc 0NAFull Pressure Attained (sec)NA Blind Switch Covers: All stations No CHOKE MANIFOLD:Bottle Precharge:NA Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA No. Valves 4P ACC Misc 0NA Manual Chokes 0NA Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 14 P #1 Rams 0 NA Coiled Tubing Only:#2 Rams 0 NA Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:1.0 HCR Choke 0 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/17/24 20:33 Waived By Test Start Date/Time:1/18/2024 3:30 (date) (time)Witness Test Finish Date/Time:1/18/2024 4:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Tested replaced Annular Preventor with 4-1/2" test joint. (Not due to well control event) C. Grueb / J. Werlinger Hilcorp Alaska LLC A. Haberthur / M.Heinz-Brown MPU B-19 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0118_BOP_Hilcorp_ASR1_annular_MPU_B-19 9 9 9 99 999 9 9 9 9 9 -5HJJ 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:Russell Gallen - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:B-18 BOPE test report weekly Date:Tuesday, January 16, 2024 5:09:48 AM Attachments:MPU B-19 BOPE test report (weekly ).xlsx Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important Thanks, Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW% 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 1/13/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1852300 Sundry #323-624 Operation: Drilling: Workover: x Explor.: Test: Initial: Weekly: x Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2387 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2 1/16"P Pressure After Closure (psi)1900 P Check Valve 0NA200 psi Attained (sec)15 P BOP Misc 0NAFull Pressure Attained (sec)56 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2393 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 14 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:4.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/11/24 08:33 Waived By Test Start Date/Time:1/13/2024 8:30 (date) (time)Witness Test Finish Date/Time:1/13/2024 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Hilcorp Tested w/ 3-1/2" & 4-1/2" test joints. Bottle average pre-charge = 1,000 PSI. Sundry allowed testing to be conducted at 2,500 psi. After updated bottom hole pressure reading. Maximum anticipated surface pressure is now 2,725 psi (2,387 psi reported in sundry) tested at 3,000 psi. Email communication sent to & approved by Mel Rixse. C. Grueb / J. Werlinger Hilcorp Alaska LLC A. Haberthur / R. Gallen MPU B-19 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0113_BOP_Hilcorp_ASR1_MPU_B-19 9 999 999 9 9 9 9 9 9 - 5HJJ Maximum anticipated surfaceyg pressure is now 2,725 psi (2,387 psi reported in sundry) tested at 3,000 psi. David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 01/09/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU B-19 -PTD 185-230 -API 50-029-21451-00-00 Gyrodata Survey 12/01/2023 Gyro + MWD Definitive Composite Survey Main Folder Contents: Definitive Survey Sub-Folder Contents: Gyrodata Survey Sub-Folder Contents: Please include current contact information if different from above. PTD: 185-230 T38265 1/10/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.10 09:55:23 -09'00' 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:Russell Gallen - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:Initial MP B-19 BOPE test report. Date:Tuesday, January 9, 2024 4:37:22 AM Attachments:MPU B-19 BOPE test report (initial ).xlsx Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important Thank you. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW% 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 1/6/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1852300 Sundry #323-624 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2387 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2FP Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)2950 P Kill Line Valves 3 2 1/16"P Pressure After Closure (psi)1850 P Check Valve 0NA200 psi Attained (sec)15 P BOP Misc 0NAFull Pressure Attained (sec)55 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2243 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 14 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:9.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/1/24 15:14 Waived By Test Start Date/Time:1/5/2024 20:30 (date) (time)Witness Test Finish Date/Time:1/6/2024 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Hilcorp Tested w/ 2-7/8" & 4-1/2" test joints. Bottle average pre-charge = 1,030 PSI. Test # 2 F/P due to leak on TIW #1 (ball type).Change out TIW & retest. (good test) Sundry allowed testing to be conducted at 2,500 psi. After updated bottom hole pressure reading. Maximum anticipated surface pressure is now 2,725 psi (2,387 psi reported in sundry) tested at 3,000 psi. Email communication sent to & approved by Mel Rixse. C. Grueb / M. Boord Hilcorp Alaska LLC S. Heim / R. Gallen MPU B-19 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0106_BOP_Hilcorp_ASR1_MPU_B-19 VHH5HPDUNV MEU 9 9 9 9 9 9 9 MEU 9 9 -5HJJ gg 2 F/P due to leak on TIW #1 22 FP 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:Rixse, Melvin G (OGC) To:Scott Pessetto Cc:Tom Fouts; Alaska NS - ASR - Well Site Managers; DOA AOGCC Prudhoe Bay Subject:20240102 1112 APPROVAL: MPB-19 - PTD# 185-230 - Sundry# 323-624 Date:Tuesday, January 2, 2024 11:12:55 AM Scott, Approved to test BOPE to test BOPE to 3000 psi rather than 2500 psi as described in Sundry 323- 624. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Inspectors From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Tuesday, January 2, 2024 10:46 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Tom Fouts <tfouts@hilcorp.com>; Alaska NS - ASR - Well Site Managers <AlaskaNS- ASRWellSiteManagers@hilcorp.com> Subject: MPB-19 - PTD# 185-230 - Sundry# 323-624 Mel, An update for you on MPB-19. ASR is currently rigging up. We obtained an updated bottom hole pressure on MPB-19. The pressure increased from 3,085 psi to 3,412 psi, both measured at 6,982’ TVD. We now plan to test our BOPE to 3,000 psi instead of the planned 2,500 psi in the approved sundry. The maximum anticipated surface pressure is now 2,725 psi (2,387 psi reported in sundry), we will keep the same BOPE setup as approved in the sundry. Thank you, Scott Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 12/15/23 Monty M Myers 323-673 By Grace Christianson at 2:47 pm, Dec 15, 2023 108 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Alternate plug placement approved. MGR22DEC23 SFD 108 10-407 SFD SFD 12/19/2023 SFD DSR-12/18/23*&:JLC 12/27/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.12.27 09:35:01 -09'00'12/27/23 RBDMS JSB 122823 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: December 15, 2023 Re:MPU B-19 Sundry Request Sundry approval is requested to set a whipstock and mill the window in MPU B-19, as part of the pre-rig for drilling and completing of the proposed MPU B-19A CTD lateral. Proposed plan for MPU B-19A Producer: Prior to drilling activities, a RWO will be conducted to install a 4-1/2" completion. Post RWO screening will be conducted to MIT, caliper and drift for whipstock. E-line will set a 4-1/2"x7" whipstock. Service coil will mill a 3.80" window + 10' of formation (the rig will set whipstock/mill the window if needed). See MPU B-19A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set or mill pre-rig, the rig will set a 4-1/2"x7" flow through whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Kuparuk B silts. The lateral will drill back up into the Kuparuk C and cross a fault back into the B silts. The lateral will drill up into the Kuparuk C sands to TD. The proposed sidetrack will be completed with a 3- 1/2"x3-1/4"x2-7/8” L-80 solid liner and cemented. This completion WILL abandon the parent Kuparuk perfs. The well will be perforated post rig (see future perf sundry). This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start December 2023): 1. RWO: install 4-1/2” tubing (see separate RWO Sundry) 2. Slickline: Post RWO work, Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 3. Fullbore: MIT a. MIT-T to 3,000 psi 4. E-line: Set 4-1/2”x7” whipstock a. Top of whipstock at 10,125’ MD (top of window at 10,130’ MD = pinch point) b. Oriented 0° ROHS (high side) 5. Service Coil: Mill Window (mill with rig if needed) a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,800 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 7” casing 6. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: Reference MPU B-19A PTD submitted in concert with this request for full details. General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,800psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Perforate (only if not done post-rig) 6. Freeze Protect and RDMO 7. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i)approved - mgr plugging the existing Kuparuk perforations Change 3" rams to vbrs PTD Sundry 323-673 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Hole Size: The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: BOP diagram is attached. AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. 20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: The highest recorded H2S well on the pad was from MPU B-03 (43 ppm) in 2009. Reservoir Pressure: The reservoir pressure is expected to be 3,500 psi at 7,000 TVD. (9.6 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,800 psi (from estimated reservoir pressure). Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs BK-Dome 8/64" TRO 1411psi BK-Dome 10/64" TRO 1424 psi BK-Dome 10/64" TRO 1403 psi BK-Dome 10/64" TRO 1384 psi BK-Dome 10/64" TRO 1364 psi BK-Dome 10/64" TRO 1348 psi BK-Dome 10/64" TRO 1331 BK-Orifice 10/64" _____________________________________________________________________________________ Created By: JNL 12/15/2023 PROPOSED SCHEMATIC Milne Point Unit Well: MPU B-19A Last Completed: TBD PTD: TBD GENERAL WELL INFO API: 50-029-021451-01-00 Initial Completion by Nabors 27E- 10/19/1985 A Sidetrack (CDR2) Completed - TBD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 13-3/8" Conductor 48 / H-40 12.415” Surface 108’ 0.1571 9-5/8" Surface 36 / K-55 8.921” Surface 6,113’ 0.0773 7” Production 29 / L-80 6.184” Surface 10,130’ 0.0371 3-1/2” x3-1/4” x2-7/8” Liner 9.2 / L-80 / STL 6.6 / L-80 / TCII 6.5 / L-80 / STL 9,950’ 13,350’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 3.958” Surf ~10,000’ 0.0152 JEWELRY DETAIL No Depth Item 1 ~2,400’ GLM STA 5: Dummy Valve / BK Latch 2 ~4,275 GLM STA 54: Dummy Valve / BK Latch 3 ~6,120’ GLM STA 3: Dummy Valve / BK Latch 4 ~7,290’ GLM STA 2: Dummy Valve / BK Latch 5 ~8,395’ GLM STA 1: Dummy Valve / BK Latch 6 ~9,808’ 3.813” X Sliding Sleeve 7 ~9,860’ 7” x 4-1/2” Packer 8 ~9,910’ 3.813” N-Nipple 9 ~9,959’ WLEG PERFORATION DETAIL Sand Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kup WELL INCLINATION DETAIL Max Angle is 59 deg. @ 4,500’ A Sidetrack @ 10,130’ TREE & WELLHEAD Tree FMC 3-1/8” API 5000# w/ 3-1/2” 8 RD TreetopConnection Wellhead Waiting on Confirmation 4-1/2” fits OPEN HOLE / CEMENT DETAIL 17-1/2” 100 cf Permafrost Cement 12-1/4” 552 bbls Perm E, 56 Bbls Class G 8-1/2” 300 sx Class G 4-1/4” 186 sx Class G TD =13,250’(MD) /TD =7,235’(TVD) 6 Initial KB Elev.: 59.0’ / GL Elev.: 24.0’ 7” 7 8 9 3 5 Whipstock set @ 10,125’ TOW @ 10,130’ 13-3/8” 1 2 PBTD =13,220’ (MD) / PBTD =7,232’(TVD) 4 9-5/8” 3-1/4”xo 2-7/8” @10,350’ 3-1/2”xo 3-1/4” @10,100’ Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Rixse, Melvin G (OGC) To:Scott Pessetto Cc:AOGCC Records (CED sponsored) Subject:20231206 1440: PTD: 185-230 MPB-19 Sundry 323-624 Date:Wednesday, December 6, 2023 2:43:13 PM Attachments:MP B-19 PROPOSED_GLM 12-5-2023.pdf Scott, Modification to Sundry 323-624 adding GLMs to the production tubing is approved. Be sure to include this approval email in the upcoming 10-404. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. AOGCC Records From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Wednesday, December 6, 2023 1:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD: 185-230 MPB-19 Sundry 323-624 Updated schematic attached. Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, December 6, 2023 10:35 AM To: Scott Pessetto <Scott.Pessetto@hilcorp.com> Subject: [EXTERNAL] RE: PTD: 185-230 MPB-19 Sundry 323-624 Scott, Please send an updated schematic. Mel Rixse 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. Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Scott Pessetto <Scott.Pessetto@hilcorp.com> Sent: Tuesday, December 5, 2023 4:03 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD: 185-230 MPB-19 Sundry 323-624 Mel, I would like to add quantity 5 gas lift mandrels to the approved MPB-19 tubing completion in Sundry 323-624. Well MPB-19 is being setup for a coiled tubing sidetrack and there is a chance the drilling results in wanting to keep the well a producer and not convert to an injector. Planned GLM depths are 2400’, 4275’, 6120’, 7290’, 8395’ measured depth. The permitting to producer or injector will be handled with the CTD drilling PTD. Thank you, Scott Scott Pessetto | Milne Point | Operations Engineer | Hilcorp Alaska Office: 907-564-4373 | Cell: 801-822-2203 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. _____________________________________________________________________________________ Created By: STP 12/5/2023 PROPOSED Milne Point Unit Well: MPU B-19 Last Completed: 6/6/1991 PTD: 185-230 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 108’ 0.1571 9-5/8" Surface 36 / K-55 / BTRC 8.921” Surface 6,113’ 0.0773 7” Production 29 / L-80 / BTRC 6.184” Surface 10,684’ 0.0371 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958” Surface ±10,000’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±2400 GLM STA 5: Dummy Valve/ BK Latch 2 ±4275 GLM STA 4: Dummy Valve/ BK Latch 3 ±6120 GLM STA 3: Dummy Valve/ BK Latch 4 ±7290 GLM STA 2: Dummy Valve/ BK Latch 5 ±8395 GLM STA 1: Dummy Valve/ BK Latch 6 ±9,808’ 3.813” X Sliding Sleeve 7 ±9,860’ 7” x 4-1/2” Packer 8 ±9,910’ 3.813” X-Nipple 9 ±9,959’ WLEG PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kup 10,102’ 10,119’ 7,116’ 7,127’ 17’ 10/20/1985 Open 5” 10,390’ 10,409’ 7,306’ 7,319’ 19’ 5/1/1991 Squeezed 5” WELL INCLINATION DETAIL Max Angle is 59 deg. @ 4,500’ OPEN HOLE / CEMENT DETAIL 17-1/2” 100 cf Permafrost Cement 12-1/4” 552 bbls Perm E, 56 Bbls Class G 8-1/2” 300 sx Class G TD = 10,710’ (MD) / TD = 7,506’(TVD) Initial KB Elev.: 59.0’ / GL Elev.: 24.0’ 7” 3 Planned Whipstock set @ 10,125’ 13-3/8” 1 2 Kuparuk Sands PBTD = 10,240’ (MD) / PBTD = 7,207’(TVD) 4 9-5/8” Gas Lift Valve w/o Latch 5 7 6 8 9 TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC w/ 4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-021451-00-00 Initial Completion by Nabors 27E- 10/19/1985 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install 4-1/2" Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,710'±10,240' Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047433 185-230 C.O. 432E MILNE PT UNIT B-19 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21451-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 7,506' 10,240' 7,207' 2,387 KUPARUK RIVER OIL N/A TVD Burst 9,956 7,240psi MD 1,730psi 3,520psi 108108 6,113 7,4907" 13-3/8" 9-5/8" 907-564-4373 scott.pessetto@hilcorp.com 9,900(MD) / 6,982(TVD) and 567(MD) / 567(TVD) 4,545 6.5# / L-80 Scott Pessetto Wells Manager 12/24/2023 2-7/8" Perforation Depth MD (ft): See Schematic 7" OTIS MHR Perma Pkr and OTIS 10 FMX TRSV 10,240' 10,68410,684 See Schematic 108 6,113 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:59 am, Nov 17, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.11.16 14:56:19 - 09'00' Taylor Wellman (2143) 323-624 10-407 DSR-11/20/23 * MIT-IA to 2500 psi. 24 hour notice to AOGCC for opportunity to witness. *BOPE test to 2500 psi. * Variance to 20 AAC 25.412(b) approved for alternate production packer placement ~240' above existing perforations. * Slickline to set plug in TT then perform 10 minute charted pressure test to 1500 psi of tubing and GLVs to assure integrity of GLVs. MGR24NOV23 ADL0047438, ADL0047437 SFD SFD 11/26/2023 2,387 *&:JLC 11/27/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 11:37:33 -09'00' RBDMS JSB 112823 Well: MPB-19 CTD Setup PTD: 185-230 API: 50-029-21451-00-00 Well Name:MPU B-19 API Number:50-029-21451-00-00 Current Status:Long-Term SI Producer Rig:ASR 1 Estimated Start Date:December 24, 2023 Estimated Duration:7 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:185-230 First Call Engineer:Scott Pessetto 801-822-2203 Second Call Engineer:Todd Sidoti 907-632-4113 AFE Number: Current Bottom Hole Pressure:3,085 psi @ 6,982’ TVD 8.5 PPGE | SBHP 3/1/2021 Maximum Expected BHP:3,085 psi @ 6,982’ TVD 8.5 PPGE Max. Anticipated Surface Pressure:2,387 psi Gas Column Gradient (0.1 psi/ft) Min ID:2.313” @ 567’ Otis Series 10 FMX TRSV Brief Well Summary MPB-19 was originally drilled as a water injector in 1985. In 1991, MPB-19 was converted to a gas lifted producer in the MK-1 sand. As part of the recompletion MPB-19 was fractured stimulated with 31,000 pounds of carbolite proppant. The conversion to producer was unsuccessful due to sustained high water cuts as a producing well. In 2016 a step rate test was conducted to determine whether MPB-19 was capable of water injection. Injection results were not sufficient to justify conversion to injection. It is now proposed the MPB-19 wellbore be used to drill a CTD sidetrack to create an injection lateral to support offset producers. Hilcorp requests a variance to 20 AAC 25.412(b) requirement of placing the packer within 200’ measured depth of the top perforation is requested. After the CTD lateral is drilled and cemented back to the parent well, it will not be possible to have the 4-1/2” x 7” packer within 200’ MD of the perforations. Planned packer set depth is 40’ MD shallower than previous packer depth of 9,900’ RKB. An Area of Review will be submitted with the CTD sidetrack permit to drill. Objective 1.Pull 2-7/8” gas lift completion and packer. 