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185-067
03 By Grace Christianson at 10:36 am, Apr 19, 2024 Abandoned 4/2/2024 JSB RBDMS JSB 050124 xGMGR29DEC2025DSR-5/6/24 Drilling Manager 04/19/24 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.19 09:55:30 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 4/15/24 SCHEMATIC Milne Point Unit Well: MPC-13 Last Completed: 2/5/2024 PTD: 185-067 TD =8,270 (MD) / TD = 7,313’(TVD) 13-3/8” Orig. KB Elev.: 52.0’/ GL Elev.: 16.2’ 7” 8 Est. TOC @ 6,900’ 9-5/8” 6 7 C-13APB1: 8014’ – 8183’Whipstock #1 set @ 8,009’ Window @ 8,014’ PBTD =7,978’ (MD) / PBTD = 7,095’(TVD) 9 Whipstock #2 set @ 7,978’ 10 5 4 3 2 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 4,779’ 7" Production 26 / L-80 / Btrc 6.151 Surface 8,236’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 3.833” Surface 7,729’ JEWELRY DETAIL No Depth Item 1 2,503’ Sta #5: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 2 3,516’ Sta #4: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 3 5,010’ Sta #3: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 4 6,308’ Sta #2: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 5 7,438’ Sta #1: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 6 7,502’ 4-1/2” Sliding Sleeve (3.813” Sealbore) 7 7,522’ 4-1/2” Gauge Carrier 8 7,581’ 7” x 4-1/2” Packer D&L Perm Hyd Packer 9 7,640’ 4-1/2” X Nipple (3.813” Sealbore) 10 7,729’ 4-1/2” WLEG PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 Sands 7,770’ 7,786’ 6,934 6,946 16 11/3/94 Open C1 Sands 7,770’ 7,786’ 6,934 6,946 16 5/85 Open B-Silt Sands 7,878’ 7,881’ 7,016 7,018 3 5/85 Open B-Silt Sands 7,890’ 7,894’ 7,025 7,028 4 5/85 Open B-Silt Sands 7,904’ 7,910’ 7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’ 8,055’ 7,100 7,149 65 11/3/94 Open A3 Sands 7,991’ 8,009’ 7,101 7,114 18 5/85 Open A2 Sands 8,021’ 8,056’ 7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC - Phase w/4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 4-1/2” Comp for CTD Prep by ASR – 2/5/2024 OPEN HOLE / CEMENT DETAIL 17-1/2” ~100 cu ft Cement 12-1/4” 1,120 sx Permafrost E, 250sx Class G 8-1/2” 310 sx Class G ACTIVITYDATE SUMMARY 2/12/2024 ***WELL S/I ON ARRIVAL*** PULL RHC @ 7667' SLM / 7640' MD 20' X 4-1/2 DUMMY WHIPSTOCK DRIFT, 1-3/4'' SAMPLE BAILER (ball), TAG @ 8098' SLM, (no recovery) ***WELL S/I ON DEPARTURE*** 2/15/2024 ***WELL SHUT IN ON ARRIVAL*** SPOT IN/RIG UP PT PCE 200LP - 3000HP PULLED GR/CCL CORRELATION PASS 8,100' - 7,400 ***WELL SHUT IN ON DEPARTURE*** Job continued on 16-Feb-2024 2/16/2024 Job continued from 15-Feb-2024 ***WELL SHUT IN ON ARRIVAL*** PT PCE 200LP - 3000HP RIH with 1 7/16" Cable Head, 1 11/16" Swivel, Titan Roller Centralizers, CCL, Baker 10 Setting Tool, 3.62" Baker Whipstock (Max OD = 3.62" , Max Lenth = 46') Whipstock Set Depth = 8,009' , CCL Offset = 13.4', CCL Stop Depth = 7,995.6' Rig Down/Move Off ***WELL SHUT IN ON DEPARTURE*** Job Complete 2/23/2024 *** WELL SHUT-IN ON ARRIVAL.*** RAN READ 40 ARM (extended reach) CALIPER AS PER PROGRAM (Good data). *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.** Daily Report of Well Operations PBU MPC-13 Whipstock Set Depth = 8,009' , CCL Offset = 13.4', CCL Stop Depth = 7,995.6 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install 4-1/2" Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,270 feet N/A feet true vertical 7,309 feet N/A feet Effective Depth measured 8,156 feet 7,581 feet true vertical 7,228 feet 6,792 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / TXP 7,729' 6,906' Packers and SSSV (type, measured and true vertical depth)7" x 4-1/2" D&L Hyd Perm N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 323-625 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 115' 0 Size 115' 4,623' 02000 0 00 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-067 50-029-21328-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025516 & ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-13 Plugs Junk measured LengthCasing Conductor 8,236' 4,779'Surface Production 13-3/8" 9-5/8" 7" 115' 4,779'3,520psi 7,240psi8,236' 7,284' Burst 1,730psi Collapse 740psi 2,020psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:37 pm, Mar 08, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.08 12:53:24 - 09'00' Taylor Wellman (2143) RBDMS JSB 031424 WCB 2024-07-09 _____________________________________________________________________________________ Revised By: TDF 3/6/2024 SCHEMATIC Milne Point Unit Well: MPC-13 Last Completed: 2/5/2024 PTD: 185-067 TD = 8,270 (MD) / TD = 7,313’(TVD) 13-3/8” Orig. KB Elev.: 35’/ GL Elev.: 17’ 7” 8 Est. TOC @ 6,900’ 9-5/8” 6 7 PBTD =8,156’ (MD) / PBTD = 7,228’(TVD) 9 KUP Sands 10 5 4 3 2 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.921 Surface 4,779’ 7" Production 26 / L-80 / Btrc 6.276 Surface 8,236’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.958” Surface 7,729’ JEWELRY DETAIL No Depth Item 1 2,503’ Sta #5: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 2 3,516’ Sta #4: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 3 5,010’ Sta #3: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 4 6,308’ Sta #2: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 5 7,438’ Sta #1: 4.5” K&B GLM – Latch BK 2 (1” Dummy) 6 7,502’ 4-1/2” Sliding Sleeve (3.813” Sealbore) 7 7,522’ 4-1/2” Gauge Carrier 8 7,581’ 7” x 4-1/2” D&L Perm Hyd. Packer- COE 7.8” f/ PIN Threads Off 9 7,640’ 4-1/2” X Nipple (3.813” Sealbore) w/ RHC Installed 10 7,690’ 4-1/2” WLEG – Btm @ 7,729 PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 Sands 7,770’ 7,786’ 6,934 6,946 16 11/3/94 Open C1 Sands 7,770’ 7,786’ 6,934 6,946 16 5/85 Open B-Silt Sands 7,878’ 7,881’ 7,016 7,018 3 5/85 Open B-Silt Sands 7,890’ 7,894’ 7,025 7,028 4 5/85 Open B-Silt Sands 7,904’ 7,910’ 7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’ 8,055’ 7,100 7,149 65 11/3/94 Open A3 Sands 7,991’ 8,009’ 7,101 7,114 18 5/85 Open A2 Sands 8,021’ 8,056’ 7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” FMC Gen 5 - Phase w/4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 4-1/2” Comp For CTD Prep by ASR – 2/5/2024 OPEN HOLE / CEMENT DETAIL 9-5/8” Cmt w/1,120 sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 8-1/2” Cmt w/ 310 sx Class G Well Name Rig API Number Well Permit Number Start Date End Date MPU C-13 ASR #1 50-029-21328-00-00 185-067 1/31/2024 2/6/2024 2/2/2024 - Friday Cont. POOH w/ ESP completion, laying dw 3-1/2" 9.2# L-80 IBT tubing F/ 4,090 Encounter over torque joints. Hammering collars of all joints. Lay down BHA - ESP assembly. Send out cable clamps. L/D pumps and motor. Observed top pump was seized & the discharge was packed off. Install wear bushing in well head and RILDS. ID - 6.250''. Load 3 1/2'' work string, and set BHA in the shed. Make up BHA #1, 7" scraper / test PKR combo. Trouble shoot elevator closing issue. Replace elevators with slip type 3-1/2" Complete Picking up BHA. P/U 4-1/4" drill collars x4. Total BHA length w/ DC - 176.51'. RIH w/ 7" scraper / test PKR combo t/ 2,958'. 1/31/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue spotting in Pipe Sheds, torque BOP bolts. Move Tiger tank into position and route line from IA. Install 6" flow line and Bird Bath. OPS check BOPE systems. Bleed IAP F/ 170psi T/0psi. Monitor well. Bench test TIW. Line up to pump through BPV and landing joint to circ/kill well 11.0 ppg. Accept Rig at 08:00 1-31-24 Circ. 40 bbls dw tbg taking returns from IA to tiger tank. Close IA & bullhead 20 bbls down tubing. Blow down all lines & montior IA. Slight pressure build on IA to 40. Pump dw tubing taking returns to Tiger tank. Break down fluid lines & blow down. Remove landing joint & L/D P/U Tee bar, dry rod in CTS plug. L/D tee bar. P/U test tools. Test BOPE as per approved sundry. AOGCC wavied witness to testing. Test t/ 250 psi low & 3500 psi high f/ 5/5 charted mins. 1 F/P on kill line valve #3. 