2.Run new 4-1/2” injection string to allow for CTD sidetrack and water injection. Notes on Well Condition x MIT-IA to 2,500 psi passed on 3/2/2021 x Only bottom station will be pulled, live valves in upper mandrels x Verified FMC tubing bowl can fit a 4-1/2” tubing hanger Procedure: Slickline, Pumping & Well Support (Non-Sundried Work) 1. MIRU slickline. Pressure test PCE to 250 low / 2,500 psi high. 2. Confirm TRSV flapper is pressured up and open. Run flapper checker. 3. Drift and tag as deep as possible to confirm whipstock setting depth is not covered. a. Previous reports indicate that knuckle joints should be ran if going deeper than 9,690’. 4. RIH to 9,900’ MD / 6,982’ TVD, obtain 30 minute pressure reading. 5. PUH to 9,780’ MD / 6,882 TVD for 10 minute station stop. 6. PUH to 9,596’ MD / 6,782’ TVD for 10 minute station stop. 7. RIH pull BK-Orifice from GLM at 8,698’ MD. 8. RDMO slickline. Pump and Well Support (Non- Sundried Work) 9. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 10. RD well house and flowlines. * Before pulling tubing, set TT plug and perform 10 minute tubing test to 1500 psi to assure integrity of GLVs. *May need to reset BK-Orifice if performed after full wellbore circulation. -mgr Well: MPB-19 CTD Setup PTD: 185-230 API: 50-029-21451-00-00 11. MIRU pumpers and PT lines to 250 psi low / 3,500 psi high. 12. Circulate at least one wellbore volume down tubing taking returns up casing to tank. a. Do not reverse to kill as the well has live GLVs installed. b. Plan to pump kill two days in advance of ASR in the event GLVs need to be pulled and dummied. 13. Confirm well is dead and FP if necessary. 14. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 15. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If required, kill well w/ 8.7 ppg brine prior to setting CTS plug. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure off casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well w/ 8.7 ppg brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. MU landing joint or spear and PU on the tubing hanger. a. Pickup and slack off weights were not recorded during the 1991 workover. b. Tubing was noted to be set with 15,000 pounds of compression. c. Tubing should pull out of the SBR. d. Expected string weight ~70,000 pounds. 6. Confirm hanger free, lay down tubing hanger. a. If tubing does not pull out of SBR, rotate ~20 turns to release from packer. b. If unable to release tubing, E-line cut in first full joint above PBR. ~9,860’ RKB. 7. POOH and lay down the 2-7/8” tubing. a. Discard all tubing and jewelry. b. Call out spooler for ~500’ of TRSV control line. c. 19 stainless steel bands run for TRSV 8. Pick up packer milling BHA and 3-1/2” workstring. a. If the PBR was not recovered, add enough wash pipe to swallow stub. 9. Trip in hole to Otis MHR Perma-Drill packer at 9,900’ MD. 10. Establish PU, SO, and rotating parameters. 11. Engage and mill packer slips per fishing tools company. a. Packer is a single trip mill and retrieve packer. b. Distance from top of packer to: i. Top of rubber element 2.1’ ii. Center of rubber elements 2.65’ iii. Bottom of lower slips 3.58’ 12. Once packer is free, close the annular element and perform a bottoms up to confirm any packer gas is removed from the well. 13. POOH with packer and tailpipe. 14. Observe for solids, corrosion, or schmoo on outside of pulled to tubing to dictate whether a 7” scraper run is needed across the packer setting interval in the 7” casing. 15. Pick up new 4-1/2” injection completion and RIH to ~10,000’ MD. Assure balance fluids T x IA. -mgr Well: MPB-19 CTD Setup PTD: 185-230 API: 50-029-21451-00-00 Nom. (OD)Length Item Lb/ft Material Notes 4-1/2"41 Mule Shoe Jt 12.6 L-80 Bottom @ ~10,000' 4-1/2"41 4-1/2" jt 12.6 L-80 4-1/2"10 4-1/2" Pup 12.6 L-80 5.03"2 3.813" X Nipple - RHC Installed L-80 ~9,910’ 4-1/2"10 4-1/2" Pup 12.6 L-80 4-1/2"41 4-1/2" jt L-80 4-1/2"10 4-1/2" Pup 12.6 L-80 6"10 7" x 4-1/2" Packer L-80 ~9,860 4-1/2"10 4-1/2" Pup 12.6 L-80 4-1/2"41 4-1/2" jts 12.6 L-80 4-1/2"10 4-1/2" Pup Jt 12.6 L-80 5.6"2 4-1/2" Sliding Sleeve, 3.813" X, open down L-80 4-1/2"10 4-1/2" Pup Jt 12.6 L-80 4-1/2"9800 4-1/2" jts 12.6 L-80 4-1/2"10 Space out pup 12.6 L-80 30 4-1/2” Tubing hanger L-80 16. Space out and land hanger. 17. RILDS. Lay down landing joint. 18. Pump 124 barrels of 1% KCL with 1% by volume corrosion inhibitor (CI) down the IA, taking returns up the tubing. a. This is to inhibit the entire inner annulus. 19. Displace CI with 52 barrels of diesel freeze protect down the annulus. 20. Consult OE/WSL on whether to FP tubing prior to RDMO. 21. Drop ball and rod and pump to seat in X-nipple below the packer. Set the packer per vendor setting procedure. 22. Pressure test the tubing to 3,000 psi, charted for 30 minutes. 23. Pressure test the IA to 2,500 psi, charted for 30 minutes. a. 0.25 psi/ft x 7,490’ TVD = 1,873 psi 24. Set CTS. 25. RDMO ASR. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU tree and tubing head adapter. 4. Test both tree and tubing hanger void to 500psi low/5,000psi high. 5. Pull CTS. 6. RD crane. Move 500 bbl returns tank and rig mats to next well location. 7. Replace gauge(s) if removed. 8. Turn well over to wells group for CTD prep. * MIT-IA to be witnessed by AOGCC. 24 hour notice. Well: MPB-19 CTD Setup PTD: 185-230 API: 50-029-21451-00-00 Slickline 1. Spot Slickline unit and RU. 2. Pressure test PCE to 250 psi low and 2,500 psi high. 3. Pull ball and rod. 4. Pull RHC profile. 5. Run 4.5” x 7” whipstock drift to 10,150’ RKB. E-Line 1. MIRU Electric line 2. Pressure test PCE to 250 psi low, 2,500 psi high 3. RIH with 4.5” x 7” whipstock 4. Set whipstock with TOWS at 10,125’ RKB a. Confirm WS set depth with OE Scott Pessetto – (801) 822-2203 5. RDMO Attachments: 1. Well Schematic Current 2. Well schematic Proposed 3. BOP Drawing BK-Dome 8/64" TRO 1411psi BK-Dome 10/64" TRO 1424 psi BK-Dome 10/64" TRO 1403 psi BK-Dome 10/64" TRO 1384 psi BK-Dome 10/64" TRO 1364 psi BK-Dome 10/64" TRO 1348 psi BK-Dome 10/64" TRO 1331 BK-Orifice 10/64" _____________________________________________________________________________________ Created By: TDF 11/16/2023 PROPOSED Milne Point Unit Well: MPU B-19 Last Completed: 6/6/1991 PTD: 185-230 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / PELP 12.715” Surface 108’ 0.1571 9-5/8" Surface 36 / K-55 / BTRC 8.921” Surface 6,113’ 0.0773 7” Production 29 / L-80 / BTRC 6.184” Surface 10,684’ 0.0371 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958” Surface ±10,000’ 0.0152 JEWELRY DETAIL No Depth Item 1 ±9,808’ 3.813” X Sliding Sleeve 2 ±9,860’ 7” x 4-1/2” Packer 3 ±9,910’ 3.813” X-Nipple 4 ±9,959’ WLEG PERFORATION DETAIL Sand Top (MD)Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kup 10,102’ 10,119’ 7,116’ 7,127’ 17’ 10/20/1985 Open 5” 10,390’ 10,409’ 7,306’ 7,319’ 19’ 5/1/1991 Squeezed 5” WELL INCLINATION DETAIL Max Angle is 59 deg. @ 4,500’ OPEN HOLE / CEMENT DETAIL 17-1/2” 100 cf Permafrost Cement 12-1/4” 552 bbls Perm E, 56 Bbls Class G 8-1/2” 300 sx Class G TD =10,710’(MD) / TD =7,506’(TVD) Initial KB Elev.: 59.0’ / GL Elev.: 24.0’ 7” 3 Planned Whipstock set @ 10,125’ 13-3/8” 1 2 Kuparuk Sands PBTD =10,240’ (MD) / PBTD =7,207’(TVD) 4 9-5/8” Gas Lift Valve w/o Latch TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC w/ 4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-021451-00-00 Initial Completion by Nabors 27E- 10/19/1985 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs STATE OF ALASKA ALIRA OIL AND GAS CONSERVATION COMNISION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Plug Perforations H Fracture Stimulate H Pull Tubing Lf Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Slick Water Step Rate❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development E Exploratory ❑ 185-230 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21451-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047433 MILNE PT UNIT KR B-19 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL JAN 13 ?nil 11.Present Well Condition Summary: Q �`�+/�► Total Depth measured . 0GCC p 10,710 feet Plugs measured 9,950 feet true vertical 7,506 feet Junk measured ±10,240' feet Effective Depth measured 10,240 feet Packer measured 9,900 feet true vertical 7,207 feet true vertical 6,982 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 13-3/8" 108' 108' 1,730psi 740psi Surface 6,113' 9-5/8" 6,113' 4,545' 3,520psi 2,020psi Production 10,684' 7" 10,684' 7,490' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic SCO O�E0 A `/i I!! True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 9,956' 7,019' Packers and SSSV(type,measured and true vertical depth) OTIS MHR Perma Pkr OTIS 10 FMX TRSV See Above 567 MD/567 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: o 0 0 940 0 Subsequent to operation: o 0 0 940 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I Exploratory❑ Development❑, Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/".44-e. .Exemot Contact Ted Kramer Emailtkramerhilcorp.com Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 1/10/2017 3z - /7' 5 Form 10-404 Revised 5/2015 RDDIVIS (/jjj 2 2017 Submit Original Only • • 11 WELL No. B-19 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50-029-21451 IIiI,,.rp.%luwka.IAA: PERMIT No.: 85-230 COMPLETED: 10/19/85 LAST WORKOVER: 6/6/91 t 1 FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE NOTES: 2 7/8", 6.5# L-80 EUE TUBING (2.441" ID) 1. ALL MEASUREMENTS ARE FROM KDB OF I.D., 2.867" DRIFT) NABORS RIG NO. 27E KDB - SL = 59' KDB - GL = 35' (sssv 567' O11S SERIES 10 FMX TRSV (2.313" ID) 2. MAX. ANGLE = 59.25' ® 4500' 3. K.O.P. = 500' All GLM are Dummied Off 1842' GLM 4. SLANT HOLE: YES MO 2776' GLM 5. MIN. ANGLE = 48.5' AT 10,000' 4111 3678' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# WITH = 4644' GLM (LOCATED 49 '' WLM 6/21/93)J 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION: OTIS SERIES 10 ! 5542' GLM CAMCO 2 7/8" KBMG FMX TRSV (2.313) 0 567' 6348' GLM 8. COMPLETION FLUID: 10.2 PPG NaCI-Naar BRINE 7121' GLM 8. FRAC 6/91 - 31,000# 16/20 ISP 7895' GLM MK-1 • 8698' GLM 9797' WLM FOUND 1.75" RESTRICTION WITH 060 SLICKLINE ON 2-26-93 9884' OTIS PBR, SEAL ASSEMBLY (2.313" ID) 9900' OTIS MHR PERMA DRILL PACKER (3.875" ID) �� 9906' OTIS MILLOUT EXT. (4.35" ID) \22./...„... 9913' XO 4 1/2" EUE x 3 1/2" EUE (2.441 ID) xo �_ 9914' XO 3 1/2" EUE x 2 7/8" EUE (2.441 ID) 2 7/8" TUBING PERFORATIONS: ♦i- - 9950' "X" NIPPLE (2.313" I.D.) W/Plug Body set 7/20/16 12 SPF AT 120' PHASING 9951' 2 7/8" PUP LK-1 - SQUEEZED 5/91 ( ° �---9956' TUBING TAIL 10,409.-10,390' MD 7322'-7306' TVD J"/- --.'-'k MK-1 GAS LIFT VALVE W/O LATCH 10,119'-10,102' MD 7130'-7116' TVD Er=r777 (BASED ON OIL LOG OF 10-16-85) 10,240' EST TOC 10,102'-10,118' MD 7116'-7129' TVD n • n 10,599' PBTD (WIRELINE MEAS.) 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ID D IN Cf) in a) — @ 0 CD 71 E NI lri cc e -4 -1.. ta -2 7- To E 0 i . 0 4 i..1 a) -- . -I--P < U ')" N' c5 L.,„ o ..._ 2 a) a) Q. 0 - o .-.', s.2. u) cd .-1 (.i o 13 (0 u) c a) 1-4 ef — co 2 0 a 0 nt- E i- ( —I -,-5 D (0 V) 4 • 2 a cf, Cie) , c 0 CD 23 "Fr. a Jo 1 ,-.. c=, t. 0 1-... ...'. 2 a_ 0 u..., ... Lo r-.: 01 QD L a) ti • C r.s1 Cc) CD a) o al e•i D) E c , a) st ...., 1 (0 - U .....: a) ,--, CI * . . . . ; . . . . , § § § § 0-. . c.; o rn o 8 111 tl) 0 0 iNi 1 I ial rn ,-1 (isd)ainssaid UI F- 1 ID • V'OF 7,4 g -I'l y/�.,. THE STATE Alaska Oil and Gas Fes,;,-��� of Conservation Commission _ :-_= __- ALASIc:A ft itt _5 333 West Seventh Avenue " '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '' -------r,1--"°— Main: 907.279.1433 OF ALA�P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC sfc:'•NHg MP 6, I 201 , 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR B-19 Permit to Drill Number: 185-230 Sundry Number: 316-535 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster /-'<...---- Chair DATED this 2Iy of October, 2016. RBDMS V/ Ow t 8 2016 • • RECEIVED • STATE OF ALASKA OCT 1 7 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ADCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. Slick Water Step Rate Or 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 0, 185-230 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-21451-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D ' Will planned perforations require a spacing exception? Yes ❑ No Q / MILNE PT UNIT KR B-19 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047433 MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Dept)TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,710' . 7,506' • 10,101' + 7,115' • 4,000 10,240' ±10,240' Casing Length Size MD TVD Burst Collapse Conductor 108' 13-3/8" 108' 108' 1,730psi 740psi Surface 6,113' 9-5/8" 6,113' 4,545' 3,520psi 2,020psi Production 10,684' 7" 10,684' 7,490' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic f See Attached Schematic 2-7/8" 6.5#/L-80/EUE 9,956 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): OTIS MHR Perma Pkr and OTIS 10 FMX TRSV 1 9,900(MD)/6,982(TVD)and 567(MD)/567(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0, Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: i'Q/3i/ice OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ 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. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Bo York Title Operations Manager Signature' Phone 777-8345 Date 1-014/2U16 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness (Sundry Number. 2 `L 6.- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: �; f' !' A x (!d/1.t rs.i- r:..c.,.�..„,c'_. 2i S /S-0 /38C— t�1-4. '....--C - Post Initial Injection MIT Req'd? Yes ❑ No ❑u/ ! / C, O(1 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /v ,`l 61`7 RBDMS / OCT 1 B 2016 .5 . 2SItt. I/ APPROVED BY Approved by:il /3 �aleP COMMISSIONER THE COMMISSION Date: 10 _ �// it P/AfliCA ORIGINAL 00 tij r0/ZO//6 t--- Ory Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate . • Well Prognosis Well: MPB-19 IIilcorp Alaska,LD Date: 10/14/2016 Well Name: MPU B-19 API Number: 50-029-21451-00 Current Status: SI Producer Pad: B Pad Estimated Start Date: October 31, 2016 Rig: NA Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-230 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228 (M) AFE Number: Current Bottom Hole Pressure: 3,276 psi @ 7,059' TVD (From 7/29/2013 SBHP Survey) Maximum Expected BHP: 5,918 psi @ 7,059' TVD (Max BHP with 2,800 psi inj. pressure. No iP perforating or cleanout planned) Ing(S) Max.Allowable Surface Pressure: 4,000 psi Set limit on the cement pump truck e. 4 Psi Brief Well Summary: The Milne Point B-19 Was originally drilled and completed as a water injector in 1985. In June of 1991, B-19 was converted to a gas lifted producer in the MK-1 sand (10,102 — 10,119'). As part of the re-completion, the well was sand frac'd with 31,000 # of Carbo lite at 7,700 psi treating pressures ISIP of 2,000 psi. Once on production the well produced with a high water cut. B-19 was SI in July of 1991 and has been SI since. In August of this year, a Sundry was submitted and approved to perform an injectivity test to see if this well would take water under our current water injection header pressure. The test revealed that we could inject approx. 125 BWPD at the header pressure of 2,100 psi. 31 L_ 211 Objective: The purpose of this work is to perform a slick water step rate test on this well to see what would be necessary to improve the injectivity of this well. The B-19 is well situated on structure to provide water support two new wells to be drilled in 2017. / Since we will be injecting fluid into the formation,this sundry is being submitted. Procedure: 1. RU Slick line. RIH with GR and tag fill. Record depth. POOH W/GR. 2. PU Gauge, RIH and perform SIBHP. 3. RU cement truck to well head and to tank with hard piping . 4. Pressure test lines to 5,000 psi. 5. Pump step rate test according to the following schedule (Note—Record rate and pressure during each step) : • • Well Prognosis Well: MPB-19 Hilcorp Alaska,LL' Date: 10/14/2016 Step Duration Volume Cum.Vol. HHP at 4,000psi (bpm) (min) (bbl) (bbl) 0.25 4 1 1 24.5 0.5 4 2 3 49.0 0.75 4 3 6 73.5 1 4 4 10 98.0 1.5 4 6 16 147.1 2 4 8 24 196.1 3 4 12 36 294.1 4 4 16 52 392.2 5 4 20 72 490.2 6 4 24 96 588.2 8 4 32 18' 784.3 6. Shut in well. Record falloff pressure for 15 min. 7. RDMO Pump truck. Attachments: 1. As-built Schematic 2. Blank Procedure Change Form . • • • WELL No. B-19 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50-029-21451 f[irr+rr Alu*Lat,LLE PERMIT No.: 85-230 COMPLETED: 10/19/85 LAST WORKOVER: 6/6/91 I INC TUBING HANGER w/ 3 1/2" 'H' BPV PROFILE NOTES: 2 7/8", 6.5# L-80 EUE TUBING (2.441" ID) 1. ALL MEASUREMENTS ARE FROM KDB OF I.D., 2.867" DRIFT) NABORS RIG NO. 27E KDB — SI = 59' KDB — GL = 35' (sssv) 567' OTIS SERIES 10 FMX TRSV (2.3i3" ID) 2. MAX. ANGLE = 59.25' 0 4500' 3. K.O.P. = 500' 1842' GIN All GLM are Dummied Off 4. SLANT HOLE: YES 2776' GLM 5. MIN. ANGLE = 48.5' AT 10,000' 3678' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# WITH 3 1/2" 8 RD. TREETOP CONNECTION. i 4644' GLM (LOCATED 49 WLM 6/21/93) 7. MIN. RESTRICTION: OTIS SERIES 10 5542' GIN CAMCO 2 7/8" KBMG FMX TRSV (2.313) 0 567' = 6348' GLM 8. COMPLETION FLUID: 10.2 PPG NaCI—NoBr BRINE 111P 7121' GLM 8. FRAC 6/91 — 31,000/ 16/20 ISP 410 7895' GIN MK-1 • 8698' GLM = 9797' KM FOUND 1.75" RESTRICTION WITH [0:s. SLICKLINE ON 2-26-93 9884' OTIS PBR, SEAL ASSEMBLY (2.313" ID) 9900' OTIS MHR PERMA DRILL PACKER (3.875" ID) 9906' OTIS MILLOUT EXT. (4.35" ID) 9913' XO 4 1/2" EUE x 3 1/2" EUE (2.441 ID) IELIV 9914' XO 3 1/2" EUE x 2 7/8" EUE (2.441 ID) 2 7/8" TUBING PERFORATIONS: R 9950' "X" NIPPLE (2.313" I.D.) W/Plug Body set 7/20/16 12 SPF AT 120' PHASING 9951' 2 7/8" PUP LK-1 — SQUEEZED 5/91 G 9956' TUBING TAIL 10.409'-10,390' MD 7322'-7306' TVD r, . MK-1 GAS LIFT VALVE W/O LATCH 10,119'-10,102' MD 7130'-7116' TVD (BASED ON DIL LOG OF 10-16-85) 10,240' EST TOC 10,102'-10,118' MD 7116'-7129' TVD n 7C 10,599' PBTD (WIRELINE MEAS.) REPERF 6/91 5 SPF 60' PHASE 10,685'--7", 26 LB/FT L-80 BTRS (6.184" ID, 6.059" DRIFT) APPROVED BY: JHA/HDS DATE: 6-29-93 DRAFTED BY: SJN CAD FILE: WCOB19 0 • � � R a) 5Wc & aQ 2 _ 7 /oSoo / 2 2 2 § m « E £ . . 0 oc 10co a) % Yt2 7 §f k� \ / < � ,_ .— = o / 2 a0 A/ I2� ei e cr 0 % 2 a) a) 2 \ R R $ % CCD o 0 - @ 2 4. 