2/1/2024 - Thursday BOPE testing & accumulator draw down completed. Line up for well operations. Fill gas buster, remove testing fluid from pit #4. Change handling equip. to 3-1/2". P/U tee bar & remove BPV. M/U landing joint & TIW. BOLDS. Unseat hanger at 91K. POOH w/ ESP completion, laying dw 3-1/2" 9.2# L-80 IBT tubing F/ 7,479¿ T/ 4,090'. Pump double displacement for pipe pulled. Encounter over torque joints. Shearing make break selector pin x2. Hammering collars of all joints from 105 joints on. Land tubing hanger with 1/4 tech line, set 4" CTS BPV, nipple down BOPs and move off ASR, Nipple up adapter, terminate tech line, tested adapter to 500/5000 for 10 mins. Pull BPV with S-10 Lubricator. RIH W/ KJ, 4-1/2" BELLGUIDE, 3-1/2" BELLGUIDE & 2" JUC, SD & LATCH BALL & ROD @7,621' SLM (7,641' MD), OVERPULL, COME FREE, SEE PRESSURE DECREASE, LRS ONLINE TO F/P TBG, POOH.OOH, STANDBY FOR LRS TO FINSIH F/P. F/P COMPLETE. LRS RIG OFF WELL, SECURE WELLHEAD, BEGIN RIGGING DOWN. Cont RIH w/ 7" scraper / test PKR T/ 7,700' S/O wt = 53K P/U wt = 65K. Pump single displacement. RIH to 7,628' Set PKR w/ COE at 7,620'. Test CSH t/ 3,650 psi hold for 30 charted mins. (good test) Blow down fluid lines & POOH f/ 7,628' T/ 200' P/U wt = 6K. Pump double displacement. Change handling equip. for BHA. L/D BHA all componets intact & PKR operational. Clean & clear rig floor. Unload pipe shed of workstring, Pull wear bushing. Change handling equip. to 4-1/2". Hang sheave for tec line. Spot in tec line spooler. Rack & tally 4-1/2" completion tools & pipe. 2/3/2024 - Saturday M/U landing joint to hanger. Terminate TEC line to hanger. Perform final test on Zenith Gauge. (good test). Land hanger. Final S/O wt = 69K P/U wt = 84 K. Final depth - 7729'. RILDS with wellhead rep. Pump 100 bbls of 11.0 PPG 1% CI brine, followed by 55 bbls of diesel FP down IA. Drop ball & rod dw tubing. Pressure up to 4000 PSI to set PKR. MIT- TBG at 3900 psi for 30 charted mins. Bleed TBG dw to 1,000 psi, Pressure up IA to 3,650 psi. Hold for 30 charted mins. (Good tests) P /U T-bar & install BPV. Begin rig down. Release rig from C-13 on 12:00 2-5-2024. 2/6/2024 - Tuesday 2/4/2024 - Sunday P/U 4-1/2" completion Jewelry as per detail. WLEG, JT, X nip, JT 7 x 4-1/2" perm PKR, JT, Zenith Gauge, SS, JT, GLM. RIH w/ CTD prep completion on 4-1/2" 12.6# L-80 tubing F/ 308' T/ 7,533' Pump double displacement for pipe tripped in. Testing Zenith gauge every 1,000'. S/O wt = 69K P/U wt = 84K. 2/5/2024 - Monday Test BOPE as per approved sundry. AOGCC wavied witness to testing P/U 4-1/2" completion Jewelry as per detail. WLEG, JT, X nip, JT 7 x 4-1/2" perm PKR, JT, Zenith Gauge, SS, JT, GLM. RIH w/ CTD prep completion on 4-1/2" 12.6# L-80 tubing F/ 308' T/ 7,533' RILDS with wellhead rep Pressure up to 4000 PSI to set PKR. MIT- TBG at 3900 psi for 30 charted mins. Pull BPV with S-10 Lubricator Cont. POOH w/ ESP completion, laying dw 3-1/2" 9.2# L-80 IBT tubing F/ 4,090 Encounter over torque joints Pressure up IA to 3,650 psi. Hold for 30 charted mins. (Good tests) Land tubing hanger with 1/4 tech line, set 4" CTS BPV, nipple down BOPs and move off ASR, SD & LATCH BALL & ROD @7,621' SLM (7,641' MD), OVERPULL, COME FREE BOLDS. Unseat hanger at 91K. POOH w/ ESP completion, laying dw 3-1/2" 9.2# L-80 IBT tubing F/ 7,479¿ T/ 4,090' Land hanger 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: 3/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240307 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 13 50133205250000 203138 1/9/2024 AK E-LINE GPT-Perf BCU 19RD 50133205790100 219188 1/25/2024 AK E-LINE Perf BCU 