4 — a) k2 0 $ 7 / a) 22 2 kk k k a co L§ Q a _ \ -c) 0 ms co C < 0 CD E = d ® 2 -a 1 § 2 / a 4 . II . 0 103 c ( cc -0 . w > 2. / . kms $ ) 2 co L. . 0 CD o. 2 ._ u) o0 § = ril _M ■ 2 R co < � a / co cc $0. \ § � w � � / � a g fQ om % m § � E % a 2 / V kk k \ 9 . . . . ¢ . . . . . . STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Injectivity Test ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: A 11--/A Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 185-230 n t 1`-r- 3. 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21451-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047433 MILNE PT UNIT KR B-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: RECEIVED Total Depth measured 10,710 feet Plugs measured 9,950 feet SEP 15 2016 true vertical 7,506 feet Junk measured ±10,240' feet Effective Depth measured 10,240 feet Packer measured 9,900 feet AO G CC true vertical 7,207 feet true vertical 6,982 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 13-3/8" 108' 108' 1,73Qp§j,_ 740psi Surface 6,113' 9-5/8" 6,113' 4,545' 3,520psi 2,020psi Production 10,684' 7" 10,684' 7,490' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic �y �^ True Vertical depth See Attached Schematic SCANNED FEE. 2 2 2L!f/ Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 9,956' 7,019' Packers and SSSV(type,measured and true vertical depth) OTIS MHR Perma Pkr OTIS 10 FMX TRSV See Above 567 MD/567 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 940 0 Subsequent to operation: 0 0 0 940 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: y� 316-377 Contact Ted Kramer �/ !/ Email tkramerr7a,hilcorp.com Printed Name Bo York Title Operations Engineer Signature ., _ Phone- , ,,, , 777-8345 .- Date 9/15/2016 / b -- 7- 4, .74 • 4 / 0A«% Form 10-404 Revised 5/2015 RBDMS 0/SEP 1 6 2n46bmit Original Only • • WELL No. B-19 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50-029-21451 IhkuruAla-L.1,1,1.! PERMIT No.: 85-230 COMPLETED: 10/19/85 LAST WORKOVER: 6/6/91 t 1 FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE NOTES: 2 7/8", 6.5# L-80 EUE TUBING (2.441" ID) 1. ALL MEASUREMENTS ARE FROM KDB OF I.D., 2.867" DRIFT) NABORS RIG NO. 27E KDB — SL = 59' KDB — GL = 35' (sssv} 567' OTIS SERIES 10 FMX TRSV (2.313" ID) 2. MAX. ANGLE = 59.25' 0 4500' 3. K.O.P. = 500' 1842' GLM 4. SLANT HOLE: YES 2776' GLM 5. MIN. ANGLE = 48.5' AT 10.000' 3678' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# WITH 4644' GLM (LOCATED 49 WLM 6/21/93) 3 1/2" 8 RD. TREETOP CONNECTION. / 7. MIN. RESTRICTION: OTIS SERIES 10 5542' GLM CAMCO 2 7/8" KBMG FMX TRSV (2.313) 0 567' 6348' GLM 8. COMPLETION FLUID: 10.2 PPG NoCI—NaBr BRINE 7121' GLM 8. FRAC 6/91 — 31,000# 16/20 ISP 7895' GLM MK-1 8698' GLM 9797' WLM FOUND 1.75" RESTRICTION WITH 0 0 0 SLICKLINE ON 2-26-93 9884' OTIS PBR, SEAL ASSEMBLY (2.313" ID) 9900' OTIS MHR PERMA DRILL PACKER (3.875" ID) yam9906' OTIS MILLOUT EXT. (4.35" ID) 9913' XO 4 1/2" EUE x 3 1/2" EUE (2.441 ID) xo 9914' XO 3 1/2" EUE x 2 7/8" EUE (2.441 ID) Co �� 2 7/8" TUBING PERFORATIONS: 9950' "X" NIPPLE (2.313" I.D.)1W/Plug Body set 7/20/16 12 SPF AT 120' PHASING — 9951' 2 7/8" PUP LK-1 — SQUEEZED 5/91 ° '— 9956' TUBING TAIL 10,409'-10,390' MD 7322'-7306' TVD MK-1 GAS LIFT VALVE W/O LATCH 10.119'-10.102' MD 7130.—7116. TVD (BASED ON DIL LOG OF 10-16-85) til � 10,240' EST TOC 10,102'-10,118' MD 7116'-7129' TVD Tr c 10,599' PBTD (WIRELINE MEAS.) REPERF 6/91 5 SPF 60' PHASE 10,685'--7", 26 LB/FT L-80 BTRS (6.184" ID, 6.059" DRIFT) (Conoco, CONOCO INC. APPROVED BY: JHA/HDS DATE: 6-29-93 ANCHORAGE DIVISION DRAFTED BY: SJN CAD FILE: WCOB19 �� �� Hilcorp A|~~ ^~, - Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-19 SL& Pump 50-029'21451'00'00 185'230 7/20/16 8/5/16 Daily ''� "' ~.. ^��m~ 7/20/2016 Wednesday DRIFT WITH KJT, 2'7/8" BRUSH & 2.30" G-RING OUT TTATy956' MD (brush x-nip at 9950' MD and tight spot at~9700' SLM). RIH W/ KNUCKLE ABOVE SPANGS AND ONE ABOVE X LINE &SET PX-PLUG BODY AT 9,950' MD (recovered all pins & nubbins) NO ISSUES GOING THRU PROBLEM AREA. 7/21/I016 Thursday WELL S/I ON ARRIVAL, NOTIFY PAD'0y, PT PCE 250L/2,500H. SET P-PRONG/BAIT SUB (catcher)AT 9,918' SLM (plug body @ 9,950' MD on 7/20/16). SET BK-DGLV's IN STA's# 1,2,3,4,5,6,7,8 & 9 7/22/2016 Friday ~~..1/1/O=252/873/416 MITT PASSED to 3,000psi/M|T IA was Inconclusive to 3,808psi (Integrity). Pump 5.7 bbls criesel down tbg to 3,000psi TP lost 198 psi 1st 15 min & 72 psi 2nd 15 min PASSED. Multiple Multiple_attempts to MIT IA to 3,000psi.Appeared to have some stabilization but couldn't get it to fit the PASSING MIT Criteria. Left with 3,500 psi on IA& Crystal guage to monitor lAP overnight. 7/23/2016 Saturday No activity to report. 7/24/2016 Sunday No activity to report. 7/25/2016 Monday No activity to report. 7/26/2016 Tuesday No activity to report. _~~- x - � /4hi)/ nv'' ._~_-~_---.-~~~~- • I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP B-19 SL& Pump 50-029-21451-00-00 185-230 7/20/16 8/5/16 Daily Operations: 8/3/2016-Wednesday No activity to report. 8/4/2016-Thursday No activity to report. 8/5/2016- Friday _Freeze protect Tubing post injection test- Rigged up to hardline and pumped 20 bbls 60/40 meth down Tubing. 8/6/2016-Saturday No activity to report. 8/7/2016-Sunday No activity to report. 8/8/2016- Monday No activity to report. 8/9/2016-Tuesday No activity to report. . w 0 ' Time/Date Injection Rate Tubing Pressure I/A Pressure 0/A Pressure, ,;,:011:::‘• 4.7 1 2-1c>6 13P1) .5610 g`6 0 Ale() /he.) RP') 9 ) TS i3P0 a4 S'15. _ //00 tt IXe2 ; on eptp! /5'," 124 21.2'.0 1 i i•-0 ..5.0e; ; )35 2.4 '''t1 17096 SAC) _ /..3o 2 ‘_2•6) i •700 Xax) ' 6 VO /j/ Zge9C4 ) V5-$1 72.C11 26 A/3 t X'kC,)' 5?::;"2"c? — ' .0 /:0 7 ,-, t56 Z-7 2._(-..) 115 i S 2Aoao 1 02-`.36 I W : • 2..2 O I2-0 2.6/30 (?- JO Wo i) — 12..co 7A-•••:o ' ?"-/-_--,,,,- 7------- s5 z‹....:-, ,,_ E I ,,,,,,1 / 25 2 7,t)t:2 700 --7Z,7:5 . ,. 010:45. I25 21[1 got? et.S° IT(S as 2,.1 00 lom 0 - bitty.] 4 501 1 04110 I2_b 1 Opi0 12,71 .s: 27 I s• s 27tg .6) 00 100 36o -Med fp b P 6 -6,1tled) to S-60 121 ' 'A 2700 110 0 , bn 0 QV,55 12-9 2-711 i 000 1)2_0 Rb taq 7 -1,t1' POD tztp -121-e&a tp 5-00 L25 2,72? 0)10 11D° 12S 2.111- 10q0 ' 1 II:.00 IAA) 7 li 1 Iti)s)biteolit clot) toi 0 -13R-tot lb 500 e. U.0.0 #i _ 12_5 :47,1 t S -- cr41 600 'art icii I 2:5U "11 tk) t•ON 1;2) °I 0 3O 'I 2.19 SD 071 310 , 3*.3 1-2_2_ 2_lAq zyl-0 • 1 4 St 1 I ct a co 4 4 tb / 5:00 i g a, 26 613 ct cto Lj,00 5:30 1101 201 Ito° i2.0 I a ‘ 43 1, 600 ql() M.:0 ' 2-72i, /oe'),,- 1-) 7-43 ii -) 272-? 7,,es, 0 41 7-1) .11 (/ 10 ',00 'f i , " 2,-) -2__,,S I e.> lio fi: .--- T-,5"-i 4 • • .0e •! 00 ) i 3 2.7 a 7 )0 el 0 11 6)0 Z 6' 2) 2 ''''. /I-9 ti 0 0 22. c.D . " f ‘c>c,, 773 .0100 :_... 61? S Z 0 ___ I ®F 711 • c ,\ )%%i c THE STATE Alaska Oil and Gas of Li A sKA Conservation Commission Witt 333 West Seventh Avenue GOVERNOR BILL WALKER —Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®FALASY`P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SEWEQ fl�1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR B-19 Permit to Drill Number: 185-230 Sundry Number: 316-377 Dear Mr. York: 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, Daniel T. Seamount, Jr. Commissioner DATED this C7 day of July, 2016. RBDMS (,\/ JUL 2 9 2016 RECEIVED STATE OF ALASKA JUL 21 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: Injectivity Test 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC ' Exploratory ❑ Development D. 185-230 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-21451-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT KR B-19 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047433 - MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,710' 7,506' - 10,101' - - 7,115' 2,800 10,240' ±10,240' Casing Length Size MD TVD Burst Collapse Conductor 108' 13-3/8" 108' 108' 1,730psi 740psi Surface 6,113' 9-5/8" 6,113' 4,545' 3,520psi 2,020psi Production 10,684' 7" 10,684' 7,490' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 9,956 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): OTIS MHR Perma Pkr and OTIS 10 FMX TRSV . 9,900(MD)/6,982(TVD)and 567(MD)/567(TVD) 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development D. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 7/25/2016 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approvedr�fire- herein will not be deviated from without prior written approval. Contact Ted Kramer r Email tkramer@hilcorD.com Printed Name York Title Operations Manager Signature2ux/ Phone 777-8345 Date 7/21/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ?_\Le_ _ 3 77 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS LL- JUL 2 9 2016 Post Initial Injection MIT Req'd? Yes ❑ No ❑ 1) 1 Zv�t Spacing Exception Required? Yes ❑ No lid Subsequent Form Required: 10,- y 0&. APPROVED BY 7 /2,t //Approved by: (2(° COMMISSIONER THE COMMISSION Date: !/ ►*a 7lIi� Zlzt-�� e -r) 1zeit, - 7-z7—/4 OpRtGINASubmit Form and Form 10-403 Revised 1112015 Ld for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPB-19 FIilcoru Alaska,LI) Date:7/21/2016 Well Name: MPU B-19 API Number: 50-029-21451-00 Current Status: SI Producer Pad: B Pad Estimated Start Date: July 25, 2016 Rig: NA Reg.Approval Req'd? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-230 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 3,276 psi @ 7,059'TVD (From 7/29/2013 SBHP Survey) Maximum Expected BHP: 5,918 psi @ 7,059' TVD (Max BHP with 2,800 psi inj. pressure. No perforating or cleanout planned) Max.Allowable Surface Pressure: 2,800 psi (Max. Injection Pressure of injection header) Brief Well Summary: The Milne Point B-19 Was originally drilled and completed as a water injector in 1985. In June of 1991, B-19 was converted to a gas lifted producer in the MK-1 sand (10,102 — 10,119'). As part of the re-completion, the well was sand frac'd with 31,000 # of Carbo lite at 7,700 psi treating pressures ISIP of 2,000 psi. Once on production the well produced with a high water cut. B-19 was SI in July of 1991 and has been SI since. Objective: The purpose of this work is to dummy off all of the gas lift valves in this well and conduct a tubing pressure test and an MIT to see if this well is suitable as an injector. / Hilcorp would then like to conduct a three day injectivity test to determine if this well would be suitable as a water injector to support two new drill wells in the 2017 drilling plan. Data from this test will be used to determine how much additional work needs to be performed on B-19 in order to use it to provide injection support for the new drills. At the conclusion of the test,the well will be shut In. If the well will take sufficient water,then anew ,Sundry Application will be submitted to convert the B-19 to water injection. Procedure: 1. RU Slick Line and pull all GLV's replacing them with dummy valves. 2. RIH with a plug and set in the X nipple @ 9950'. Pressure test tubing to 3,000 psi on chart for 30 min. Release pressure and pull plug. 3. RU pump truck on back side. Conduct an MIT IA to 1800 psi.on chart for 30 min. , 4. Conduct Injectivity test. • • • llWell Prognosis Well: MPB-19 Hilcarp Alaska,LI. Date:7/21/2016 5. RU Little Red Services.Shut in and freeze protect well. Attachments: 1. As-built Schematic 2. Blank Procedure Change Form i • WELL No. B-19 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50-029-21451 Hli*'owp AltoLa.WE PERMIT No.: 85-230 COMPLETED: 10/19/85 LAST WORKOVER: 6/6/91 I 1 FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE NOTES: 2 7/8", 6.5# L-80 EUE TUBING (2.441" ID) 1. ALL MEASUREMENTS ARE FROM KDB OF I.D., 2.867" DRIFT) NABORS RIG NO. 27E KDB - SI = 59' KDB - GL = 35' (sssv) 567' OTIS SERIES 10 FMX TRSV (2.313" ID) 2. MAX. ANGLE = 59.25' 0 4500' 3. K.O.P. = 500' CO 1842' GLM 4. SLANT HOLE: YES ! 2776' GLM al 5. MIN. ANGLE = 48.5' AT 10,000' 3678' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# WITHal 4644' GLM (LOCATED 49 '' WLM 6/21/93) 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION: OTIS SERIES 10 GI 5542' GLM CAMCO 2 7/8" KBMG FMX TRSV (2.313) 0 567' 6348' GLM 8. COMPLETION FLUID: 10.2 PPG NoCI-NaBr BRINE ! 7121' GLM 8. FRAC 6/91 - 31.000# 16/20 ISP i 7895' GLM MK-1 i 8698' GLM 9797' WLM FOUND 1.75" RESTRICTION WITH 1:::1 SLICKLINE ON 2-26-93 9884' OTIS PBR, SEAL ASSEMBLY (2.313" ID) 9900' OTIS MHR PERMA DRILL PACKER (3.875" ID) 9906' OTIS MILLOUT EXT. (4.35" ID) 9913' XO 4 1/2" EUE x 3 1/2" EUE (2.441 ID) WEI X0i"' 9914' XO 3 1/2" EUE x 2 7/8" EUE (2.441 ID) • - 2 7/8" TUBING PERFORATIONS: B• 9950' "X" NIPPLE (2.313" I.D.) 12 SPF AT 120' PHASING 9951' 2 7/8" PUP LK-1 - SQUEEZED 5/91 9956' TUBING TAIL 10,409'-10,390' MD 7322'-7306' TVD -J_,,Th MK-1 GAS LIFT VALVE W/0 LATCH 10.119'-10.102' MD 7130'-7116' TVD (BASED ON DIL LOG OF 10-16-85) 10,240' EST TOC 10,102'-10,118' MD 7116'-7129' TVD 1C, . TC 10,599' PBTD (WIRELINE MEAS.) REPERF 6/91 5 SPF 60' PHASE 10,685'--7", 26 LB/FT L-80 BTRS (6.184" ID, 6.059" 's II.. DRIFT) (Conoco) CONOCO INC. APPROVED BY: JHA/HDS DATE: 6-29-93 ANCHORAGE DIVISION DRAFTED BY: SJN CAD FILE: WCOB19 410 • •Wallace, Chris D (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, July 27, 2016 3:38 PM To: Wallace, Chris D (DOA) Subject: RE: Milne Point Unit KR B-19 (PTD 1852300) Sundry 316-377 Attachments: B-19_Water_Production_Analysis.pdf Chris, The short answer is that we did an exhaustive search of our records and we have not found any production/ injection records for the B-19 well. We did find an internal report dated August 13, 1991 (Attached)that summarizes the injection and later the production. Pulling from that report: The MPU B-19 well was drilled as a water injection well in late 1985 as part of the Phase II development of the Milne Point Unit. An attempt was made to put the well on line in the Lower Kuparuk zone in 1986, but satisfactory injectivity was never established and the well was left,shut in. Samples of indicating the perforations may be completely plugged. Dummy valves isolating the Middle Kuparuk sand were pulled in late 1989 and an attempt was made to inject in that zone. Acceptable injectivity could not be established and the well was again left shut in. It was recommended in December 1990 that the B-19 well be converted to a producer. The 8-19 is located in an isolated fault block in both the Middle Kuparuk and Lower Kuparuk sands , Bottomhole pressure surveys indicate the well is not in pressure communication with wells in the surrounding fault blocks and therefore had no utility as an injector. In May 1991 the wet 1K-1 sand was permanently abandoned by spotting and squeezing cement across the wellbore tubulars were then pulled, the MK-1 oil zone was open perfs. The w reperforated, and a 34,000 lb. fracture stimulation r atment was pumped to bypass the damage left after drilling. The B-19 was completed and brought on line June 26, 1991 as a 2-7/8" gas lift producer. It initially unloaded 100% water/brine at 500 BLPD. Production soon dropped to 200 BLPD at 90% BS&W. It produced on gas lift for approximately one month before it was shut in to curtail field-wide gas lift compression requirements. Water cut had not dropped significantly below 90%. Because of the lack of production history of this well, the injectivity test is needed to determine if the well can be injected into . Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. • 0 907=777-8420 C 985-867-0665 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, July 26, 2016 11:16 AM To: Ted Kramer Subject: Milne Point Unit KR B-19 (PTD 1852300) Sundry 316-377 Ted, AOGCC is progressing the Application for Sundry Approvals for the injection test of the well. Our review of our data and database found zero records of production or injection volumes. Please pull the file and see if there are records from 1985 showing any injection, or from June-August 1991 showing any injection or production. If you have any idea what went on with this well relating to injection/production we would like to hear so that we can update our records. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 • cor :o FiL Interoffice Communication { TO: D. E. Howell FROM: J. H. Andrew DATE: August 13, 1991 SUBJECT: MPU B-19 Excess Water Production Introduction The Milne Point Unit B-19 well has produced at an excessive water cut since it was worked over and fracture stimulated in June of this year. It is the objective of this report to evaluate this problem and make recommendations for future action. Conclusions 1. Natural water production from the MK-1 primary completion sand is very unlikely. Pressure surveys taken earlier this year indicate the B-19 fault block has not been depleted and is not in communication with offset Kuparuk wells. 2. Water production is most likely coming from one of two water-bearing sands within 300' below the MK-1 sand perforations. There are no water sands immediately above the MK-1 zone. 3. Poor primary cement coverage is not a likely conduit for the produced water. There is good cement coverage behind the production casing in this well . In addition, external casing packers were inflated and set between the water-bearing sands and the MK-1 oil zone. 4. There are no casing holes or open perforations near the wet sands which could allow water influx. The LK-1 water sand was permanently abandoned with cement prior to the workover. The cement also covered the small water lobe above it. The casing was pressure-tested following cement abandonment. 5. Possible casing damage is not a likely flow path for the produced water. Portions of the fracture stimulation were pumped at pressures in excess of calculated casing burst pressure. This may or may not have been above actual casing burst pressure. The casing could not have split all the way to the water zones since they are covered with cement. 6. Water production is most likely a result of penetrating one or both water sands during the fracture stimulation treatment. • • Recommendations 1. Run Water Flow and Production Profile diagnostic logs to determine the exact source of both the water and oil production. 2. Use the results of the logs to evaluate potential remedial action to block the water. Discussion The MPU B-19 well was drilled as a water injection well in late 1985 as part of the Phase II development of the Milne Point Unit. An attempt was made to put the well on line in the Lower Kuparuk zone in 1986, but satisfactory injectivity was never. established and the well was left shut in. Samples of acid-insoluble scale and mud were recovered from the wellbore at that time, indicating the perforations may be completely plugged. Dummy valves isolating the Middle Kuparuk sand were pulled in late 1989 and an attempt was made to inject in that zone. Acceptable injectivity could not be established and the well was again left shut in. It was recommended in December 1990 that the B-19 well be converted to a producer. The B-19 is located in an isolated fault block in both the Middle Kuparuk and Lower Kuparuk sands. Bottomhole pressure surveys indicate the well is not in pressure communication with wells in the surrounding fault blocks and therefore had no utility as an injector. In May 1991 the wet LK-1 sand was permanently abandoned by spotting and squeezing cement across the open perfs. The wellbore tubulars were then pulled, the MK-1 oil zone was reperforated, and a 34,000 lb. fracture stimulation treatment was pumped to bypass the damage left after drilling. The B-19 was completed and brought on line June 26, 1991 as a 2-7/8" gas lift producer. It initially unloaded 100% water/brine at 500 BLPD. Production soon dropped to 200 BLPD at 90% BS&W. It produced on gas lift for approximately one month before it was shut in to curtail field-wide gas lift compression requirements. Water cut had not dropped significantly below 90%. The B-19 is in a fault block which has been shown by recent pressure measurements to be completely isolated from other Kuparuk wells. There is little chance that the MK-1 formation is the source of the produced water. Attachment One is a structure map showing the B-19 location. It is more likely that the water is coming from wet sands below the MK-1 interval (10,102-10,119') . There is one small wet sand lobe at 10,240' . The wet LK-1 sand is located at 10,390' , approximatley 270' below the MK-1 perforations. There are no sands immediately above the MK-1 sand. Attachment Two is an open hole log section across the zones of interest. Formation water can reach the MK-1 perfs by four primary means. First, there could be poor cement coverage behind pipe as a result of a poor primary cement job. Drilling and cementing records have been reviewed as part of this study and both indicate a good cement job was probably obtained. This cannot be confirmed since a cement bond log was not run. However, many similar jobs were pumped and there have been very few documented instances of behind-pipe e flow. There was good circulation throughout the cement displacement. The wiper plug was bumped near the calculated displacement and the floats held. 41/ The casing and shoe passed a 1500 psig pressure test for 30 minutes. In addition, two external casing packers were run and inflated; one is above the bottom lobe of the LK-I sand and one is between the MK-1 sand and the top wet stringer. The second method water could be getting to the MK interval is through casing perforations or holes. Neither of these is likely. Since injection could never be established in the LK zone, the perforations were probably never adequately opened. We also spotted and attempted to squeeze cement into the perfs and any other open holes (from corrosion, buckling, etc.) during permanent abandonment. The casing held 500 psig pressure for 15 minutes with no cement loss. The cement top was tagged above the top wet lobe and a positive plug was set above that in a wireline nipple. All flow up the casing is effectively blocked. The third path of water influx could be through casing which was split or damaged during the frac job. The 10 ppg, 12 ppg, and 14 ppg stages of the frac job were all pumped near or above casing burst pressure, depending on the actual friction pressure loss. These stages were all pumped above the rated casing burst pressure using friction pressure losses calculated prior to the job. However, these are not very accurate calculations (since effects of proppant cannot be included) and the actual losses are almost certainly higher. Additional losses needed to remain below burst pressure range from 150 psi during the 10 ppg stage (our gauges aren't that accurate) to 850 psi during the 14 ppg stage. At any rate, it does not appear that this is a real problem. The packer used to treat the well came out of the hole with no problems. There were also no reports of pressure on the 3-1/2" x 7" workstring-casing annulus so if the pipe was parted it did not split very high. The production packer was also set near the MK-1 sand and it held test pressure with no losses. The casing could not part down to the top wet sand since that sand is covered with cement. Finally, we could have frac'ed down into one or both of the wet sands. This appears to be the most likely of the scenarios evaluated. Relatively high water production rates (180-500 BWPD) indicate the water is coming through a substantial conduit and not just a small crack somewhere. This is especially significant when one considers the production which should be coming from the thick, clean MK oil sand which is completely open and fractured. Experience in the L-Pad Kuparuk wells indicates the laminated transition zone between the MK and LK sands can be frac'ed through if the rate and pressures are high enough. In fact, we are designing frac treatments to do just that with the same 25 BPM treating rate used in this well . If the interval below the MK sand in the B-19 is a laminated sand and not a shale as initially thought, we could very easily have reached water with the frac. High injection pressures may have also opened a channel behind pipe either through or around cement even if a full fracture was not propagated. It is recommended that diagnostic production logs be run across and below the MK-1 sand to determine the exact water entry point. There is little that can be done if it is entering across the entire zone. However, if it is coming from one spot we may have a chance to block it. In addition, diagnostic logs are needed to confirm to both ourselves and our partners that we have done all we can to firmly establish the source of the water and make reasonable efforts to correct the problem following our $583,000 conversion and • * I � stimulation investment. Total cost for a Water Flow Log and one Spinner Log will be less than $30,000 gross. I am ready to discuss this at your convenience. Please let me know if you have any questions or need further information. cm 44 J. H. Andrew Production Engineer cc: DIR, DOU, B-19 Well File Milne Point - Sr. Foremen, Prod. Foremen i I • • . 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They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. L(~5-~,_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [3 Grayscale items: [] Other, No/Type [] Other items scannable by large scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) 'f Other: " ~} '~1 [] Logs of various kinds [] Other 'I'OTAL PAGES: ~/~" NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL~OWELL Project Proofing PROOFED BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: ISI PAGES: ~ ~ (at the time of scanning) SCANNED BY; ~EVERLY BREN ViNcE~MARIA LOWELL RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: / O/'"'~Z ~'/0~'' Quality Checked (done) PAGES:~ RevlNOTScanned.wpd .... Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-in Well Shut-In ~ Current Mechanical Condition of Well2 Possibilities 3 Comments MPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle gas. Possible production after gas expansion project. MPB-08 May-94 E No known problems 3 Futher use as an injector not required MPB-13 Jan-86 B GL well that was shut in due to high 3 We#house and flowlines removed water cut. Possible channel into water zone. MPB-17 Jan-96 E No mechanical problems. Quick 3 We#house and flowlines removed communication with producer MPB~.,19.,!% Jul-91 B GL well. High water cut producer. 3 We#house and flowlines removed · .~:....:: . -~ Possible frac into water zone MPC-11 Feb-96 E No known problems 3 Further use as an injector not required while associated producer shut-in MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems, 12a MPC-16 Aug-93 A High GOR well, perfs and completion 3 We#house and flowlines removed abandoned MPC-17 May-O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for solution to ~roblem. MPC-20 Apr-O0 B High water cut well, no mechanical I Evaluating possible plans for solution to ~robiems ~roblem. iMPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible plans for solution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block problem. Possible alternative uses for = we#bore MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well IMPE-02 Jun-05 C No known problems 2 Recomplete to upper Kup zone MPE-19 Aug-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb-O0 B , High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities MPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities MPL-21 0ct-98 E 'High pressure block - 5000 psi, no I Possible use for injection when pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP, no other mechanical I Evaluating possible side track plans or issuses recompletlons MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or for it. recompletions *Note - Wells were shut in 100% during 2001 Milne P1 Shu! In Wells 2001 .)ds . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount O:/'Y DATE: July 12, 2000 Commissioner I tf Ilo/bc.) THRU: Blair Wondzell, <a~ P. I. Supervisor .êf-r(dJ FROM: Jeff Jonei, I:!t¡- SUBJECT: Safety Valve Tests Petroleum I sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. 3 ~~ r.z..-k-7t- 21 well houses were inspected, no failures. .".. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rcp: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 BPS NI A 7/9/00 N ~ N ~".:<' : W ell :tjat~',:" ;{.':- '/::!'",'>.;/::-:;.,;.. +.: ,:..\-, Pilots~', i' ..i, '~\'~~J~¡/~:,~:'~:,::,/ ',,-SV' ,~SSV,~ ," " Well::Type ".. .~ \ ..:., ~ ,:,: :,.~...,..::-:.~.,::._I.._.~., Well Pern1it Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE B-02 1811420 B-03 1820560 140 100 115 P P OIL B-04A 1821000 ]40 100 95 P P OIL B-06 ]850130 140 100 90 P P OIL B-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 Components: 18 Failures: Failure Rate: 5.50/0 090 Day Wells: Remarks: Three well SV's recorded slow closing tilDes; B-04A(3:20), B-03(3:03),B-06(3:30). Son1e of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. ~ /7 100 Page 1 of 1 Vvo43m 1 t.xls Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 December 17, 1993 Mr. Russell A. Douglass Commissioner Alaska Oil and Gas Conservation Commission 3001-Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. DoUglass, Pursuant to our December 15, 1993 meeting, please regard this letter as Conoco's request to-cancel the following Applications for Sundry Approvals, Form 10-403' Well Approval Date Approval No. Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist CC: Mr. Jack Hartz, AOGCC JHA, WCD/HDS Chevron Occidental E-3 Well File C-8 Well File B-19 Well File DEC 2~ 199~ Oil & Gas Oons. Commission Anchorage June 22, 1993 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MPU B-19; APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached are three copies of our Application for Sundry Approval, Form 10-403, for perforating and stimulating Milne Point Unit well B-19. Please direct any questions or concerns regarding this application to me at 564-7660. Sincerely, o~\ . Tom Yeager SHEAR Specialist Attachment CC: JHA, TJY Chevron Occidental B-19 Well File RECEIVED JUN 2 9 199 A:aska Oil & Gas Cons. Commission AnchOrage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation shutdown ~ Re-enter suspended well . Alter casing ~ Repair well ~ Plugging-- Time extenfion Stimulate X Change approved program Pull tubing X Variance Perforate X Other __ / 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development X_.~_ 59' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Strafigraphic Milne Point Unit 4. Location of well at surface 8. Well number 881' FSL, 890' FWL, Sec. 18, T13N, R11E, U.M. B-19 At top of productive interval 9. Permit number 53' FSI_, 3780' FEL, Sec. 12, T13N, R10E, U.M. 85-230 At effective depth 10. APl number 231' FSL, 3978' FEI_, Sec. 12, T13N, R10E, U.M. 50-029-21451 At total depth 11. Field/Pool 364' FSL, 4126' FEL, Sec. 12, T13N, R10E, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 10,710' feet Plugs (measured) true vertical 7506' feet Effective depth: measured ~ [~) ~' I'/feet Junk (measured) true vertical ~ feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" To Surface 115' 115' Surface 6077' 9-5/8" 275 sx Class G 6113' 4545' Intermediate 1575 SX Permf E Production 10,650' 7" 300 SX Class G 10,684' 7558' Uner RECEIVED Perforation Depth: measured 10,102' - 10,119' true vertical 7115' - 7126' JU~J ~ ~) Alaska.Oil.& 8as Cons, .Commission Tubing (size, grade, and measured depth) 2-7/8", L-80, 9956' . ancl~orag~-' Packers and SSSV (type and measured depth) Otis FMX SCSSV @567';'Otis MHR Pkr @9900' 13. Attachments Description summaryof proposal X Detailed operations program m BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: · September 1, 1993 16. if proposal was verbally approved Oil x Gas Suspended Name of al~prover / Date approved Service 17. I hereby c, rtify tharthe foregoing is true and correct to the best of my knowledge. / Signed L~ ,/~AOF,~J J.H. Andrew Title Sr. Production Engineer Date June 22,1993 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Cj.., / ¢ Plug integrity BOP Test__ Location clearance ~ °"I~C~ GO~3~J [ Mechanical Integrity Test__ Subsequent form required 10- ~O~f'~ ~,,~ .9~.;~ ~ ~,- i ...~ i..~'/ Original Signed BY David W. Johnston Commissioner Date ,~'~.,-~"l.~o,~,~,~^ Approved by order of the commission ¢1 'ri-- S[J IN Form 10-403 Rev 06/15/88 ~ .,~ //, .-, ~ ..... ,,, ...-4 ,~, .... Milne Point Unit B-19 Workover Procedure Summary 1. RU tanks with completion fluid. Kill well. 2. MIRU workover rig. ND tree, NU and test BOPs. · MU landing joint and PU to sting out of Otis PBR seal assembly at 9884'. Circulate 10.2 ppg packer fluid remaining from the 2-7/8" x 7" annulus with new kill-weight completion fluid to balance hole. 4. POOH and LD 2-7/8" EUE production tubing. · PU power swivel and drillpipe. TIH with packer milling BHA and mill slips from Otis MHR Perma-Drill packer at 9900'· POOH with packer and tailpipe. · TIH with 6" bit and BHA for drilling cement. Drill cement from 10175' to 10460'. POOH and LD BHA. · RU electric line. GIH and perforate the LK interval 10390'- 10409' and 10438'-10482' overbalanced at 24 SPF with 4-1/2" casing guns. POOH and RD electric line. · PU treating packer and TIH to 10350'. Set packer. RU and pump fracture stimulation treatment to open LK sand interval. · Allow pressure to dissipate and POOH. LD packer. TIH open ended and reverse frac proppant remaining in wellbore to PBTD. POOH and LD workstring. 10. RU electric line and set permanent packer with tailpipe assembly at 10300'. RD electric line. 11. TIH with 2-7/8" 6.5#/ft EUE production tubing string including retrievable packer, MKsand isolation/seal assembly, gas lift mandrels and SCSSV. 12. Sting into packer above LK sand. PU and space out completion. Circulate inhibited fluid. Freeze-protect tubing and casing with methanol. Land and lock down hanger. 13. Set packer. Pressure test 2-7/8" x 7" annulus to 1850 psig for State MIT. 14. ND BOPs. NU and test tree. 15. 16. RD workover rig. Place well on gas lift production. RECEIVED JUN 8 9 199 Alaska OJJ & Gas Cons. Comm~sio[~ Anchorage NOTES: WELL No. COMPLETION MILNE POINT ]3-19 SKETCH UNIT (P) APl No.: 50-029-21451 PERMIT No.: 85-230 COMPLETED: 10/19/85 LAST WORKOVER: 6/6/91 1. ALL MEASUREMENTS ARE FROM KDB OF NABORS RIG NO. 27E KDB - SL = 59' KDB - GL = 35' 2. MAX. ANGLE = 59.25' @ 4500' 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. MIN. ANGLE = 48.5' AT 10,000' 6. TREE TYPE: FMC ,3 1/8" APl 5000# WITH ,3 1/2" 8 RD. TREETOP CONNECllON. 7. MIN. RESTRICTION: OTIS SERIES 10 FMX TRSV (2.513) @ 567' 8. COMPLETION FLUID: 10.2 PPG NoCI-NoBr BRINE 8. FRAC 6/91 - 51,000# 16/20 ISP MK-1 F3~,C TUBING HANGER W/ 5 1/2" 'H' BPV PROFILE --2 7/8", 6.5# L-80 EUE TUBING (2.441" ID) I.D., 2.867" DRIFT) --567' OTIS SERIES 10 FMX TRSV (2.313" lO) 1842' GLM 2776' GLM 3678' GLM 4644' GLM 5542' GLM 6548' GLM 21' GLM GLM 9797' --98EM' 9900' 9906' 9915' GLM WLM FOUND 1.75' RESTRICTION WITH SLICKMNE ON 2-26-93 OTIS PBR, SEAL ASSEMBLY (2.313" ID) OTIS MHR P-ERMA DRILL PACKER (,3.875" ID) OTIS MILLOUT EXT. (4.,35" ID) XO 4 1/2" EUE x ,3 1/2" EUE (2.441 CAMCO 2 7/8" KBMG 9914' XO 3 1/2" EUE x 2 7/8" EUE (2.441 ID) PERFORATIONS: 12 SPF AT 120' PHASING LK-1 - SQUEEZED 5/91 10,409'-10,390' MD 7522'-7306' TVD MK-1 10,119'-10,t02' MD 7130'-71i6' TVD (BASED ON DiL LOG OF 10-16-85) 10, i02'-10,118' 1',.4D 7116'-7i29' TVD REPERF 6/91 5 SPF 60' PHASE ;--.-. :; :..::--.-.:-'.. ._. CONOCO INC. A;-JCHORAGE DIVISION --2 7/8" TUBING ~9950' "X' NIPPLE (2.313" I.D.) --9951' 2 7/8" PUP -- 9956' TUBING TAlL ~ c~"" ..~ · 10,240' EST TOC ~0,599' PBTD (\'4RELINE MEAS.) !0,685'--7", 26 LB/FT L-60 BTRS (6.184" ID, 6.059" DRIFT) IAPPRO\,"ED ::JY: 5HA/HDS DATE: 2-25-9.3 ? I ..... '¢,:CO!3 ! 