13 50133205250000 203138 12/8/2023 AK E-LINE CMT CUT END 2-34 50029216620000 186172 10/29/2023 AK E-LINE PERF KBU 42-6 50133205460000 204209 2/19/2024 AK E-LINE Perf MPU C-13 50029213280000 18567 2/15/2024 AK E-LINE Whipstock Please include current contact information if different from above. T38604 T38604 T38605 T38606 T38607 T38608MPU C-13 50029213280000 18567 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.07 13:13:02 -09'00' 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: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -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:MPU C-13 BOPE test report Date:Friday, February 2, 2024 5:25:48 AM Attachments:MPU C-13 BOPE test report (initial ).xlsx 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* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 2/1/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11850670 Sundry #323-625 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3107 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 1 2 7/8" x 5"P H2S 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)2900 P Kill Line Valves 3 2 1/16"FP Pressure After Closure (psi)1750 P Check Valve 0NA200 psi Attained (sec)17 P BOP Misc 0NAFull Pressure Attained (sec)64 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2337 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 21 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:12 HR 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 1/28/24 19:36 Waived By Test Start Date/Time:1/31/2024 15:30 (date) (time)Witness Test Finish Date/Time:2/1/2024 3:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Sully Sullivan Hilcorp Tested w/ 3-1/2" & 4-1/2" test joints. Bottle average pre-charge = 1,035 PSI. Test #2 K3 valve fail, replaced valve & re-tested. (pass) Approved altered minimum test pressure to 3300 psi, Due to higher MASP. Actual testing done at 3,500 psi. C. Pace / M. Boord Hilcorp Alaska LLC S. Heim / R. Gallen MPU C-13 Test Pressure (psi): skans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0201_BOP_Hilcorp_ASR1_MPU_C-13 9 9 9 9 999 9 9 9 9 9 9 9 -5HJJ FP 1 gp K3 valve fail Drilling Manager 12/08/23 Monty M Myers 323-654 By Grace Christianson at 10:50 am, Dec 08, 2023 * BOPE test to 3500 psi. * Approved for variance to 20 AAC 25.112 (i) Alternate plug placement approved. MGR22DEC23 8270 SFD 10-407 SFD 12/11/2023 DSR-12/8/23 7313 *&:JLC 12/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.26 10:32:14 -09'00'12/26/23 RBDMS JSB 122623 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 7, 2023 Re: MPU C-13 Sundry Request Sundry approval is requested to set whipstock and mill window in well MPC-13 as part of the drilling and completion of the proposed MPC-13A CTD lateral. Proposed plan for C-13A Producer: Prior to drilling activities, a rig workover will pull the ESP completion and run 4-1/2" tubing. Screening will be conducted to MIT and drift for whipstock. E-line will then set a 4-1/2"x7" flow through whipstock (if not possible, will set with rig). Service Coil will mill the window if a unit is available. 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 mill a single string 3.80" window + 10' of formation. The well will kick off drilling and land in the Kuparuk A sands. The lateral will continue in the Kuparuk 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. CDR2 will then perforate the 2-7/8" liner. This completion WILL abandon the parent Kuparuk perfs. This Sundry covers plugging the existing 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)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in December 8th) x Reference MPC-13 Sundry submitted in concert with this request for full details. 