9 DRAFTED :BY: SJi,.' CAD -~ ~-' Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 September 18, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Report of Sundry Well Operations Dear Mr. Johnston' Attached please find the Report of Sundry Well Operations for Well B-19. The well is located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564-7617. Yours very truly, Bob Soptei Environmental Coordinator RJS(bgs) attachments CC Occidental Petroleum Chevron Inc. B-19 Well File C:\DATA\WP51 \RJS\AOGCC 17 RECEIVED $,zP ~. o ,,.,.., Alaska Oil & Gas Cons. C0mrnissi0~ Anchorage · ~ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. C~.perations performed: Operation shutdown __ Stimulate ~ Plugging __ Pull tubing__ % Alter casing ~ Repair well __ 2. Name of ©perator ~ 5. Type of Well: CONOCO INC 1 Development · Exploratory 3. Address Stratigraphic 3201 "C" St., Suite 200 Anchorage, AK Service~ 4. Location of well at surface 881'FSL, 890'FWL, Sec. 18, T13N, RilE, U.M. At top of productive interval 53'FSL,3780'FEL, Sec. 12, T13N, R10E, U.M. At effective depth 231'FSL,3978'FEL, Sec. 12, T13N, R10E, U.M. At total depth 364'FSL,4126'FEL, Sec. 12, T13N, R10E, U.M. Peflorate __X Conve rs ion- Inj ec tJ Other___ to Producer 6. Datum elevation (DF or KB) 59' KDB feet 7. Unit or Property name Milne Point Unit 8. Well number B-19 9. Permitnumbedapprovalnumber 85-230 10. APInumber 50-02.9-21451 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured 10,710 ' true vertical 7,506 ' Effective depth: measured 10,450 ' true vertical 7,344 ' Casing Length Size Structural Conductor 80 ' 16" Surface 6077 ' 9-$/8I' Intermediate Production 10,650 ' Liner Perforation depth: measured 10,102' - 7,115' feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth To Surface 115' 115' 275 sx Class G 6113' 4545' 1575 sx Permf E 711 10,118' 7,126' 300 sx Class G 10,684' 7558' true vertical Tubing (size. grade, and measured depth) 2-7/8", OTIS Packers and SSSV (type and measured depth) OTIS REC IVF. D 6.5#/Ft., L-80, 9956' "MHR" 7" 26-32¢ ~9900' ,c.;_ ~. ,.~ i~,~,, 'F~' TRSV ~567' Alaska 0i~ ,~ Ga3 Cons. Oommiss[o~ 13. Stimulation or cement squeeze summary FRAC JOB lntervals treated (measured) '10,102' - 10,118' Treatment description including volumes used and final pressure 31,100# ISIP - 2000 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil X_. Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~or~over Histo~ ~D~ Point B No.19 - Convert Injector to Producer API No: 50-029-~1451 Location: Milne Point Field - KUPARUK RIVER 05/27/91: Move rig from J-3 to B-19. R/U on location. Rig accepted on AFE 1341 @ 1000 hrs, 05/26/91. 05/28/91: .Dump to raise derrick broke down. Change out pump. Finish R/U. Install BPV. N/D tree. N/U BOPs. Pull BPV. Install two-way check valve. Test BOPs. Test rams, choke & kill lines to 5000 psi. Test annular to 1500 psi. 05/29/91: Finish BOP test. Pull two-way check valve. M/U landing jt to tbg hgt. Pull seal assby out of PBR. L/D hgr, 3 PUP jts. String pulling wet w/ diesel. Attempt to rev circ diesel out of tbg. SCSSV closed. R/U to circ down tbg. build berm for trash tank. R/U tank. Make full circ down tbg (= 400 bbls). POOH L/D 3-1/2" tbg. Clean rig floor. Change out tongs. 05/30/91: Change pipe rams from 3-1/2" to 4". P/U FMC test plug. Could not break XO off plug. Get 7-5/8" tongs from J-Pad. Tongs did not break out XO. Bring test plug to Nabors 27E to break sub. RIH w/ test plug to test rams to 5000 psi. POOH w/ plug. Run wear bushing. M/U overshot, bumper sub, jars. P/U 4" DP & TIH Tag PBR @ + 9912' S/O & '~-~ ~ TM · - -. ~.. ~B~.. Rotate to right = 12 turns & P/U. Increase in string weight & drag indicated PBR/Packer was latched & free. POOH. Note: @ 02300 hfs, retrieved full PBR/PKR assby. 05/31/91: Finish POOH. Retrieved PBR, BOT PKR, GLM, seals. L/D same. P/U bit, scraper & TIH. Tag PKR @ 10,135' (EWS RKB). R/U to rev circ. Pump 20 bbl dirt magnet pill, 30 bbl HzO, 20 bbl dirt magnet pill. Filter while circ. Flowline came apart as "gunk" off bottom reached surface. Repair same. Finish circ/filter hole. POOH. Clear rig floor. Move tool shed for HLS truck. R/U Halliburton Logging Services. Arm guns. Finish R/U lubricator. P/U gun/GR tool. Pin end of open hole to cased hole. -Adaptor bent while picking up gun. No backup on location. Call to locate backup adaptor. ~iaska 0i! & f3as Oa¢is. ¢ommissio~ Anchorage Workover History, Milne Point Well No. B-19 Page 2 06/01/91: Wait on HLS XO adaptor from Deadhorse. Bridge out, wait on helicopters to fly. R/U HLS to perf. RIH w/ perf gun-GR. Tie in w/ GR. Perf MK-1 sand f/ 10,102'-10,118' MD, 5 SPF, 60' phasing, 36 gram. POOH. R/D HLS. P/U 3 its 4" DP for stinger, Champ III PKR, jars & TIH on 4" DP to 10,050'. Set Champ PKR @ 9961' Test backside to 2000 psi. Prime pumps. Test surface line~ to 9000 psi. Pump frac job as follows: (@21-25 bpm). 100 bbls pre-pad - ISIP 2283 psi, 1670 psi after 10 minutes; 190 bbls pad, 2 ppg slurry (12 bbls) , 4 ppg (14 bbls), 6 ppg (17 bbls), 8 ppg (20 bbls), 10 ppg (22 bbls), 12 ppg (26 bbls), 14 ppg (16 bbls), 109 bbls 10.2 ppg flush. ISIP - 2000 psi. 06/02/91: Shut in well after frac job. ISIP - 2000 psi. R/D D/S. Monitor well pressure: @ 1:00 am - 1000 psi, 2:00 am - 650 psi, 3:00 - 450 psi, 4:00 - 300 psi. Bleed = 1-2 bbls off DP. Press - 180 psi. Monitor well. Bleed 2 bbls @ 11:00 am, Press - 50 psi. @ 1500 hfs, well trickling. Unseat PKR. R/U to rev circ. Rev circ 1 DP volume. Observe well for 1 hr. Well dead. POOH w/ Champ PKR- L/D same. P/U saw~ooth collar, flapper valve, 10 stds DP, safety jt, bailer. Prepare to TIH. 06/03/91: TIHw/ bailer. Tag sand @ 9997'. Bail sand f/ 9997 - 10,135' (depth of PKR). Pull 5 stds. Wait 1 hr. TIH to PKR @ 10,135'. No fill. Take 11.0 ppg brine. Cut weight to 10.2+ ppg. POOH. L/D bailer. Recovered 5 bbls frac sand. Clean floor. P/U bit, 2 jts DP, csg scraper. TIH. TIH w/ bit & scraper. Tag bottom @ 10,132'. Filter brine in tanks. 06/04/91: POOH L/D 4" DP. R/U to run PKR, 2-7/8" tbg. Function test BOPs. Change ou~ pipe ra~s to 2-7/8" & test to 5000 psi. OK. M/U wireline re-entry guide, 2-7/8" PUP Jt (4'), Otis , 7" Otis "MHR" permanent PKRassby "X" nipple 1 jt 2-7/8" tbg, . RIH on 2-7/8" tbg. Place GLMs per completion procedure. 06/05/91: RIH w/ Otis PKR, GLMs on 2-7/8" tbg. P/U SCSSV & M/U control line. Test line to 5000 psi. Continue RIH w/ PKR. Found defect in control line. Pul pipe to SCSSV & spool off control line. Wait on new spool from Deadhorse on helicopter. Helicopter fogged in a.m. M/U new spool. Test to 5000 psi. RIH & put Otis PKR @ 9900'. R/U wireline. RIH & attempt to set plug in X-nipple @ 9951'.. Plug would ~ot set. POOH. Add weight, k~uckle jt & RIH to nipple @ 9951 . Set plug. POOH. Press up on tbg to 2700 psi - PKR set. Press up to 3400 psi - SBR sheared. Press up to 4600 psi & wait 5 minutes. P/U out of SBR. Workover His=cry, Milne Point Well No. B-19 age 3 06/06/91: Circ 295 bbls completion fluid (10.2 ppg brine w/ 4 gal per 100 bbl NALCO 3900) down 7" x 2-7/8". Space out, P/U tbg ngr. M/U control line. Test to 5000 psi. Land hgt. R/U Otis. RIH to _+ 1850' & pull GLM dnmmy, circ 11 bbls diesel down 7" x 2-7/8" for freeze protection. Let U tLLbe down 2-7/8" tbg. RIH w/ wireline & set dum~y back in GLM. Press test backside to 1800 psi. OK. Hold for 30 min. RIH w/ wireline & pull plug from nipple @ _+ 9959'. R/D Otis. Set BPV. N/D BOPs. N/U tree. Set 2-way check valve. Test tree to 5000 psi. OK. Pull 2-way. Set BPV. SCSSV closed. R/D & move to L-5. Operations concluded. Released rig @ 1900 hfs, 06/05/91. TO: THRU: FROM: MEMORANuUM of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Sm DATE: Aug. 20,1991 Commissioner FILE NO: DA 820-3 TELEPHONE NO: SUBJECT: BOP Test Conoco MPU B-19 Permit No. 85-209 Kuparuk Ry. Field Doug Amos~ Petroleum Inspector Friday'Aug. 16. 1991: I traveled this date from Prudhoe Bay to Conoco's MPU B-19 well to witness the BOP test at Nabors Rig No~ 27E. The testing commenced at 3:30 pm and was concluded at 5:30 pm. As the attached AOGCC BOP inspection report indicates the cell~ar gas detector was out of calibration. I was contacted by Dave Mountjoy Conoco rep. on 8/17/91 and informed that the cellar gas detector had been calibrated. Because this was a workover for the repair of a hole in the 9-5/8" csg I remained on location and witness the csg test. The casing was tested at 1500 psi for 30 minutes and loss 40 psi during this time. In summary, I witnessed the BOP test at Conoco's MPU B-19 injection well on Nabors Rig No. 27E, the single failure during this test was corrected on 8/17/91. I also witnessed the successful 1500 psi 30 min. 9 5/8" csg test. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg , Wkvr Operator O,d 0 Well /V"] P U 1,,~ " / ? Location: Sec i~ T /.~j~/ R , grlg contrctr ,~/~/~ Location (general) J Housekeeping (general) ~ 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report MUD SYSTEMS: Visual Trip tank ~ Pit gauge J/~ Flow monitor / Gas detectors / Well sign l~ Rig k~~ Audio 'V BOPE STACK: ' Test Pressure Annular preventer Pipe rams 4/ Blind rams Choke line valves~ HCR valve ,.,J(' J If Kill line valves Check valve DATE TEST: Initial Rig# Representative ./~, ~. '~ /' C~sing set ~ ACCUMULATOR SYSTEM~ Full charge pressure Press after closure Weekly Other iAO0 Pump incr clos press 200 psig min ~ Full charge press attained / min "2 ! 3 psig Controls: Master / Remote ~/ Blind switch cover y~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly ~ j Test pressure Lower Kelly J~ ! Test pressure Ball type ~ Test pressure / Inside BOP ~f' J Test pressure // Choke manifold ~-/ Test pressure /! Number valves /~ Number flanges Adjustable chokes Hydraulically operated choke / ft psig psig ~..~ sec (o sec TEST RESULTS: Failures / Test time ~ hrs Repair or replacement of failed equipment to be made within ~.~ days. Notify the Inspector, and follow with written/FAXed verification to Commission office. orig - AOGCC WITNESS (~ c - Operator ~ c - Supervisor C. 004 (rev 07/08/91 ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCATTON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well X Alter casing Repair well __ Plugging__ Time extention m Stimulate X Change approved program__ Pull tubing X Variance Perforate X ' Other X Abandon LK-1 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development 59' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit Service X 4. Location of well at surface 8. Well number 881' FSL, 890' FWL, Sec. 18, T13N, R11E, U.M. B-19 At top of productive interval 9. Permit number 53' FSL, 3780' FEL, Sec. 12, T13N, RIOE, U.M. 85-230 At effective depth 10. APl number 231' FSL, 3978' FEL, Sec. 12, T13N, RIOE, U.M. 50-029-21451 At total depth 11. Field/Pool 364' FSL, 4126' FEL, Sec. 12, T13N, RIOE, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 10,710' feet Plugs (measured) true vertical 7506' feet Effective depth: measured 10,450' feet Junk (measured) true vertical 7344' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" TO Surface 115' 115' Surface 6077' 9-5/8" 275 sx Class G 6113' 4545' Intermediate 1575 SX Permf E Production 10,650' 7" 300 SX Class G 10,684' 7558' Liner Perforation Depth: measured 10,102' - 10,119'; 10,390' - 10,409' RECEIVED true vertical 7116'-7126'; 7306' - 7316' ;JAN ].991 Tubing (size, grade, and measured depth) 3-1/2", L-80, 10,185' .jt~:O~J ~, .Gas C0135, ~]~1 , ch0rag Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @1899';DOT HB Pkr @9947', 2B Pkr @10,154' 13, Attachments Description summaryof proposal X Detailed operations program __ BOP sketch ~ 14, Estimated date for commencing operation 15, Status of well classification as: February 1, 1991 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Watertood Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / Signed J.H. Andrew Title Production Engineer \v/l~ j~J~ Date 12/08/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. / Plug integrity BOP Test Location clearance__, ~'/' Mechanical Integrity Test//~ Subsequent form recluired 10- ~/Y'~ ~3~,O~j Gd ~,,~0~)¥ Approved by order of the Commission ORIGINAL SiG,F--D ~,¥ ~ner /-/~ , ~,~l~c r' c:~JIITI-I Date - /~'/ ...................... ~,~, ,..,. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE B-19 Injector Conversion Procedure Summary I · 2~ e e e 7, 9. 10. 11. 12. 13. 14. RU slickline. GIH and pull circulating valves from 1-1/2" BOT FMHO mandrels at 10,020' and 10,063'. Replace with dummy valves. GIH with gauge ring/impression block and tag PBDT (near 10,450'). RD slickline. _ - RU coiled tubing unit. GIH and spot cement plug across the LK-1 zone. PU into tubing and squeeze cement into perfs. Fill hole with 10.2 ppg brine. POOH and RD coiled tubing. MIRU EWS workover rig on well. ND tree. NU BOP's. POOH and LD 3-1/2" 9.2 #/ft production tubing above BOT PBR assembly at 9933'. PU workstring. GIH with retrieving tool and latch BOT HB packer. POOH with packer and isolation assembly. RU electric line. GIH and perforate the MK-1 sand 10,102'-10,119' with 5 SPF casing guns. RD electric line. RU fracing equipment and frac zone. RD fracing equipment. Clean out prop. from wellbore. TIH with 2-7/8" production string with XN nipple, production packer, production seals, gas lift mandrels, and SCSSV. Run tubing to set packer near 9930' and SCSSV near 550'. Circulate freeze protection. Space out and set packer. ND BOP's. NU production tree. RU flowlines and control system. ~P]~e w_ell on production. Install gas lift valves to initiate/accelerate-pro~io-6~,~y. /tlLNE POINT UNiT B-19 £Ot PLETED ON KD8 - Si_ · 59' KD8 - GL · 35' /',AX. AI~ · 59.25 o 45f~8' KOP · 50~' F~.£ 3 !/8' APl 5B00. TRCE V/ 3 !/2' 8 FO. TREETOP ~CT I Ct4 AIN CClNSTRICTICN, 2.75' 'O' NIPPLE APl ND.' 5B-B29-21451 ~ I ~.~-~ N~,Ct/N~B,- PERFORAT I 5' HOCLOV CARRIER RETRIEV,*?~.E CN v/I 12 SFF. 12,.] PHASII'IG ?L FI$ 'TVD 1~. 399- I ,"'1.,.409 ' rD 72,¢,6-~'3.~£ ' TVD IE)-21 FAC TUBING HANGL~ V/ 3 I/2' 'H' Et~ ~II_E 3 I/2' 9.2, L-Bi] BTRS. 12.992 ID, 2.867 DRIFT) 1899 ' CAt',CO T~- 1 A-SSA SCSSV I ID · 2.8121 9933' ~T ~ SF_AL ASSF_,',.RLY IS.il ,qYE~,ALL 1 PAF_j~ t 2.89 ID I 9987' CA*CO 5ELE£T I\~ N IF-FLE 12. 875 iEII 18.828' BOT F/N-lO I 1/2' C-,LA 1~.063' Oi_~ lB. 181 ' BLAST JOINTS ;J.6,55' 7' ~6,~ L-ED BTR-%. ~ lb 184 lO 6.~59 L'I:~IFT) 1. Type of Request: Abandon__ Suspend m Operation shutdown __ Re-enter suspended well X Alter casing __ Repair well Plugging __ Time extention __ Stimulate X Change approved program Pull tubing X Variance __ Perforate X Other X Abandon LK-1 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ ,5~)' KDB feet 3. Address Exploratory __ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic __ Milne Point Unit Service X x 4. Location of well at surface 8, Well number 881' FSL, 890' FWL, Sec. 18, T13N, R11E, U.M. B-19 At top of productive interval 9. Permit number 53' FSL, 3780' FEL, Sec. 12, T13N, RIOE, U.M. 85-230 At effective depth 10. APl number 231' FSL, 3978' FEL, Sec. 12, T13N, RIOE, U.M. 50-029-21451 At total depth 11. Field/Pool 364' FSL, 4126' FEL, Sec. 12, T13N, RIOE, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 10,710' feet Plugs (measured) true vertical 7506' feet Effective depth: measured 10,450' feet Junk (measured) true vertical 7344' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" To Surface 115' 115' Surface 6077' 9-5/8" 275 sx Class G 6113' 4545' Intermediate 1575 SX Permf E Production 10,650' 7" 300 sx Class G 10,684' 7558' Liner Perforation Depth: measured 10,102'-10,119'; RECEIVED true vertical 7115' - 7126'; 7306'- 7318' DEC 1 2 199(} Tubing (size, grade, and measured depth) 3-1/2", L-80, 10,185' Alaska Oil & Gas Cons. C0mm'msi0a Anchorage Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @1899';BOT HB Pkr @9947', 2B Pkr @10,154' 13, Attachments Description summary of pmposai X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: January 1, 1991 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Waterflood Iniector 17. I hereby c ;rtify the Ithe foregoing is true and correct to the best of my knowledge, Signed k,~ M ,~ ~ J.H. Andrew 3-~e Production Engineer Date 12/08/90 J FOR COMMISSION USE ONLY Conditions of approvai: Notify Commission so representalive may witness Subsequent required Plug integrity BOP Test Location clearance --- Mechanical Integrity Test ~ form 10- ,~-~-' OI~IGI~AL SIG~ED BY ~ Approved Copy LONNIE C. Sk~TH R(~turnl~d Approved by order of the Commission --. ~:¥~0] ~ Commissioner Dato STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMIS~),ON "~ APPLICATION FOR SUNDRY APPROVALS SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 - B-19 InjectOr Conversion Procedure Summary · · e 4e · e Be 9. 10. 11. 12. 13. 14. RU slickline. GIH and pull circulating valves from 1-1/2" BOT FMHO mandrels at 10,020' and 10,063'. Replace with dummy valves. GIH with gauge 'ring/impression block and tag PBDT (near 10,450'). RD slickline. RU coiled tubing unit. GIH and spot cement plug across the LK-1 zone. PU into tubing and squeeze cement into perfs. Fill hole with 10.2 ppg brine. POOH and RD coiled tubing. MIRU EWS workover rig on well. ND tree. NU BOP's. POOH and LD 3-1/2" 9.2 #/ft production tubing above BOT PBR assembly at 9933'. PU workstring. GIH with retrieving tool and latch BOT HB packer. POOH with packer and isolation assembly. RU electric line. GIH and perforate the MK-1 sand 10,102'-10,119' with 5 SPF casing guns. RD electric line. RU fracing equipment and frac zone. RD fracing equipment. Clean out prop. from wellbore. TIH with 2-7/8" production string with XN nipple, production packer, production seals, gas lift mandrels, and SCSSV. Run tubing to set packer near 9930' and SCSSV near 550'. Circulate freeze protection. Space out and set packer. ND BOP's. NU production tree. RU flowlines and control system. Place well on production. Install gas lift valves to initiate/accelerate production, if necessary. RECEIVED DEC 1 2 1990 Alaska Oil & Gas Cons. Com~tss'tot~ Anchorage AILNE POINT UNIT B-19 CO/ PLETED ON 10-2I -85 Fee - st. · 5g' KD8 - GL · 35' AAX. AN~ · 59.25 4588' K~ · 500' F/LC 3 I/8' AP[ 5000, TREE V/ 3 !/2' 8 RD. TREETOP ~CT [C~I AIN. CO~TRICTII3N , 2.75' 'O' NIPPLE APl NO.' 58-829-2145I PERFORAT [ONS' 5' HCt..LOV CARRIER RETRIEVAELE ON ','/I 12 SPF. I2~ PHASII~ i 16-71 ' FAC TUBING ~ V/ 3 I/2' 'H' EPV PRIZe'ILE I ! / 10,.~.~'~0 .10.40g, 731~6-7322 ' T~ i i 3 I/2' 9.2~' L'80 BTRS. 12.992 ID, 2.867 BRIFT) 1899' CA/~O TREP'IA'SSA SCSSV I ID · 2.812 i RECE 9933' EOT Pe~ DEC 1 SEAL ^SSE~J~LY I 3.0 ID I Alaska 0il & Gas [ Anchm 9947' EOT 'H~' FF~ALL lC PACKF_~ (2.89 IDi 9987' C/u,JSO v- 1 SELECT I VE N I PPLE 1 2,8?5 ID I 10,828' EOT F~ I 1/2' GLA 10.063' 6LA 10. 101 ' BAST JOINTS 10. 153' EOT 'CL' ~_~ LOCATER c_.E. AL ASSE/tBLY ~ 10.154' EOT '2B' PER~NT F¥,R. Abl3 SEAL EOF~ EXTENSION A 1LLOUT EXTEN51 ON -- 10, I??'CAACO 'O' NIPPLE 12.T5 ID -- 10. 