1. RWO : Pull ESP completion, Run 4-1/2" tubing (Separate Sundry) 2. Slickline : Dummy WS drift, Caliper 3. E-Line : Set Whipstock 4. Fullbore : MIT-IA or MIT-T to 3000 psi 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in February 7th, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,800 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~301' (40 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2720' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” L80 liner leaving TOL at ~7750’ MD. 6. Pump primary cement job: 38 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Perforate ~1000' of 2-7/8" liner in Kuparuk A Sands 8. Freeze protect well to a min 2,200' TVDss. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) g flow through whipstock lateral wellbore SFD 20 AAC 25.036(c)(2)(A)(iv) : at least one preventer equipped with pipe rams that fit the size of the tubing, liner, or casing being used Change 3" pipe rams to VBRs. -mgr approved - mgr PTD 223-118 Sundry 323-654 Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set live GLVs, set LTP* (if necessary). 3. CT : Post rig perforate ~ 1000’ (if not done with CDR2) 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: x 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. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x 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. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x 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. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 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: x MPC is not an H2S pad. H2S reading on MPC-13: 2 ppm 10/16/2022. x Max H2S recorded on MPC: 20 ppm. x 1 fault crossings expected. x Medium lost circulation risk. Reservoir Pressure: x The reservoir pressure is expected to be 3500 psi at 7000 TVD. (9.6 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,800 psi. Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka _____________________________________________________________________________________ Revised By: TDF 3/1/2019 SCHEMATIC Milne Point Unit Well:MPC-13 Last Completed: 4/25/2015 PTD: 185-067 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8"Surface 36 / K-55 / Btrc.8.765 Surface 4,779’ 7"Production 26 / L-80 / Btrc 6.151 Surface 8,236’ TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT 2.867 Surface 7,480’ JEWELRY DETAIL No Depth Item 1 292’GLM w/ Orifice Valve 2 7,199’GLM w/ Dummy Valve 3 7,351’XN-Nipple 4 7,405’Discharge Head 5 7,406’Upper Pump: 161P11 / PMSXD AR 6 7,428’Lower Pump : 18P75 / PMSXD 7 7,435’Gas Separator: GRSFTXARH6 8 7,440’Upper Tandem Seal Assembly: GSB3DBUT SB/SB PFSA 9 7,447’Lower Tandem Seal Assembly: GSB3DBUT SB/SB PFSA 10 7,453’Motor: CL5 / MSP1-250 / 210hp / 2,145V / 59A 11 7,476’Sensor: Phoenix XT150 12 7,478’Centralizer –Bottom 7,480’ PERFORATION DETAIL Kuparuk Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status C1 Sands 7,770’7,786’6,934 6,946 16 11/3/94 Open C1 Sands 7,770’7,786’6,934 6,946 16 5/85 Open B-Silt Sands 7,878’7,881’7,016 7,018 3 5/85 Open B-Silt Sands 7,890’7,894’7,025 7,028 4 5/85 Open B-Silt Sands 7,904’7,910’7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’8,055’7,100 7,149 65 11/3/94 Open A3 Sands 7,991’8,009’7,101 7,114 18 5/85 Open A2 Sands 8,021’8,056’7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 3-1/2”” Wellhead 11” 5M FMC - Phase ( 1 & 2) w/ 3.5” FMC Tubing Hanger, 3.5” NSCT Threads, 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 OPEN HOLE / CEMENT DETAIL 9-5/8”Cmt w/1,120 sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 8-1/2”Cmt w/ 310 sx Class G _____________________________________________________________________________________ Revised By: TCS 11/6/2023 PROPOSED Milne Point Unit Well: MPC-13 Last Completed: 4/25/2015 PTD: 185-067 TD =8,270 (MD) / TD = 7,313’(TVD) 13-3/8” Orig. KB Elev.: 52.0’/ GL Elev.: 16.2’ 7” 8 Est. TOC @ 6,900’ 9-5/8” 6 7 Whipstock set @ 8,014’ PBTD = 8,014’ (MD) / PBTD = 7,122’(TVD) 9 KUP Sands 10 5 4 3 2 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 4,779’ 7" Production 26 / L-80 / Btrc 6.151 Surface 8,236’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 3.833” Surface 7,720’ JEWELRY DETAIL No Depth Item 1 ~2,500’ 4.5” GLM KBG 2 ~3,500’ 4.5” GLM KBG 3 ~5,000’ 4.5” GLM KBG 4 ~6,200’ 4.5” GLM KBG 5 ~7,500’ 4.5” GLM KBG 6 ~7,520’ 4-1/2” Sliding Sleeve (3.813” Sealbore) 7 ~7,570’ 4-1/2” Zenith Gauge Carrier 8 ~7,620’ 7” x 4-1/2” Packer 9 ~7,680’ 4-1/2” XN Nipple (2.75” Sealbore) 10 ~7,720’ 4-1/2” WLEG PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 Sands 7,770’ 7,786’ 6,934 6,946 16 11/3/94 Open C1 Sands 7,770’ 7,786’ 6,934 6,946 16 5/85 Open B-Silt Sands 7,878’ 7,881’ 7,016 7,018 3 5/85 Open B-Silt Sands 7,890’ 7,894’ 7,025 7,028 4 5/85 Open B-Silt Sands 7,904’ 7,910’ 7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’ 8,055’ 7,100 7,149 65 11/3/94 Open A3 Sands 7,991’ 8,009’ 7,101 7,114 18 5/85 Open A2 Sands 8,021’ 8,056’ 7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC - Phase w/4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 OPEN HOLE / CEMENT DETAIL 9-5/8” Cmt w/1,120 sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 8-1/2” Cmt w/ 310 sx Class G _____________________________________________________________________________________ Revised By: JNL 12/7/2023 PROPOSED Milne Point Unit Well: MPC-13A Last Completed: TBD PTD: TBD TD =11,035’(MD) / TD = 7,050’(TVD) 13-3/8” Orig. KB Elev.: 52.0’/ GL Elev.: 16.2’ 7” 8 Est. TOC @ 6,900’ 9-5/8” 6 7 3-1/2”x3-1/4” 3-1/4”x2-7/8”Whipstock / TOW @ 8,014’ PBTD =10,975’ (MD) / PBTD = 7,051’(TVD) 9 TOC / Top of Liner @ 7,700’ 10 5 4 3 2 1 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8" Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8" Surface 36 / K-55 / Btrc. 8.765 Surface 4,779’ 7" Production 26 / L-80 / Btrc 6.151 Surface 8,236’ 3-1/2” x 3-1/4” x 2-7/8” Liner 9.3 / L-80 / STL 6.6 / L-80 / TCII 6.5 / L-80 / H511 2.992 2.805 2.441 7,700’ 11,035’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 3.833” Surface 7,720’ JEWELRY DETAIL No Depth Item 1 ~2,500’ 4.5” GLM KBG 2 ~3,500’ 4.5” GLM KBG 3 ~5,000’ 4.5” GLM KBG 4 ~6,200’ 4.5” GLM KBG 5 ~7,500’ 4.5” GLM KBG 6 ~7,520’ 4-1/2” Sliding Sleeve (3.813” Sealbore) 7 ~7,570’ 4-1/2” Zenith Gauge Carrier 8 ~7,620’ 7” x 4-1/2” Packer 9 ~7,680’ 4-1/2” XN Nipple (2.75” Sealbore) 10 ~7,720’ 4-1/2” WLEG PERFORATION DETAIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status WELL INCLINATION DETAIL A KOP @ 8,014’ Max Hole Angle = 106 deg. @ 8,215’ TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC - Phase w/4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-21328-01-00 Drilled and Cased by AUD #3 - 5/9/1985 A Sidetrack – CDR2 - TBD OPEN HOLE / CEMENT DETAIL 17-1/2” ~100 cu ft Cement 12-1/4” 1120 sx Permafrost E, 250sx Class G 8-1/2” 310 sx Class G 4-1/4” 172 sx Class G 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 HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 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" Completion 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): 8,270 NA 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 Todd Sidoti 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 ADL0025516 185-067 C.O. 432E MILNE PT UNIT C-13 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21328-00-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 7,313 8,156 7,228 1,538 KUPARUK RIVER OIL N/A 115' 115' 9.23 / L-80 / IBT TVD Burst 7,480 7,240psi MD 1,730psi 3,520psi4,623'4,779' 7,284'7" 13-3/8" 9-5/8" 115' 4,779' 907-777-8443 todd.sidoti@hilcorp.com Wells Manager 12/10/2023 3-1/2" Perforation Depth MD (ft): See Schematic NA and NA NA and NA NA 8,236'8,236' See Schematic No 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 3:21 pm, Nov 17, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.11.17 12:16:34 - 09'00' Taylor Wellman (2143) 323-625 DSR-11/20/23MGR21NOV23 * BOPE test to 2500 psi. * Separate sundry to POP well on jet pump completion. 