185' TLIBIr,G TAIL 10.599' PgTD 1¢ 685' 7' 26~, L-80 BTRS "~ 16'184 ID 6.859 DRIFT i VED 1990 ,ns. Commission age Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. B-3, B-4A, ~-6, .n_c,_ , h-lO,~ B-~i,...5-13,~ B-15, B-!6, C-l, C-2, C-j, C-4, =" C- ~ C-~=, C-7, 9, C-13, C-14, C-i6 S T~? lC: B-20, B-2i, B-22 C-i7, C-IS All active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. %he annular fluid levels will be monitored for leaking gas li=t valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-do~ operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Mi~ne Point Unit.~! ~ [ ','~, ~ ~" ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-Ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. ~ne wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the ~ '~ ~ If you have any questions on the shutdo~ procedure please contac~ Don Girdler at 564-7637. Vo~rs very t "~ '~ Manager "---' STATE OF ALASKA .... ALASt_. OIL AND GAS CONSERVATION COMN .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown _ Re-enter suspended well [3 Alter casing [-J Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Address 6. Unit or Property name 3201 C Street, Ste. 200, Anchorage, Alaska 99503 Milne Point Unit 4. Location of well at surface 881' FSL, 890' FWL, Sec. At top of productive interval 53' FSL, 3780' FEL, Sec. At effective depth N/A At total depth 364' FSL, 4126' FEL, Sec. 12, T13N, R10E, U.M. 18, T13N, RllE, U.M. 12, T13N, R10E, U.M. 7. Well number 8. Permit number 85-230 9. APl number 50-- 029-21451 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 10710 feet 7506 feet Effective depth: measured N/A true vertical feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 80' 16" Surface 6077' 9 5/8" Intermediate Production 10650' 7" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) 3!~'' L-80 , , Cemented To Surface 608 bbls 300 Sxs 10102'-10119'; 10390'-10409' 7115'-7126'; 7306'-7318' 10185' Measured depth 115' 6113' ~ue Verticaldepth 115' 4545' 10684 ' 7558' Packers and SSSV (type and measured~de~t'n)SCSSV @ 1892'; Ret.'Pkr. @ 9947'; Perm. Pkr. @ 10154' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereJ~f-ceftify th~tt the foregoing is true and correct to the best of my knowledge Signed ~O,~,--~ '"U~ J-,~-- Title - Sr. 2roduction Zngiz. aa~ Commission Use Only Date 12 --g'~ - ~. Qo Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ~.~.~ur,~d/ . Commissioner IApproval No. 7 0 ~' by order of // " the commission Date/,~/~' ,~,,..~9' ~ Subrhit in"triplicate Form 10-403 Rev 12-1-85 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 Ig07) 564-7600 August 27, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are daily drilling recaps for MPU wells B-5A, B-8, B-12, B-14, B-18, B-19, B-21, C-10, C-II, C-12, C-18. Completion reports were submitted by our letter of August 18, 1986. If you should have any questions please call Charles Taylor at 564-7606. Yours very truly, E. D. Wilson Division Administrative Manager CLT/vv Well File RECEIVED AUG 2 8 1986 Ala.-Im Oil & Ga~ Cono. Commie, sion Anchorago Kuparuk River Field - North Slope Borough, Alaska W.I. - 53.3355% Milne Pt. B. No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890' FWL,Sec. 18, T13N, RilE, U.M. Objective: 10,508' - Kuparuk River 10-6: RIG ACCEPTED 0830 hrs. on 10-5-85. Drlg. to 250' f/108'. Mud Wt. 9-2 ppg. Viscosity: 62 Cum. Mud Cost: $ ~ Nabors 27-E (0-1-0) Drilling Foreman: Brady Weather: Temp. 27° Wind: S 6 knots Visibility: 15 miles 10-7: Drlg. f/1145' to 3250'. Mud Wt. 9.5 ppg. Viscosity: 60 Nabors 27-E (0-2-0) Weather: Temp. 37° Wind: SW 8 knots Kuparuk River Field - North Slope Borough, Alaska Milne Pt. B. No. 19 (I) CONFIDENTIAL Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 15 miles W. I. - 53.3355% AFE 10-61-1141 Location: 881' FSL, 890' FWd,Sec. 18, T13N, RllE, U.M. Objective: 10,508' - Kuparuk River 10-8: Drlg. f/3250' to 4775'. Mud Wt. 9.6 ppg. Viscosity: 54 Nabors 27-E (0-3-0) Weather: Temp. 38° Wind: SW 15 knots Kuparuk River Field - North Slope Borough, Alaska Milne Pt. B. No. 19 (I) CONFIDENTIAL Location: 881' FSL, 890' FWL,Sec. 18, T13N, RilE, U.M. Objective: 10,508' - Kuparuk River 10-9: Drlg. f/4775' to 5760'. Mud Wt. 9.7 ppg. Viscosity: 56 Nabors 27-E (0-4-0) Weather: Temp. I1° Wind: NE 23 knots Kuparuk River Field - North Slope Borough, Alaska Milne Pt. B. No.-19 (I) CONFIDENTIAL Location: 881' FSL, 890" FWL, Sec. 18, T13N, RILE, U.M. Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 20 miles W. I. - 53.3355% AFE 10-61-1141 Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 4 miles AFE 10-61-1141 Objective: 10,508' - Kuparuk River 10-10: Drlg. f/5760' to 6071'. Mud Wt. 9.8 ppg. Viscosity: 56 Nabors 27-E (0-5-0) Weather: Temp. I1° Wind: NE 18 knots Kuparuk River Field - North Slope Borough, Alaska Milne Pt. B. No. I9 (I) CONFIDENTIAL Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 1½ miles W. I. - 53.3355% AFE 10-61-1141 Location: 881' FSL, 890' FWL, Sec. 18, T13N, RllE, U.M. Objective: 10,508' - Kuparuk River 10-11: RU & run 161 its. of 36 #/ft. K55 Butt. csg. Circ. 550 bbl. mud; pump 552 bbls. of 12.3 Permafrost type E cmt. w/5#/sk gilsonite. Pump 56 bbls. of 15.8 ppg. Class G w/3% NaC1 & I% CFR-2. Drop plug & displace w/476 bbl. mud. Full returns. CIP @ 1915 hrs. Mud Wt. 9.6 ppg. Viscosity: 42 Cum. Mud Cost: $ Nabors 27-E (0-5-0) Drilling Foreman: Brady Weather: Temp. 20° Wind: SE 18 knots Visibility: 2 miles muparu~ Kiver ~'ie±, North Slope Borough, AlasKa ,,. Milne Pt. B. No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890' 'FWL, Sec. 18, T13N, RilE, U.M. Objective: 10,508' - Kuparuk River 10-12: RIH & tag cmt. @ 6113'. Drlg. f/6113' thru FC & FS. Drlg. f/6400' to 6460'. Set test plug & attempt to test BOP. Flange leaking between shear rams & choke & kill spool. Change ring gasket! Mud Wt. 9.3 ppg. Viscosity: 38 Cum. Mud Cost: Nabors 27-E (0-7-0) Drilling Foreman: Brady Weather: Temp. 8° Wind: S 3 knots Visibility: 15 miles 10-13: Drlg. f/6460' to 7530'! Mud Wt. 9.9 ppg. Viscosity: 39 Nabors 27-E (0-8-0) Weather: Temp. 2° Wind: Calm Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 15 miles 10-14: Drlg. f/7530' to 9445'! Mud Wt. 10.3 ppg. Viscosity: 42 Nabors 27-E (0-9-0) Weather: Temp. 16° Wind: SW 18-25 knots Kuparuk River Field - North Slope Borough, Alaska Milne Pt. B. No. 19 (I) CONFIDENTIAL Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 7 miles W. I. - 53.3355% AFE 10-61-1141 Location: 881' FSL, 890' .FWL, Sec. 18, T13N, RllE, U.M. Objective: 10,508' - Kuparuk River 10-15: Drlg. f/9445' to 10,305' Mud Wt. 10.4 ppg. Viscosity: 40 Nabors 27-E (0-10-0) Weather: Temp. 9° Wind: S @ 6 knots Cum. Mud Cost: $ Drilling Foreman: Brady Visibility: 15 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 53.3355% Milne Pt. B. No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890'.FWL, Sec. 18, T13N, RllE, U.M. Objective: 10,508' - Kuparuk River 10-16: Drlg. f/10,305' to 10,660'. Circ. & condition. Mud Wt. 10.4 ppg. Viscosity: 40 Cum. Mud Cost: $ Nabors 27-E (0-11-0) Drilling Foreman: Brady Weather: Temp. 18~ Wind: NE @ 13 knots Visibility: 15 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 53.3355% Milne Pt. B No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890''FWL, Sec. 18, T13N, RilE, U.M. Objective: 10,508' - Kuparuk River 10-17: Logged out of hole w/DIL-GR-SP-C~N-L-CDL-Cal f/10,638' to 9060'; GR-DIL to 6392'. Wash & ream f/10,550' to 10,660'. Drlg. f/10,660' to 10,710'. Mud Wt. 10.4 ppg. Viscosity: 42 Cum. Mud Cost: Nabors 27-E (0-12-0) Drilling Foreman: Mountjoy Weather: Temp. 11° Wind: NE @ 11 knots Visibility: Kuparuk River Field - North Slope Borough, Alaska W.I. - 53.3355% Milne Pt. B No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890'.FWL, Sec. 18, T13N, RILE, U.M. Objective: 10,508' - Kuparuk River 10-18: Wash & ream f/9700' to 10,710'. POOH, RU & RIH w/40 its. of '7", 29# L-80 Butt. csg. Mud Wt. 10.5 ppg. Viscosity: 43 Cum. Mud Cost: $ Nabors 27-E (0-13-0) Drilling Foreman: Mountjoy Weather: Temp. 18° Wind: 5 knots Visibility: 5 Kuparuk River Field - North Slope Borough, Alaska W.I. - 53.3355% Milne Pt. B No. 19 (I) CONFIDENTIAL AFE 10-61-1141 Location: 881' FSL, 890' FWL, Sec. 18, T13N, RllE, U.M. Objective: 10,508' - Kuparuk River 10-19: RIH w/144 its. of 7", 29#, L-80 Butt. csg. & 133 its. &=7", 26#, L-80 Butt. csg.; float shoe @ 10,684'; float collar @ 10,600'. Pumped: 40 bbls. 12 ppg. Zeogel spacer; bottom plug; 300 sks. Class G cmt. w/l% CFR-2 & 0.3% Halad 24 @ 15.8 ppg.; top plug; displaced plug w/400 bbls. 10.2 ppg. NaC1-NaBr brine; bumped plug w/3000 psi. Run GR-CCl-gyro survey f/surface to 10,595'. Mud Wt. Viscosity: '~ Cum. Mud Cost: $ Nabors 27-E (0-14-0) Drilling Foreman: Mountjoy Weather: Temp. 0° Wind: WSW 15 knots Visibility: 5 miles 10-20: Perf 10,409' & 10,102'-10,119' w/12 shots/ft., 1/5" gun. RU to run 3½" tbg. PU & RIH w/316 jts. 3½", 9.2#, L-80 Butt. tbg. (2 gas lift mandrels, pkr. & SCSSV) to 10,135'. Mud Wt. 10.2 ppg. Viscosity: Cum. Mud Cost: $ Nabors 27-E (0-15-0) Drilling Foreman: Mountjoy Weather: Temp. 1° Wind: SW 8 knots Visibility: 15 miles I0-21: RIG RELEASED @ 1300 hrs. 10-20-85. Nabors 27-E (0-16-85) Drilling Foreman: Mountjoy STATE OF ALASKA - ALASK~'I L AND GAS CONSERVATION C.._ i¢IMISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE J~ 2. Name of Operator 7. Permit Number Conoco Inc. 85-230 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, Alaska 99503 50-029-21451 4. Location of well at surface 9. Unit or Lease Name 881' FSL, 890' FWL, Sec. 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 53' FSL, 3780' FEL, Sec. 12, T13N, R10E, U.M. B-19 At Total Depth 11. Field and Pool 364' FSL, 4126' FEL, Sec. 12, T13N, R10E: U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field 59' KB I ADL 47433 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10-5-85 10-17-85 10-20-85 ' N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD} 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10710' !dD 10599' (7438') YES~ NO[] 1899' feetMDI 1800'-+ 22. Type Electric or Other Logs Run DIL-GR- SP-CNL-CDL-Cal-CCL-Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED i3 ~/8;; 4~# H-40 0 108 17~ 100 cf of Perm cmt 9 5/8" 36# K-55 0 6113 14" 552 bbls. Perm E, 56 bbls Class G 7" 29# L-80 0, 10684 9.~" 300 sks Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~", 9.2#.L-83 10.1.35' 992q' 5" Hollow carrier retrievable 12 SPF ]O]qq' w/1 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10,102'-10,119' (7115'-7126' TVD) 10,390'-10,409' (7306'-7318' TVD) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . - . 30. ' GEOLOGIC MARKERS'- .. · FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 5078 3922 MA 5517 4173 NA 5896 4409 0A 6114 4546 OB 6207 4604 M. Kuparuk 10103 7116 L. Kuparuk 10388 7305 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~t~r--~?~ Title S,~'~/~/~/,~/~ / Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". · ' · SEC. 18 SEC. 19 SCALE I~ MiltS /.J.::..!,::.!" l,,,. ;'.. CONOCO MIl. NC POINT UNIT [XliTINO DEVELOPMENT I. STA'IE PLaHC CO O~tDIIVAT{~S ZONE 4. ALI. GEODETIC POSITI6NS ARC BASED Iq.A.D. 19~Y. BASED O, PROTR£CTED VALUES OF THE . 4. LC~l[l~O WITHIN SECTIOff 18 8 19, TI3 N. FIlIE,UM ,AK. LOCATION B-IS .14 I] '18 B -18 B-19 i 484 r6~' 649' ~00' 416' II0 ' 814' 882' TBO' 920' 979' 960' IO~T' IOOO' 933' 1'02' 891' ~73' 6,023,424.2~ ,023, ~40.44 ,023,013.86 023,9~.O1 OZ4, O04.84 ~,. o24..o$1.o3 PLANE tOE, nOS. EASTINGS 571,864.4T 971,9~2.42 ~ ,O~2.rr :~72,022.58 5 72, II 3 . 60 5T20083.~ 572,013.~ STluT~.46 ST I ~ 96 1 .T4 ~71.74~.~ GEOOETIC LATITUDE T0028' 29.019" N. rOe 28' 31 .ESl" ti. {'0028. 2g .688'N. ~e 2e' 30.e3~'N. TO°Z.' ;r. To° ze' ~,. T0°29' 23. 376"K m~8' ~. ?0028* 33. 127"H. THaT I AM PROI'ERLT POSITION LO,Gl ! UDE - . · 14 9024' 46. r0~" W. 14 90~4' 4~ .8~ 4"W. 149024' 41.146' W. 14 90~4° 4~. 001' .W. 149024' 39. 42 3"W. 149°24' 40.2Tg*' W. 14 9e24' 42.4T2"W. 149024' 49.280'W. 14 9° Z4'45. T25 "W. 10. 23,8~ B.T. 10. 23,85 B.T. 10.23,85 9.T. 10.23,8~ 10.11[ L,O, L,O. i i i i [f IELO BOOK 21- 81S ~1 21- 8~{ 39 39-85 39-8S $9 'B' PAD AS' BUILT WELL LOCATIOH CONOCO SCALE : I' · 400'I 2 01 3 COMHENIS · ,..': . ORIGINAL .' STATE OF ALASKA ,~-'- ~ ALASKA: "L AND GAS CONSERVATION Cc, MISSION WELL COMPLETION OR RECOMPL ..TION REPORT AND LOG ¢ 1. Status of Welt Classification of Service Well ,/ OIL E~ GAS [] SUSPENDED ~ ABANDONED !~ SERVICE [] 2. Name of Operator 7. Permit Number Conoco I'nc. 85-230 3. Address 8. APl Number 3201 C Street~ Suite 200, Anchorage, Alaska 99503 50-029-21451 4. Location of well at surface 9. Unit or Lease Name 881' FSL, 890' FWL, Sec.18, T13N, RllE, g.M. Milne Point Unit · At Top Producing Interval 10. Well Number _ 53' FSL, 3780' FEL, Sec. 12, T13N, RiOE, g. M. B-19 At Total Depth 11. Field and Pool River Field R.~_ OE U M. ~uparu~ 364' FSL, 4126' FEL, Sec. 12~ T13N~ ~ · 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 59 ' KB 'I ADL 47433 12. Date Spudded~ 0--5--85 13. Date T.D. Reached 10-- 17--8 5 14' Date C°mp" SusP' °r Aband' 115' Water Depth' if °f fsh°re [ 16' N°' °f C°mpleti°ns'~,O - 20--8 5 N/A feet MSL.1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set. 21. Thickness of Permafrost 10,710' MD 10,599' (7438') YESE~ NO I--1I 1899' feet MD + 1800' 22. Type Electric or Other Logs Run D I L-GR-S P-CNL-CDL-C a 1 -CCL-Gyr o 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE~WT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1_3 3/8" 48# H-40 0 108 17~ 100 cf of Perm cmt 9 5/8" 36#. K-55 0 6113 14" 552 bbls.Perm. E,56bbls Class G 7" i 29# L-80 0 10684 9.5" 300 sks.Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE / DEPTH SET (MD) PACKER SET (MD) 5" Hollow carrier retreivable 12 SPF 3~",9.2#,L-81 10~135' 9929' 120 degrees Phasing 10,135' w/1 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10,102' ' 10,119' (7115 '- 7126 'TVD) DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 10,390' -- 10,409' (7306' -- 7318' TVD) 27. PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. c C '":: ! ,..-D A~aska b,, ,~ ...,~, .,,..,,o. u~,',.nissi011i' Anch0ra~/e Form 1l)-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ , GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. [DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA' 5078 3922 MA' 5517 4173 NA 5896 4409 OA. 6114 4546 OB .. 6207 4604 M. :Knparuk 10103 7116 L. - Kuparuk 10388 7305 31. LIST OF ATTACHMENTS . 32. I hereby certify that the foregoing is true and correct to the best of my knowledge -/J/?/.~'~'~'f~/~'7~'i~ Supervising Signed _,.- -, .v '/~ TitleReservoir En~zineerDate 12/5/85 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all type's 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. : II~em 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 10i407 Eastman Whipstock A PETROLAN£ COMPANY REPORT of SUB-SURFACE DIREC TION~I L SURVEY CONOCQ, ~nc. COMPANY "?~ ] Number-: 1° Pad [3, ,...__, . WELL NAME Hilne Point~ North S].oee, Alaska LOCATION JOB NUMBER A!O85G04i8 TYPE OF SURVEY CV_ro ~.~]].ti--Shot _ SURVEY BY B JANN gas Cans. 0ommh~lCE DATE ] 9 .--()C.T- S 5 A1 as ka Eastman Date: Noveember 15, 1985 (907) 563-3650 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 Conoco, Inc. 3201 C Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad B, Well No: 19 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro MultiShot Date: 19-0CT-85 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: A1085G0418 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multishot survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 Copy delivered to drilling in-house distribution. B. 9 Copies noted for oil company representatives. C. 3 Copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the future. %rely ~ - District Technical Coordinator TJ/ta cc/file cc: Phil Salvador - Conoco West Coast & Alaska Division O.G. Kiel - P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco William Van Alen- Alaska Oil & Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. San Ramone Office Jim Laws - Champlin Petroleum Co. C.E. Seery, Jr. - Reading & Bates Petroleum Co. Neil Buttram - Cities Service Oil & Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide EASTMAN WHIPSTOCK. INC. R E C 0 I:'~ T.- 0 F:' '.:'.-'.; I .I IR V E Y F' O I:i'. · ';~:- I"-II'--'ERAT(3F~'. : E % .:.~. · ~.:~'.'2; T I'~ U I.~: T I.J F;; I~' ',: F:' ~':'~iEi f-'_.'.{ ..~ ~:i. '?:i .-:::i. I..,1.. F:' ]_ I... ,", :[ 'i;:' ,::.l...., ,... L-J 'T' ',' 1 '.'"; .... i. '?:!' ':i ...... .. -'.'.:!- [...I"iIC¢-~'T'T I'"il',t ',', ~',1 'r L.,*'...iF' i:",r'i I I'...~1"~l',..iOl:;~-t"H :.{:1 i'"iP't!::' iE:'-iI. ~.:,]-...r-.i .:.-7. · i~. .:..: .~.. . :?.'. .,~ ~" 'i::~. '~' DF. Cl.. T NAT ']' Cliq ,". ..?',':~':', ..x-R I'::;BT O '.::; F.' A · .~- -h:- -.,'::- F't. 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C :': CLOSURE - D'I'ST~NCE -' /:,_"9't,6,,.8c.:)' REPORT UNI'TSFeet ) DIRECTION : N 46 2? I,,,! '.E;URVE/Y C:A[..F:Ut_AT'I'ON MI:TTF'IOD ',', R,'..zd~.us o'F ,:,.~r-va.'t:ur-e :Z;URVEYOR: B ,_}At-IN ,"'- I--i .:,l_l --x t,,. ,:. r RL!N I blFOI-'RMAT I '..--.; U R V E Y T 0 Iii t.: 6; i' R 0 M U L T ! -- :-'-';I--'I 0 T CAMERA NO: 17'.:'..', 'F.."O I"~EG A/1_1 NO: I :F'4.',3., GYRO NO: :':-','.--..,'.-T,, ._lOB NO: A1C:':35C~041:3 I',.I 0 T' E: 1 <;) 6 (;) ,:]) -.. :1 <')'7 .1 ,:'.) M D A R E F' R 0 ._{ Fq r..:: 'T f-.-T._'Et :-]-; 'T A T I 0 I',.I :E: Eastman A t~'TI~ ANE C~OI~fP~NY C O N 0 (]:0 ~ :[ lxt C: ,. I'-:'A D B 1,4 E: L L: 't '!;) '.E;I.. O'T': .1. 'i.'".' l'fl .T. I_.NE F:'O I I~,i"1"~ NORTH SI..OF'E, ALA!:.-".';I<A QMS., 0 .... :I.('~F-.()C) MD Eastman ~ L__~--.~ . ~=-.:_.-_-_-..~ Whtpstock l )~ A t::ft:'TROLANE C4)MP~NY '[ Ixlr: ,, ............................. PI A R I< F!: R ................. ..... ............................ C 0 DIE ........................ .................. N'AME' MEASIJRED DEF'TH FEET ._,'d' / ,:', · C),::) 5154. C) C) 5'.:;.'. 12. C)0 :5:32'P. ()C) 5:7', 54.00 PlA MB PIC: I',IA 40 C). 00 5517 ,, 00 6:3.4. C.', 0 ._,., .:,..-,. (')(.'.) ::2:':.'-.' 6. C' 0 NB I'q C ND NIE NF.' 59:25.00 5'? 6 6. C, 0 59 F-: 4.00 /-, 0 .I ~ ("~'~ 60/.-, 6.00 OA OB B /0 B '.:.:' 5 / :::" I_ C I_1 TRI_IE V E IR"F I C A L DEF'TH F:'EET Pi t-::: R-- 19 T / K U F' -f' / M K--..1. B / M K--. 1 ]' i Id K - '.-7 B/MK-2 I._-7 L-:_:: 1_-9 T / L K- 1 i:: 9'2:.1 . 99 396, !5.04 399:..3. 10 404, 4.79 4 () 79 ,, ,:D 4. 41 C, 5.26 /.I. :l 7 ::3 ,, 4 .1. 42,,.I. 4.6 .1. 4 :Z: C) :.'.-., ,, 2':, 4. 4 ,.':.',',= ,, 7' 6 F;t..IBSE~ V E R T I C A L. DEF:'TFI FEET 40()5. '79 40:2:0.04 4 (::, 46, ,, ':::' 6 4.1. 1.4,, 4! 4 .1. :~:!::5 ,, 61 4:74'7 ,, 2'? 4. :ii: d.'P, 76 4 :.3 6 E: ,, 0 ] 4:2:'.:,:' :2: ,, :31 440'.5 ,, 14. .4424.62 445 ;.":,./-::"", 10121.00 10240. C) 0 1 C) 247.. 00 10275. C)0 10 :--: :3',B. C)0 717.: 8. 15 7:7('_)7. C)7 '72]. !. 72 72:30. :32 7:304. :30 ,. F'AGE NO. 1 R E C T A N G I_.l L A R C: 0 0 R 13 I N A T FT..5.; FEE T C L 0:5; U R E ]31 :::;'r A I',IIS: E: El I R E IS: T ICl I".1 F:' E Ii::: 'l" D M 1 :E-:45. 15 N .1. E: () 1. :.'-:: 0 W 1. 8:5:9.49 N 1, 846.51 W 1. '.--.s'2'2. :2 :--', N 1 ::2:8 .1 . .1. 4 W 1 '.:.;' 87.64 N 19 ,':'51 ,, 5'i.:'.' 200 .1.52 N 1 i..v,''.., 6.7 :.5:t4 2 C, 2 7. () 5 Iq ! '? 5:' 4, ,::,(::, W 2152 ,, 10 N 21:34. :,'?, 6 IAI 220:7.5:3 N 2 .1 ,.-Ts 2.7 :! IA1 :22 ::2: P,. 4' 0 N :22':'5: ./:: ,, 91 W 2579,:2::.7: N 44 18 W :26"-I- 1,5:':3 N 44 '.70 W 2,/.:,::: 9.55 IXl 44 2: :':.: W 2785.57 N 44 29 W 2: :E',O 6.0'2, IXl 44. :2:0 W 2:30 :::.. ,,/'., ....... ("} IXl 2:7:05:. '::, ._ '=, W '.'.-i: :2: :2: 5 . 1:3 txl '...2:2', :2'7. () 4 W 2: :2', :2', 4.5',:2: Ix! 2:7.': :2','7 ,, :2:'.=i W :2:35 O. 94 N '2:2:55 ,, ':::, 6 W 2:2:7 ::',. C):;5: N 2 :::!', :.:_': 4.0'!7.' W '::!: 4 C):2:. 51 N ::241. 1 ,. ,"I 2 ',.,,.! :24.=; :,.2 '2,'.-.~ I',.t '-:' *'~ :.7 4'7 ~:"], :24- N 24 ',T:: 7, :"i: 6 1,.,.! .,c ....... ('~ :':',,'"', N .- r::- , ·:j. '"':' i.....J · . · - - ,'L -.. ~//.) ,'.'S, , .... 422.':::2 ,, .'71 N .44 425:2.5.3 N 44 :.5: 5. ,:.:).4 t4 .4:34- 6,. '7::: N 45':' .<1, :71 W 44-52,2:__.', N 4.,':-,/:,'.--..',,',75 445z_-,, 1/_-, I',l-46,74. :2'7 W 4457. 14 IX! 4.,'S75.40 W 44-6,1. (D'7 N 467'? ,, 'ii:' 2 W 4.520.0'P N 4.74.6,. 6,:7 W 452:_::. ,_,../-'":' N .4-75o_. 4:3 W. · 1 ..... :,/.76 N 4765.9.1 1,4 4._,., ..... ,S 0 N 4:5,,:2:5:. 1 '7 W 6,4E, 5.5! N 4.,"_-, "-!:2 W /':i554.5.1 N 4,':-, 24 W :: ......... .'74 N 48, 2q. I,,~ /_-,5',E:C)./-,7 N 46 24 N 6665./'-,4 t',1 46 2.5 W / Eastman ........................ (": 0 Et E ........................ N A M E ........................... B / L.I< ..... 1 T / L K-2 B / L K -:2 B / K U F' I N T E' R V A I., F'BT'D "F.O M lEE A S U R E [) DEPTH FLEET 104 i. 2 · 00 104. 2 :::. 00 :104 E:5. ()0 1 i} 553.00 J. 06 C) 0. ()0 10710.00 R.'T' I C A L. DF.E:F"TH FEET 73'20. :'.32 '7:3:2:0.50 7:']/:,6 "7= # / ...! 7409..I..1. 74:3 C.',. 2 C) F:-; U B '.E; E A VF..RT I CAL. '0 E P'T l,..I FEET '72/.:, 1. :3:2: '7:2:'7:1. ="' . ..', (.) 7:307 "';"= · , .,. 7:2:50. 11 7:3 '7 9 ,, '2 0 7446 ,, 'F.~:?: F-:(]MF'UTAT I ON T I PIE OA"I"E C)'--..~: :3 F,: 25 1 '- - '-' ~'-' .... 5--1'41.. V-,:: · ' F' A GIE N 0: R E C T A N G U L A R C ri 0 R )'"'J I N A T E :::-.'; F'EE'F 46C.):3.C)2 N 4:341.60 W 4616,.:2:6 N 485C),7]. W 46,4.6.07 N 4 88:'::. /. :2: W 4 ./.,,:.:..', .1., 47 N 492:2.. E: 4 W 4705.'?'2 N 49.50.48 W 47/-,'2 7'F' N r-:;O1F; ':,F) W C L I"I c' II R E D I E;TAI",ICE D '[ R,..- I_.T ! CII'4 FEET D M 66:'2::3.9:3 N 4.6 :,..--: 5 W 66'.--.~6.2E: N 4-6 25 W /:, 74 c). ::.!: 5N 4 6 2 6 1,4 ,{:, 7'.:.) :]:.',. 41 N 46 '.'-i:/:., W /.':,C:::30, :30 N 46 27 W ,'.": 'i;:' ]. ,!i,, E',':T" N 4,'.':,, ) W _ Eastman Whipstock A PETF~OLANE OF'zMPANY CONOCO, "XNC'; ......... PAD B WELL, 19 ' EASTMAN WHIPSTOCK. INC. SLOT, 1 9 HOR I ZONTAL PRO'JECTI'ON ...... SCALE I IN. I l Oeo FEET DEPTH [ND I CATOR, 'T,YD ........ '. ' ' . FINAL STATION, ~ DEPTH 10710 MD. 7505.93 TVD ~x. NORTH 4762 79 WEST 5015.90 ~6 ) CLOSURE 6916.89 N 46 28 58 W CONOCO, ! NC PAD B WELL~ 19 ', ' SLOT,I9 · EASTH N WHIPSTOCKr. INC. : . ' .............. ! ............................... i* ' : 2000 4000 6000 _ BO001 1000 2000 3000 4000 5000 6OOO 7000 8000 9000 m i ( 0 2000 4000 6000 VERT I CAL SECT I ON ! 0000 I 8OOO VERTI CAE: 'PROJECTION SCALE 1 rIN. = 12000 FEET ', : ~. .. CLOSURE 6916.89 N 46 28 58. W Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · . ~'P.~OR~ W~.LL' 'N~' A~D' NUM~.~ - . Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Well History ~ Samples . . Mud Log Core Chips Cbr~ 'Descripti°n ~: ~ ', . . Incl%ua~on Sur~ey . . _ D ~ree t ~onal .Survey Drill Stem Test Reports WI, ~ .., .. , .. , ....... L. FJ. 04 Eastman 1985 (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen survey run for Conoco Inc.°n B '~%'w~~.~, Well No: /~. This is to be considered a~_~l~al letter of transmittal. The data herein, is to con~$~d strictly confidential. A copy of this letter ~..~;~~'~g sent to Conoco's represen- tatives, Mr M. Bradshaw.~~4'~' r S. Davies. Should you have any qu ions regarding this survey data, please refer all questions to CONOCO INC. Distr~ Technical Coordinator c c: M. BRAD S HAW S. DAVIES RECEIVED Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via ~A,~"~A~.A,i ~{7/~ :~ 7~ ¢~k"',.... is hereby acknowledged: QUANTITY DESCRIPTION ~tx ue-M 'B- 15 RECEIVED: DATED: Copy sent to sender YES NO : STATE OFALASKA ALASKA '-",.. AND GAS CONSERVATION C¢-'"/IISSION MONTHLY REPORT DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ , Workover operation [] 2. Name of operator 7. Permit No. Conoco tnc. 85-230 3. Address ~ 8. APl Number 3201 C Street, S.bite 200, ~n~h'orage, AK 99503 50-029-21451 4. LocaTion of We~_~ : ~ at surface / ,. ./ 881~' FSL, 890" FI~, Sec. iS, T13N, RllE, U.M. 5. Ele~rati~ ~ ~e~-"t ~J~dic~m ~.]], DF, etc_) ! ~. Lease Designation and Serial No. 59' KB I ADL 47433 9. Unit or Lease Name Milne Point Unit 10. WeAl No. B-19. 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. October , 19 85 12. De¢'~ at ~ef mon~. f~rc/je d~[¢. f~ing jo~. dir~tio~l drilling problems, spud date, remarks Spud Date: ~O-.5-85 Depth at en,d of rno~h: 10,710' MD Footage Drilled: 10,710' 13. Ca¢~ o~ J~er ru~ a~ q~J~s of ~ement, results ¢ pr~r~ t~ts Ran t61 its. :of 9 5/8", K-55, 36#, Buttress casing. Pumped 552 bbls of 12.3 ppg Permafros: Type ~ c~t. w/5~ sk gitsonite. Pu~ped 56 bbls of 15.8 ppg Class G w/3% NaC1 and i%CFR-2. Ran 317 its '7", 29#, L-80 Buttress csg., Pumped 300 sks. Class G w/l% CFR-2 & .3% Halad 24. 14. CeTJT~ ;r~rr~e a¢~t ,brief description None DIL-OR-SP-C~L-CDL-Cal from 10,638' to 9,060' GR-DIL to 6,392' CCL, gyro from surface to 10,595' RL::CEtV£D 6. DS]' ~a~'a. ~erf-orat~ng da{a, ~hows of H2S, mic, ceJlaneous data Perfed iO,&Og", 10,102' to 10,119' 17. I hereby ce.rtily that the fore(joing is true and correct to the best of my knowledge. DATE /// NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 November 15,~.1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: Monthly Report of Drilling and Workover Operations Attached for your information and file are the original and one copy of each of the required Monthly Reports of Drilling and Workover Operations conducted during October 1985. If you should have any questions, please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Administrative Manager LA/ah Enc RECEIVED i\J,:.-_)V 1 ~ Alaska Oil & Gas Cons. Cornrnissior, Artchoracn G£AR~RT INDUSTRIES, INC. Date Job Ran lO-IL,'~ ~-c~_~ Blue Line Sepia Pre-Fold Rolled Logs mai led to: ALASKA OIL AND GAS COMMISSION 3001 F'ORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ATTN: WILLIAM VAN ALEN CRRRt PRINTS HAILED FROM · DISTRIBUTED BY 2" & 5" LOGS ARE COMBINED INTO ONE PRESENTATION 2"/100' TOP DEPTH ~~(,Ln'E - _ BOll'OM DEPTH , lob ~0 lO.t,.- . lob ~O '~ ~to ~D' I. 05' 6'0 Please date and sign and return in the enclosed self-addressed envelope and return to Conoco. " ~fi NOV 0 5 I~ATED 011 & Gas Cons. O~mluMn : An~orage MEMORANL)UM State of Alaska ALAS~& t?IL AND GAS CONSERVATION COPR'[ISSION TO: Cl ,~,'~./~a/cterton DATE: October 15, ~*~ ~ F,LENO: D.~A.51 THRU: Lonnie C. S~th Co~iss ioner TELEPHONE NO: F~OM: Doug ~OS ~~ Petroie~ Inspector 1985 SUBJECT: B.O.P.E. Test Conoco MPU B-19 Well Permit No. 85-230 Kuparuk River Field Thursday, Oct~9.b. er 10, 1985: After finishing the Sohio Safety Valve ~, I traveled to Conoco's }-LPU-B-19 well to stand by for the B.O.P.E. test. Friday, October 11~ 1985: The B.O.P.E. test commenced at 2:00 am ~-~-~d Was Con6IUded' at~4--:~o am. There were no failures and I filled out an A.O.G.C.C. B.O.P.E. Inspection Report which is attached. In summary, I witnessed the successful B.O.P.E. test at Conoco's MPU B-19 well. At _acnment 02-00IA(Rev. 10;79) O&G ~4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~ k~, Ot~t~_ Well -~ .~- U '~ ~- ~q Location: Sec T ~RI~6 M ~,m/ Drilling Contractor ~) ~~ Representative Ps rmi t # ~ ~Casing Set Rig ~ ~ Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig ACCUMULATOR SYSTEM Full Charge Pressure ~20~ psig Pressure After Closure I~ OO psig 200 psig Above Precl]arge Attained: BOPE Stack Annular Preventer Pipe Rams ~ Blind Rams ~ Choke Line Valves H.C.R. Valve ~'PC Kill Line Valves Check Valve Test Pres sure min l~ sec Full Charge_ Pressure a~tt~d_~.- I min_~_~sec Controls: Master O~ Remote 0 ~ Blinds switch cover ~'~ Kelly and Floor Safety Valves Upper Kelly I ~Test Pressure Lower Kelly I ,~/Test Pressure Ball Type I ~%'Test Pressure Inside BOP I ~est Pres sure Choke Manifold No. Valves No. flanges I ~cTest Pressure AdjustaBle Chokes HydrauiCally operated choke Test Results: Failures ~1~,~ Test Time ~-~ hrs. Repair or Replacement of failed equipment to be made within. . days and Inspector/Commission office notified. Remarks: Distribution orig. - AO&GCC- cc - Operator cc - Supervisor InsPector '~~ September 25, 1985 Mr. James R. Hand Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. B-19 Conoco Inc. Permit No. 85-230 Sur. Loc. 881:FSL, 890'F%U~, Sec. 18, T13N, RllE, UM. Btmhole Loc. 5025'FNL, 3929'FEL, Sec. 12, T13N, R10E, U~4. Dear Mr. Hand: Enclosed 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 govermnental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co_mm_ission may witness testing before drilling below the shoe of the conductor pipe. V~_~y trulv~ yours, ,:-.; .- ........... Chairman of Alaska Oil and Gas Conse~ation Co~ission BY ORDER OF ~"/4E CO~ISSIOM be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 September 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-19. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, plemse call Jim Hand at 564-7640. Ve~uly yours, , Rog~J. Francis Manager - Engineering JRH/vv cc: MP B-19 Correpondence File "-' STATE OF ALASKA '--~ ALASKA O,- AND GAS CONSERVATION CON,MISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [~x STRATIGRAPHIC I_~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK. 99503 .. RECE,,,ru 4. Location of well at surface 881' FSL, 890' FWL, Sec 18, T13N, RilE, U.M. SE?2.~L:' ]985 At top of proposed producing interval 5130' FNL, 3820' FEL, Sec 12, T13N, R10E, U.M.~iaSka 011 & Cons. At total depth C0mmj 5025' FNL, 3929' FEL, Sec 12, T13N, R10E, U.M. Anollorage 5. Elevation in feet (indicate KB, DF etc.) KB 59' to MSL I 6. Lease designation and serial no. ADL 47433 9. Unit or lease name Milne Point Unit 10. Well number B No. 19 $~;ib/~Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 13. Distance arid direction from nearest town 14. Distance to nearest property or lease line 33 mi of Deadhorse miles 5346' at target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10,207' MD* (7237')TVD feet 2,560 ol 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 49.7 (see 20AAC25.035(c) (2) Amount $200,000.00 15. Distance to nearest drilling or completed well B-12 ]_20 feet 18. Approximate spud date 9127185 3100 psig@80°F Surface ~o~ psig@ ~ ft, TD (TVD) - ,,,,,v 72.,~, 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER Hole Casing Weight Grade 17~"1 13 318" 48 I~-"~ 12~ 9 5/8- ~3'--'Z--- ~:-55~ 22. Describe proposed program: ~)~ 1~, Conoco Inc. proposes drilling the Coupling Length , PELP 80' . BTRS I 6340' BTRS I 10172' SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD MD BOTTOM TVD (include stage data) 35' . I 35' J 35' I 35' 35 ~ 35 I 115' I llS' 6375' ! 4760' L0207 ' 7237' +180 sks Perm Cmt · 10m cf Cmt ±1567 sks Prmfrst "E" ±275 Class G ±275 sks Class G The mud system subject well as an injection well in the Kuparuk River Field. will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.4 ppg. Mud weight at TD will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13 3/8" conductor for drilling surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is B No. 12 which is 120' from B-19 at the surface Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing of test oil and excess drilling fluids. The well will be perforated and flow tested after the rig has been released. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ f ,~.~ TITLE Engineer The space b for Commission use CONDITIONS OF APPROVAL DAT~ep~mmber 19~ 198~ Samples required Mud Icg required []YES /~O []YES [~O Permit number Approval date ~ZJo ,-- 09/25/85 Directional Survey required I APl number ~-Y, ES [] NO I 50- O'l-~- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE September 25; 1985 by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. B-19 Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM me The 13 3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Be The 9 5/8" surface casing will be cemented with ±1567 sacks of permafrost cement followed by ±275 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±275 sacks of Class "G" cement pumped around the casing shoe (estimated ±1193' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type "C"j cement followed by ±60 barrels of Arctic Pack pumped down the 7" X 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates,b ~ sequences. Estimated o 4500' - TD Predominantly shale until the Kuparuk Sands - at _+6900 subsea TVD. expected ,,e III. FORMATION EVALUATION me Wireline logs for the 8½" hole (from T.D. to ±1000' above the Kuparuk interval) will include: Dual Induction log; Spheri- cally Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. A low solids non-dispersed gel/water mud system will be used from I000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 6400'-T.D. Ve DIRECTION PROGRAM The B-19 well will be drilled to a proposed KOP of 500', then build angle in a north 44° west direction. The closest that the B-19 will come to another wellbore is at the surface, where the proposed B-19 will be 120' from the existing B-12 well. Caution will be taken and an MWD tool will be run while drilling for surveying purposes. Final hole angle will be 49.7°. The proposed depth is an estimate only.__If actual depth exceeds the permit depth by over 300', a Sundry Notice will be submitted. J. R. Hand Engineer RECEIVED Alaska Oil & Gas Cons. Commission Anchorage PAD B. WELL NO' MILNE PT.. NORTH 1 9 P~OPOSED SLOF, ALASKA EASTMAN WHIPSTOCK. INC. 0 SURFACE 1 0OO 2OOO KOP TVD=500 Ti'ID=500 DEP=O 10 15 20 25 3O 35 BUILD 2.5 DEO PER 100 FT EOB TVD=2249 TMD=2489 DEP=81 0 3000 4OOO 5000 9 5/8" CSO PT TVD=4760 TMD=6375 DEP=3775 6000 _ 7000 _ 8000 AVERAGE 49 DEG TARGET TVD=7109 I ! 1000 2000 ANGLE 43 HI N I I I I :3000 4000 5000 6000 VERTICAL SECT]:ON " I 7000 HOF-"ZON TAL SCALE 1 IN. PROJECTION '= 1000 FEET CONOCO, INC. PAD B, WELL NO, 19 PROPOSED MI LNE PT., NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 0 500O 4000 _ 3000 . 2000 _ 1000 _ O ,== 1 000 _ 5000 4000 :3000 I I "TENTATIVE' TD WEST-EAST 2000 I 1 000 0 1 000 I I I ........ TARGET TYD=7109 TMD=IO009 DEP-6548 NORTH 4549 WEST 4710 N RECEIVED AlasJ(a Oil & Gas Cons. Commission Anchorage 46 DEG W (TO TARGET) SURFACE LOCATION' 881' FSL. 890' FWL SEC. 18. T13N. R11E 1 400 _ 1 300_ 1 200 _ llO0_ 1000_ 900 _ 800 _ 700 _ ~00 _ 500 _ 600 I 700 I 800 I 900 I 10~0 I 1100 i 4563 4403 4237 \ \ %,4646 \ \ \ '" 3,,,469 ",1284 · ' 1093 '~ ~,98 CONOCO. INC. -~AD B, WELL NO, 19 PROPOSED MI LNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 4061 3877 (3~88 RECEIVED ~k'P 2 ,:, ],(18;5 Alaska Oil & Gas Cons. Commission Anchorage ! NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW S 1200 I I ! I b I I i ~ 6 A I A A AAA ~ A ...... 1 40, 130~ 120( 110( 1 00( 9OO 800 70O 60O 500 ii i ~ FROM MUD PUMP KILL MANIFOLD. FROM REMOTE HIGH ~ ~ ~ REMOTE PRESSURE GASE SENSOR PRESSURE PUMP --'"' ~----4J.I ~ NOTE: ~ HYDRAULIC CONTROLLED REMOTE OPERATED I. H'fDRAULIC CONTROL SYSTEM FOR BOP STACK 8 CHOKE MANIFOLD TO INCLUDE (5) STATION CONTROL MANIFOLD LOCATED REMOTELY WITH 3000 PSI ACCUMULATOR 8 \/ 160 GAL. RESERVOIR 8 AUX. ENERGY SOURCE. {5) STA. CONTROL MANIFOLD PLUS V~RIABLE CHOKE / \ CONTROL TO 8E LOCATED ON RIG FLOOR. /~ DRILLING Z KILL 8 CHOKE MANIFOLDS TO MEET AP! RP53 CL..(~ SPOOL 5M STDS. ~,. KILL MANIFOLD SIZE - RATING 2" - 5000 I~ 4. CHOKE MANIFOLD SIZE - RATING 3"- 5000 HYDRAULIC CONTROLLED '- ~.__R EMOTE OPERATED ' ~ ~~..~_~1T~)REMOTE PRESSURE GAGE SENSOR -, CHOKE ~UK~rAB~ 1~ CA~J~rA"LE MANIFOLD SHAKER BLFFD LINE TO ATMOSPHERIC .TO PiT MUD/GAS SEPARATOR RECEIVED i985 Alaska Oil & Gas C°ns' C°mmissi°n Anchorag9 ~'~~- BOP MANIFOLD LAYOUT- CONOCO, INC. I I CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ~ ~ Flow Line Fill-up Line ~ .. · ! Annular ' LPreventer . HCR ~ i ~ HCR - ~ , Valve~ , ..... , ] Valve ~ , .... orli£1ng ,, . 6" Relzef Lzne ~--J} Spool (~~y~--~ 6 Rellef Valve ,' ! 2000 psi I .' --- ~X-~ · - ~ ~ ~ Diverte= Quick .- 4 '~ Connect Assembly ° '".; o,.11 / / IiI~ o o~.-° - S~arting' · ~ '", '1 4 Head ~ I-'.': ' 'ii ',, ,.i /.' ' · ~'-- .: i / 3/0 / /... °''~ /casing /' /:. o . 1, ~elief l~nes .~o~ the drilling spool will be routed [or do~mwind di~e~sion. 2. ~¥draul~c control syste~ ~ill be ±n accordance with A~I specifications and AOGCC ~egulations. 3. Bot~ ~CR valves will open when the preventer closes, the~ either one ~¥ be closed. · Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up ~li~!FlOw Line~ ~ | ' !Preventer Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. RAM 13 5/8" - 5000 --RAM 13 5/8" - 5000 2" - 5000 Side Outlets 3" - 5000 Side Outlets 3" - 5000 Side Outlets RAM 13 5/8" - 5000 11" - 5000 - . RECEIVED 0il & Gas Co,~s, Commission Anchora.ge CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee ~> - '~ ' ('~' thru (8)...", (3) Admin,,:",,,.' ~-~.. :"~', "'::', '!'~ 9. (9 thru 12) 10. .~ ,1.:~, 11. (13 thru (22 thr~ 2.6) 13. 14. 15. 16. 17. 18. 19. 20. 21. 1. Is the permit fee attached ........................... 2. Is well to be located in a d~i~ed pool ' . 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells ....... '.''' 5. Is sufficient undedicated acreage available in this pool' :::. 6. Is well to be deviated and is wellbore plat included ... 7. Is operator the only affected party ......................... 8. Can permit be approved before ten-day wait .................. YES NO >"), . , · , · · · · · e e e ',i '"' Does operator have a bond in force ................................. Is conservation order needed a eeleeleeeeleeeeeeeeeeeeeeeeeeeeeeeeeee Is administrative approval needed ................................... Is the lease number appropriate ..................................... (~ ..... Is conductor string provided ................... ~ .................... /_~ 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 ..................... ,4f4z WillWill all surface casing protect fresh water zones ........... te~si~'~d *''''~ casing give adequate safety in collapse, burst''/eT:~: Is this well to be kicked off from an existing wellbore ...... , ...... /~Z Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ 22. 23. 24. 25. 26. 27. Is diverter system required ' Are necessary diagrams of diverter and BOP equipment attached .., .... Does BOPE have sufficient pressure rating - Test to ~5-'O~ psig ,. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: REMARKS Geology: Eng~neer in8: ,. HWK I~ LCS "/~'~' BEW f WVA ~ MTM~Z. _~z~ HJH JAL ~?'..,/~z ........ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE I Well Histo.ry 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 APPENDIXi ., No special'effort has been made to chronologically organize this category of information. .o DIRECT DIGITAL LOGGING COMPUTER PROCESSED RECEIVED NOV o 6 1985 Alaska 0it & 6as Cons, 0ommi~ion Anchorage AN A LY''~:' Compans: CONOCO., INC, Well MILNE POINT UNIT B-;9 F i m 1 d Ki_IPAR. UK DATE OF dOB: 10-16-:35 County NORTH SLOPE State ALA.SKA Count. r~ U¢'A.., Cl I ENT FORMAT DATA TAPE LOG I NFORMAT I ON STANDARD FORMAT ( L, I I. dmll No, ~ CONOCO 8t9 C, mpths: 4893, O0 t.o I 0680. O0 Name.: MILNE POINT UF.flT 8-t9 Fi m 1 d: KUPARUK DATE OF dOB: 10-16-85 [:,at.m: Time: Page: NOV_..~ 1985 46, PM MON, 1 L, I, S, TAPE RECORDS RECEIVED NOV 0 6 1985 Alaska Oil & Gas Cons, Oommisslon Anchorage ~*** REEL HEADER ~ .~ ,'~ :+: :~ :{4 :{~ :~ :+: :{4 :~ :{4 .~: :{4 .'~ :{4 :{4 Service name: &RSF01 PPe\,'iou~ reel.: Date: 85,.'1 1/04 Comments: HEADER Origin: RECORDS Reel name: 30501 0 Continuatior: ¢~: Oi Service name: &G5FO1 Previous tape Date: 85/ii/04 Comments: Origin: Tape name: .%0501 0 Continuation ~: O1 EOF FiI~ nature: ~,G5FOi , Maximum lmngt, h: 1024 HEADER RECORDS: Vmrsior, #: File tppm: LO Pr.m~,'ious f'ilm: Dar. m: I NFORMAT I ON RECORDS M N E M C 0 N T E N T S UNIT TYPE CATG SIZE CODE CN WN FN COUN STAT CTRY SECT TOWN RANG EKD EDF EGL. PD LMF DMF RUN LCC SOH IUH FL LUL EN6i WITN .DD DL TLI BLI TCS TLAB BH.T MRT MT MSS MVIS RM ,RMF MFST MFSS RMC MCST MCSS CONOCO, iNC ................. MILNE POINT UNIT 8-19 ................ KUPARUK DATE OF JOB: 10-i6-85 ................ NORTH SLOPE .................................... ALASKA .................................... USA .................................... i :3bi ..................................................... iiE ..................................................... 59.000 .................................................. FT 58 . OOO .................................................. FT 24. 000 .................................................. FT KB .................. 30501F~ .......... 7612 ......... NORTH SL. OP~ NORTH SLOPE HUPP BENDA 1 0638,0 O 0 , ~06~4, O00 4892 , 080 , . ~ 06~4,000 , 5.200 ..... ~ ,~70 .... ~64,0.'00, . . ~ 64,000, , , DISPERSED FLOWL I NE .40, O 0 O 2. ~9.0 ........ ~ ,980 ........ 58, O 00 ....... MEASURED , 2 , 690 58 . ~00 MEASURED FT FT FT FT HR HR DEGF DEGF CP OHMM OHMM DEGF OHMM DEGF COblMEi,iT RECORDS :m:m Thi_~ LiS tape was writ. tmn by Gmmrhmrt indostrims Wirmlinm Smrs~icms, ~ All curvm and tool ~nm~onics usmd arm t. hosm which ~ost closmly match · :~ Gmarhart cu;~vm and tool mnmmonics, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEH SERVICE UNIT DEPTH FEET DEPT FT TEN MERGE MV TENS MERGE NV SP MERGE AP1 SP MERGE AP1 GR MERGE GAPI GR MERGE GAPI ILD MERGE OHMM ILD MERGE OHMM ILM MERGE OHMM ILM MERGE OHMM LL3 MERGE OHMM LLS MERGE OHMM ClLD COMPUTED MMHO CILD COMPUT MMHO DATA ~:+:* :~ ENTRY BLU_.K~ .* :~. ~-* E N T R Y FORMAT oPEC I F I CAT IONS T Y F'E S I Z E C 0 [:, E 0 1 66 F' .a ,g e :¢.*** ENTRV BLOCK LEGEND **** :'i': H': :lc :lc -'~ :lc ~ :~c ~ :lc :~ .~ :~ :lc ~ .',lc ~ :~< ~ :.lc. ~< :,lc :'1< :~ ~ :lc :lc :'t:. ~ :lc TYPE DESCRIPTION 0 Terminator ( no more entries ) DATA FORMAT SPEC: I F 1 CAT 1 OHS DATUM SF'ECtFiC:ATiON 8LOC:KS -*-'~ SERVICE,. SERVICE AP1 APl AP1 AP1 FILE MNEM ID ORDER # UNIT LOG TYPE CLASS MOD ~ DEPT .7 0501 0 FT 0 0 0 TEllS MERGE S 050i 0 MV 0 0 0 SP MERGE S050i 0 APi 0 i 0 i GE MERGE 3050i 0 GAPi O 54 i i Lb HERGE 3 05 01 0 OHMM 0 1 2 0 46 i LM MERGE 3 050 i 0 OHMM 0 12 0 ,4,-i. LL3 MERGE 30501 0 OHMM 0 220 6 CiLD COMPUT 30501 0 MMHO 0 68 4.6 PRC SIZE LVL SMPL RC 4 0 1 68 4 0 I G8 4 0 1 68 4 0 I 68 4 0 i 68 PRO[:E:~S iN[)iCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 LIULIUIjl..I tJJJUUUU IjLIIJiJiJij 000000 OOOOOO O00OO0 000000 OOOOOO OOOO00 000000 000000 go0000 DAT RECORDS DEPT TENS SP GR ILD ILM LL3 CILD i 0680,000 2849,, O00 O,OOO 0,000 I ,OOO 2 366 2 5i8 lO00 OOO i 0580,000 5119, 000 63,200 83,700 034 3 04i 342 329 610 i 0480, 000 4406, 000 26,800 42,900 2.931 069 5 176 ~4i i 93 1 0380,000 5026,000 57,300 59,200 3,890 4 074 4 699 ~.':, ,." 040 I 0280,.000 46i1.000 47.100 70 100 4,217 4 236 4 477 237 137' 10i80,000 4601 , 000 54,900 63 500 5 02._-4 5 188 5 224 199 067 1 0080, 000 4645 000 62,100 93 100 2 075 2 099 2 O8O 481,948 9980,000 4387 000 57,900 :39 2 27O 2 128 2 388 440 555 9880,000 4387 000 51,80.0 96 1.00 2 606 2 661 2 612 383 707 9780,000 4894 000 64.?00 1 09 200 i 758 1 770 2 O14 568 853 96810,000 4406 000 68,700 1 04 900 2 163 2, 070 2 234 462 381 9580,000 4489 000 53,300 167 000 548 3,381 811 281 838 948:0,000 4294 000 65,4.00 127 900 i 279 1,337 1 824 781 628 9:380,000 4230,000 6.73,000 116 100 2,518 2,570 2 582 397 191 9280,000 4416,000 55,000 116 100 2,355 2.296 2 317 424 620 9t80,000 4167,000 56,600 80.500 2,133 2.123 2 46:.'.:.': 8 i 4 DATA RECORDS DEPT TENS SF' t LD i LM LL3 C I L D F'ag6 9080 000 454~ 000 54 200 94, 100 , 243 '206 3 308 ~i 9 8980 000 42?0 000 6,3 400 95,000 2 ?99 '2 767 3 206 - '-" 73 35,'" .- 8880 000 4172 000 56 ?00 97,900 597 540 3 41° 8780 OOO 4t62 000 46 '200 69.900 2 931 '2 924 '2 897 i93 8680 000 ,4660 000 8~ 900 88,000 '2 838 2:31'2 .352 371 :3580 000 4138 000 8i 100 81 lO0 2 438 2 410 '2 47'2 41 0 '204 ,_,4~0 000 3918 000 95 WOO 84 300 2 965 2 931 2 877 337 2.::, ,' 8380.000 3938.000 81 600 82 `300 3 404 3 4.67 3 365 765 '-"280 OOO 38b0 000 8180,000 38'25,000 90 84 9 O0 000 3,00 i 00 2 931 2 761 o18 667 3 034 2 673 34i 362 8080,.'000 3723, 000 81 20'0 900 2,742 2 877 364 754 798:0, '000 3703,000 78.800 78 200 ,S 3,048 ,:,,_0:000 36'16 000 7t .900 81 600 221 3.112 456 778 O, 000 .~'== ,,, ...,.,., 7, O00 84.700 89,200 2,838 2,729 2 661 352 371 7680 .80'0 ..'3430 0.00 71 900 80 900 4 3,908 3 715 247 742 758'0.,000 3469,000 76,300 76,900 3.069 ~. ,95t 325 837 [)EPT TENS SP DA GR TA RECORDS ILD ILM L L._-4 CiLD !0 7480,000 3479,000 76.4.00 100 2 93 i '2 761 · -'":" 871 7380. 000 35'31 . 000 7=,.,.._':'00 76 'BOO 2 931 2 761 341 193 7280,000 3469,000 75,200 75 OOO 3 289 3 105 '2 965 304 089 7i80,000 3479,000 71,600 76 300 3 112 3 119 30i 301 7080,000 3181.000 68,300 67 400 2 780 '2 667 2 761 359 749 6980.000 31'23.000 66,700 82 600 '2 951 2 924 3 162 ._~3u 844. S880,:000 3'089,000 72,100 84.2.00 2,992 2 754 2 692 334 195 6780 , 000 3025,000 73 . 700 82 . 2'00 2 , 506 2.371 2 296 399 025 6680,000 3118,000 64,300 79.800 3,483 .802 990 2:'2. 7 078 6580,000 2923,000 74,300 83.900 2.099 1 .977 2 080 476 ,-.1.31 6480 .000 2~° ..... , ,63,0:00 68,200 rZ,~O0 2.i93 2. 037 2 168 456 037 ~:~'~:~ FiLE TRAILER Film n~mm: &GSF01 . i'.la:...~.imum lmngth: I 024 TRAILER RECORDS Vets i on #: File t~pm: LO Nmxt ~ilm: Dar. m: ii EOF :~-** HEADER RECORDS Fiie name: ~GSFO1 ,002 Maximum length: i024 S~rvica name: Film tppm: LO Previous f'ilm: Date: P.=~g e i2 I NFORMAT ]: ON RECORD® iS biNEM CONTENTS UNiT TYPE CATG :SIZE L:Ub'k C N t,.IN FN COUN STAT CTRY SECT TOgN RANG EKB E[)F LHF DMF RUN LCC SON LUN FL LUL ENG I WiTN DD DL TLI BLI TCS TLAB Bi-IT i'iRT HT HSS H¥IS RH RHF" biFST HFSS RHC i'i C S T biCSS CONOCO, INC ................. MILNE F'OINT UI',IIT B-19 ................ i<UPARUK DATE OF JOB: i0-i6-85 ................ NORTH SLOPE .................................... ALASKA .................................... USA .................................... i 8 i i i I i i i i i i i i I ! I i i i i i i i i i i i I i i i i I i i i i i i i i i i i i i i · ! i · I i i i 1 ~TN ..................................................... tie ..................................................... ,.,~, 000 .................................................. 58. 000 .................................................. 24,000 .................................................. 305010 76i2 NORTH SLOPi~ NORTH St_OPE HUPP BENDA 106J8,000, ,, 106~,000,., ~892,000 .... 106~4,000,., 5,2:00 ....... iS, ~Z 0 ...... 164,000 ..... ~ 64,00'0 ..... DISPERSED FLOWL I NE 40,00:0 2,190 ....... t ,980 ....... 58,0'00 ...... I'iE~SURED 2 , 69.0 ....... 58 , JO.O ...... HEASURED 1111,111 0 0 40 .,S5 0 0 40 65 0 0 4 0 t£ 5 0 0 ':-' 0 65 0 0 2O 0 0 '20 0 0 2 65 0 0 ,_7 65 0 0 ,.7 6,5 FT O ._7 4 68 FT 0 3 4 68 FT 0 ,7, ,4 68 0 ~ 2 .65 0 3 2 65 0 3 '2 65 0 0 2 7- 0 0 2 79 0 0 i0 65 0 0 i0 65 0 0 20 65 0 0 20 65 O 0 ,='-' 0 65 0 0 20 65 FT 0 ~ 4 FT 0 3 4 68 FT 0 .3 4 68 FT 0 ~ 4 68 HR 0 '2 4 68 HR 0 4 4 68 DEGF 0 t 4 68 DEGF 0 1 4 68 0 2 20 65 0 2 .-'":' 0 65 CP 0 2 ,4. 6 0Ht'11"1 0 2 4 68 0 H f'l H 0 2 4 DEG'F O 2 4. 68 0 -D 1° 65 OHHH 0 2 4. 68 DEGF 0 '2 4 68 O 2 i2 65 COMMENT RECORDS $$ This LIS tape was wpitten bp Geaphapt Industpims Wir. mline S~pvices. · '~. All curve and tool mnmmonic~ used arm thosm which most closml~ match mm Gmarhmrt curvm and tool mnemonics, GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEF' TH FEET DEPT FT TEN ~ MERGE MV TENS MERGE MV GR1 MERGE GAPI GR MERGE GAPI XCAL1 MERGE INCH CALI MERGE iN FFDC 1 MERGE CPS FFDC MERGE CPS NFDCl MERGE CPS NFDC MERGE CPS RHO81 MERGE G,,"C ~ RHO8 MERGE G,.~ C :_~ DRHO~ MERGE G/CS DRHO MERGE G/CS FCNL! MERGE. CPS FCNL MERGE CPS NCNL1 MERGE · CPS NCHL MERGE CPS CE)L. 1 COMPUTED PU DPHI COMF'UT Pt] NPHSl COMPUTED SSPU NPHi COMPUT PU RAT'I COMPUTED RAT COMPUT 14 DATA FORMAT._~F'EC 1 F 1 CAT I ON'~o ~**:.~ ENTRY 8LOCKS ENTRY ~*:+:* ENTRY BLOCK LEGEND **** P-- :~ :-B :~ :~: :4~ · .~ '~ :+: .~ :.l.: :+: :+: ~ :.~ :+:. :'I.: ~ ~ ."I-: :+:. :+: :~ :4,: :+: :.I-: :~- :~ :~ TYPE DESCRIPTION 0 Terminator < no more entries ) TYPE SiZE CODE 0 1 66 15 D TR FORMAT SPEC 1 F I CRT IONS ~m:~. DATUH SPECIFICATION BLOCKS .~.m..~ SERVICE SERVICE APl AP1 AP1 APl FILE MNEM iD ORDER # UNIT LOG TYPE CLASS biO[) ~ DEPT 30501 0 FT 0 0 TENS MERGE 3 0501 0 MV 0 0 GR MERGE S 05 Oi 0 GAPi 0 54 CALI HERGE 7_-: 050i 0 IN 0 24 FFDC: blERGE ~ 05 Oi 0 CPS 0 98 NFDC: HERGE 3 050i 0 CPS O 98 RHOB biERGE 3050i 0 G/CS 0 94 DRHO f'iERGE S 05 0 i 0 G,.'C; O i O 0 FCNL biERGE S 050i 0 CPS 0 78 NC:NL MERGE 30501 0 CPS O 78 DPHi CObiF'LiT 3050i0 PLI 0 0 NPHI L:JhPUT ~050i0 PU O 122 RAT COHPUT SO5010 O 0 0 0 0 0 0 i 0 i iS 0 1 2 0 i I 0 i i 0 i Si 0 i SO 0 i 0 0 2 0 i 0 0 i P RC SiZE LVL 'SMPL RC: 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 i 4 O i 68 4 0 i 68 4 O i 68 4 O i 6 .z, 4 0 1 68 PKuL:~'._~ iN[.,iCATnRS 16 DATA RECORDS D E P T F C N L TENS N C N L [:, P H t C:A L I N F' H i F F [:, C RAT N F D C R ta 0 8 D E' H .3 i7' i C S80, 000 0, 000 2:849, 000 O, 000 0,000 t 60,606 0, 000 '~, ,'" b 4 0 000 ri 000 0, 00 0 't 05L=;O,O00 73, 000 51 i 9, 000 I 96,400 83,700 15,697 9, O 4 0 4i ,620 467,500 2,685 593 90 0 · 2:39 i , 0 99. i 0480, 000 i 29,200 44n6, 000 270,400 42,9 0 L; 2:3,636 8 , 600 28, i 70 54 0,5 00 i, 999 557 80a '2 26.0 , 025 i 0380, 000 i 39, :3 00 50 2 6, 000 2 79.700 59,200 14,606 L .~ 0 27,340 440,6130 2. 026 560 1 00 2 409 · 051 i02:=:0,000 't 15,300 ,46i 1,000 '~ ~"~ 500 7'0,100 t4 i~'" 9, 170 3 0,94 0 410,i00 2 i '.._~ 5":' 9 000 2 416 030 't O. I ,_,°0 , 000 93,800 .4601, 000 226,500 6.3,500 i i~,~ ,,. ~,,. t..' 9,4'B 0 ,~:9, ,':~0 548 1 00 2 365 1355 i 008 0, 000 79,700 ,464 ~:: ,..,, 000 ,~02, 000 9.3, i 00 1 5,758 .;... ti) S8,020 4.="9 900 2,569 544. 300 2 ,.90 055 998 0, 000 83 PO0 4 ,.. o 7, 000 200, 000 89, 1 O0 i 9,576 9,860 :214,9 4 () ,., 3 0, 000 ..,~ ,-~ ,,.,b'8 ," 00 9880, .000 t: ,;..~ ~. , 900 ,4 .J._ P, 000 200, 000 96, I O0 i 2,485 0,340 I , 72 0 4:02,800 2,358 ~- ..... O0 .J ,_~ 4 ," 2 444 9 780, 000 ~, .:, 00 ,4 ,:, ~.~ 4, 000 18'9 = , ~.,00 1 09,200 ,~, 606 8,8 O0 46, :370 4.92,200 ,~ 8L~, =',~,.-, ."~ 9 000 2,7-`.. '7' · - 003 9680,000 62,800 44 06, 000 186,4.00 1 '04,900 20, 06t 2,060 ~'-] 9 ;'" .... ::, 4 0 4 R 8,900 2,669 54.0,::."' O0 2 .S i 9 02S . ,.,~ u 000 70,800 4489,000 20 1,900 16F, 000 I4,909 9,270 4..'~, ._', 90 428,7' 00 2 . 7 'i 6 600 ;2 ,404 0 28 DATA RECORD DEPT F C I',1 I_ T E N S !,I C N I... GR DF'HI CALl NF'H I FFDC F..:A T NFDC RHO8 D R H 0 9 .'i. 80, 000 79,700 4.'2'94., O00 207, i O0 27,900 i7.5i5 9,360 41 ,8i0 43 9,3 00 .% · -' , 638 545, i 00 '=..', ._ b t · 0,33 93:30. 000 96.9 00 4230, 000 2.'3',5,3 00 1i6,100 il,5i5 9, ~5~ U ."32.400 386. 200 526,700 2. 460 . 047' '9280, 000 ,-'.'7,700 4.416, 000 9i ..z: 300 1 i 6, I 0 0 15,515 I O, 01 0 .35,8.40 431 , :BOO '2,486 548,400 2. 394 . 0.78 9180, 000 98.9 00 4167. 000 '-'"~ '~ 800 80,500 i6,242 9..74.0 28,630 44 ?', 800 2,236 800 2.38'2 · 052 90qO OhO 05,200 4543,000 ~,a 500 94,100 i0,545 10,100 3 0,9'70 36;;, 000 ."% ~ ~, ..* 02 521.300 ,=.":' , 4.76 0 ~, 2 name: ,=,:t~..,F01 , 002 Ha::...'. i mum length: 1 0'24 TRA I LER RECORDS S~r. vice namm~ File t. ppe: LO Nc_:>::t. f'i 1 m: :-~* EOF '.:~'.~-'~ F I LE HE~DER -~.'~.~ File name: ~'~GSFL]I . 005 Maximum length: 1024 HEADER RECORDS ',.:ersion #: Fil~ t. ppe: LO Previous f'ilm: Date: I NFORMAT I ON RECORDS 2! Fi f..I E M C: 0 N T E N T S LILY, ! T TYPE CATG S Z ZE COC, E C: i',i WN FN COi. jN STAT CTRY SECT TOWN R A N G EKB EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL E N G ! WiTN DD DL. TL. t BLi TCS TL~B DH]' MT MSS blVIS RM RbiF blFS'r MFSS RblC MCST MCSS CONOCO, INC MILNE POINT UNIT 8-19 ................ KUPARUK DATE OF JOB: 10-i6-85 ................ NORTH SLOPE .................................... ALASKA .................................... USA .................................... 13N .................................................... i 1E .................................................... 59,000 ................................................. 58, OOO ................................................. 24-, 0-00 ................................................. MS I I i i I I I I I I i i I i I i i I I I i i i I i I i I i I i I i I i i I I i I i , i i I i i I i i t i I i i i if i t I i i 3050i Ct ............. 7612 ......... NORTH SLOPI~ NORTH SLOPE HUPP BENDA i 0638,'000 10634, 000 4892,000, i 0634,000 5,20 O .... 1 ~ -" , ~O. , , 164. 000, . 164, 000, , [) '_t; S F' Ei;i SE D FLOWL i NE 40. 000 ...... 2.I90 ....... 1 ,980 ....... 58,000 ...... MEASURED 2,690 ....... 58, ._-4,00 ...... i"IE~SURED IlIIiIIIII 0 0 4 0 65 O 0 4 0 65 0 0 4 0 65 0 O 2 0 65 0 0 2 0 65 0 O 2 0 ,::, ~ 0 0 c., 65 0 O ~.] 6,5 0 0 ,7.', 65 F T 0 3 4 68 F T 0 3 4 68 FT O ~ 4 0 3 2 65 O 3: 2 65 0 ..'. 2 ' ~ 0 O '2 79 0 0 '2 79 0 0 1 0 65 0 0 i 0 65 0 0 20 65 0 0 20 ,"~ 0 0 20 65 0 0 20 r'~.-, ._~ F T 0 3 4 6:3 FT 0 7 4 FT 0 .,3 4 68 F T 0 3 4. .68 HE: O 2 4 68 HR 0 4 4 68 DEGF 0 i 4 68 DEGF O i 4 68 0 2 2 0 65 O 2 2 0 65 CP 0 ,~ 4 68 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF' O 2 4 68 0 2 12 65 OHMM O 2 4 68 D E G F 0 2 4 E, 8 0 · '. i2 6~' COMMENT RECORDS This LIS tape was written b,.¢ Gear. hart Indust. rie~_-. Wir. el ine Services, All curve and tool mnmmonic~ u~md arm thosm which mo~t closml~ match Gear-hart curve and tool mnemonics, '~ I GEARHART TO SbHLJMSERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TEH2 MERGE MV TENS i"'IERGE MV GR2 HERGE GAPI GR MERGE GAPI FCNL2 I:IERGE CPS FCI',IL ME. RGE CPS NCNL2 MERGE CPS NCNL MERGE CPS RAT2 COMPUTED RAT COMF'UT ....... NPHS2 COMPUTED SSPU NPH! COMPUl' PU F' .-~g e 22 DATA ENTRY 8LOCKS mmmm ENTRY 0 Tmr. minator < no morro cntrims ) FORMAT oPECIFICATIONS TYPE SIZE CODE 0 1 66 2S DATA FORMAT SPEC I F I CAT IONS t'.:~:~m DHTLtbl SPECIFICATION BLOCKS m:~mm ~RVICE SERVICE MNEM ID ORDER # UNIT AP! AP1 AP1 APl FiLE LOG TYPE CLASS MOD ~ DEPT 3050i 0 FT TENS MERISE 3050i 0 MV GR MERGE 3050i 0 GAPI FCNL MERGE 30501 O' CPS t',IF:NL bIERGE 3 05 O i 0 CPS RAT C. OblPUT 305'010 NPHI COHPUT ~050i0 PU 0 0 0 0 0 0 O 0 0 2 0 54 i O '2 0 78 Si 0 2 0 78 ~0 0 '2 0 0 0 0 2 0 i22 2 0 2 PRC SIZE LVL SMPL I,( u 4 0 1 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 I 68 4 0 i 68 ~'KuuESS INDiF:ATORS 000000 000000 000000 000000 000000 000000 UUUUtlU UUtlULIU UUUUUU 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOL-IO00 000000 0001) 00 DEPT TENS GR DA F C N L TA RECORDS H C N L R~T NF'H I 6435.500 2806 000 O. 000 0,000 0 000 -999 250 9 062 6335,500 2747 000 71.~"' 00 59,700 168 000 2 9i7 65 6t0 36,800 50.400 149 500 2 97 i 65 638 6i35. .._,=00 2659 000 36.200 66.600 176 600 '2 633 ..o 21 0 ...... ,.,uO 2620 000 37,100 48. 000 168 600 2 976 61 500 5'935, ._,'='00 264'9 000 39.000 56,800 i64 000 2 821 59 02 0 o..',.- 500 2591 0.00 41 ,500 58.4.00 157.800 56 790 5735.500 257'1 000 43 40'0 "t9 ="] ,:pLO 146 = . ,..00 2,960 63 050 5635 500 c'557,000 31 400 48 = .... " · :aOO I 500 2 901 61 990 5535.500 2488,000 21.900 51.400 i70.00'0 2.7i9 54 470 5435,500 2435,000 32,80'0 51.000 147,000 2.925 64 210 5335.500 2361.00'0 29.200 51.000 157,000 2.751 ...:.:, 6 0 0 ~'~ 500 234'~ ,= 000 20 700 =' ~ · 3.3 4.00 15~.000 2 879 62.140 ~,500 2342,000 36,300 ~., ~00 1 64,700 2,813 6i, 380 5035,500 2230, 00:0 ,7.3,900 '-~-'-. 900 222,200 2 ,390 49.530 49-`= ,. ;2 .... .s.,,,..'=,,O0 18't , 000 58 900 45 900 t40 400 3 083 71 , 600 DEPT TENS GR DATA F C N L RECORDS N .. NL RAT NPH I Pag~ 26 Fii~ nm~,,m: o~kOi 003 Maximum imr, gth~ 1024 TRAILER RECORDo Vmr. sion ~: Film t?pm: LO N~xt £ i 1 m: D~te. ,' 27 EOF *** EOF