10-404 1,538 SFD SFD 11/24/2023 ADL0047434, *&:JLC 11/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 11:38:25 -09'00' RBDMS JSB 112823 RWO Well: MPU C-13 Date: 6 NOV 2023 Well Name: MPC-13 API Number: 50-029-21328-00-00 Current Status: SI ESP Producer Rig: ASR 1 Estimated Start Date: December 10, 2023 Estimated Duration: 4 days Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-067 First Call Engineer: Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2238 psi @ 7000’ TVD BHP Measured | 6.2 PPGE MPSP: 1538 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 43° @ 6100’ MD Max Dogleg: 3°/100ft @ 3100’ MD Brief Well Summary: Well MPC-13 well was drilled as a Kuparuk development well that TD’d at a depth of 8,270’ and ran and cemented 7” production casing in May 1985. The well was perforated and Frac’d in the Kuparuk A, B, & C sands and initially completed with gas lift. Gas lift was pulled and replaced with an ESP in November 1994. ESP pull and replacements were performed in 1995, 1996, 2005, 2009, 2012 and 2015. The last pump failed in 2019 and the well has been shut in since. Notes Regarding Wellbore Condition x Combo MIT-IA Passed to 2500 psi on 12/26/2012. Objective: Pull ESP and prepare well for CTD sidetrack with a 4-1/2” completion. Pre-Rig Work (No Sundry Required) Slickline, Pumping & Well Support 1. MIRU Slickline and pressure test lubricator to 250 psi low / 2000 psi high. 2. Pull DGLV from GLM at 7199’. 3. Pull SO from GLM at 292’ and replace with DGLV. 4. Run SBHPS with stops at 7405’ and 6050’. RDMO SL. 5. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 6. RD well house and flowlines. 7. MIRU pumpers and PT lines to 250 psi low / 3500 psi high. 8. Circulate at least one wellbore volume down tubing taking returns up casing to tank. 9. Confirm well is dead and FP if necessary. 10. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 11. NU BOPE house. Spot mud boat. Approved Sundry Required for Work Below RWO Well: MPU C-13 Date: 6 NOV 2023 RWO Pull Tubing 12. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 13. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with source water prior to setting CTS. 14. 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 rams on 3-1/2” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 15. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. Lubricate if pressure is expected. 16. Rig up ESP cable spooler and sheave for #1 round cable. 17. MU landing joint or spear and PU on the tubing hanger. 18. Recover the tubing hanger. a. PU weight was 125k and SO was 105k when last completed. 19. POOH and lay down the 3-1/2” tubing. Wash and all joints and send to GNI for inspection. 20. Recover the following (big clamps for #1 cable): b. 124 cannon clamps c. 6 protectolizers d. 3 flat guards Run Scraper and Test Packer 22. MU and RIH with 7” casing scraper / test packer BHA. 23. Scrape pipe from 7500’-7700’ 24. Set test packer at 7620’ and test casing to 3650 psi. 25. POOH laying down work string. Run CTD Completion 26. RIH with new 4-1/2” 12.6# L-80 completion to ~7720’. Item Notes 4-1/2” WLEG Place at ~7,720’ MD 1 Joint 4-1/2” 4-1/2” Pup 4-1/2” XN Nipple RHC Profile Installed 4-1/2” Pup 1 Joint 4-1/2” 4-1/2” Pup 7” x 4-1/2” Packer ~7,620’ MD 4-1/2” Pup Assure fluids and fluid levels balanced T x IA. -mgr RWO Well: MPU C-13 Date: 6 NOV 2023 1 Joint 4-1/2 4-1/2” Pup 4-1/2” Gauge Carrier 4-1/2” Pup 1 joint 4-1/2” 4-1/2” Pup 4-1/2” Sliding Sleeve 4-1/2” Pup Joints 4-1/2” with GLMs Space out Pups 1 Joint 4-1/2” Tubing Hanger a. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. b. Pump 50 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 casing from below the sliding sleeve to the top of the packer. c. Displace CI with 55 barrels of diesel freeze protect down the annulus. d. Consult OE/WSL on whether to FP tubing prior to RDMO. e. Drop ball and rod and pump to seat in XN nipple below the packer. Set the packer per vendor setting procedure. f. Perform MIT-T 3,000 psi, charted for 30 minutes. g. Perform MIT-IA to 3,650 psi, charted for 30 minutes. h. Set BPV. Post-Rig Procedure: Well Support 27. RD mud boat. RD BOPE house. Move to next well location. 28. RU crane. ND BOPE and NU tree. 29. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 30. RD crane. Move 500 bbl returns tank and rig mats to next well location. 31. Turn well over to production. RU well house and flowlines. Slickline 32. MIRU slickline and pressure test lubricator to 250 psi low / 2500 psi high. 33. Pull ball & rod. 34. Pull RHC profile. RDMO slickline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 3/1/2019 SCHEMATIC Milne Point Unit Well:MPC-13 Last Completed: 4/25/2015 PTD: 185-067 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8"Surface 36 / K-55 / Btrc.8.765 Surface 4,779’ 7"Production 26 / L-80 / Btrc 6.151 Surface 8,236’ TUBING DETAIL 3-1/2"Tubing 9.2 / L-80 / IBT 2.867 Surface 7,480’ JEWELRY DETAIL No Depth Item 1 292’GLM w/ Orifice Valve 2 7,199’GLM w/ Dummy Valve 3 7,351’XN-Nipple 4 7,405’Discharge Head 5 7,406’Upper Pump: 161P11 / PMSXD AR 6 7,428’Lower Pump : 18P75 / PMSXD 7 7,435’Gas Separator: GRSFTXARH6 8 7,440’Upper Tandem Seal Assembly: GSB3DBUT SB/SB PFSA 9 7,447’Lower Tandem Seal Assembly: GSB3DBUT SB/SB PFSA 10 7,453’Motor: CL5 / MSP1-250 / 210hp / 2,145V / 59A 11 7,476’Sensor: Phoenix XT150 12 7,478’Centralizer –Bottom 7,480’ PERFORATION DETAIL Kuparuk Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status C1 Sands 7,770’7,786’6,934 6,946 16 11/3/94 Open C1 Sands 7,770’7,786’6,934 6,946 16 5/85 Open B-Silt Sands 7,878’7,881’7,016 7,018 3 5/85 Open B-Silt Sands 7,890’7,894’7,025 7,028 4 5/85 Open B-Silt Sands 7,904’7,910’7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’8,055’7,100 7,149 65 11/3/94 Open A3 Sands 7,991’8,009’7,101 7,114 18 5/85 Open A2 Sands 8,021’8,056’7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 3-1/2”” Wellhead 11” 5M FMC - Phase ( 1 & 2) w/ 3.5” FMC Tubing Hanger, 3.5” NSCT Threads, 3” CIW BPV Profile GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 OPEN HOLE / CEMENT DETAIL 9-5/8”Cmt w/1,120 sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 8-1/2”Cmt w/ 310 sx Class G _____________________________________________________________________________________ Revised By: TCS 11/6/2023 PROPOSED Milne Point Unit Well:MPC-13 Last Completed: 4/25/2015 PTD: 185-067 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 13-3/8"Conductor 48 / H-40 / N/A 12.559 Surface 115' 9-5/8"Surface 36 / K-55 / Btrc.8.765 Surface 4,779’ 7"Production 26 / L-80 / Btrc 6.151 Surface 8,236’ TUBING DETAIL 4-1/2"Tubing 12.6 / L-80 / EUE 3.833”Surface 7,720’ JEWELRY DETAIL No Depth Item 1 ~2,500’4.5” GLM KBG 2 ~3,500’4.5” GLM KBG 3 ~5,000’4.5” GLM KBG 4 ~6,200’4.5” GLM KBG 5 ~7,500’4.5” GLM KBG 6 ~7,520’4-1/2” Sliding Sleeve (3.813” Sealbore) 7 ~7,570’4-1/2” Zenith Gauge Carrier 8 ~7,620’7” x 4-1/2” Packer 9 ~7,680’4-1/2” XN Nipple (2.75” Sealbore) 10 ~7,720’4-1/2” WLEG PERFORATION DETAIL Kuparuk Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status C1 Sands 7,770’7,786’6,934 6,946 16 11/3/94 Open C1 Sands 7,770’7,786’6,934 6,946 16 5/85 Open B-Silt Sands 7,878’7,881’7,016 7,018 3 5/85 Open B-Silt Sands 7,890’7,894’7,025 7,028 4 5/85 Open B-Silt Sands 7,904’7,910’7,035 7,040 6 5/85 Open A3 & A2 Sands 7,990’8,055’7,100 7,149 65 11/3/94 Open A3 Sands 7,991’8,009’7,101 7,114 18 5/85 Open A2 Sands 8,021’8,056’7,123 7,150 35 5/85 Open WELL INCLINATION DETAIL KOP @ 3,000’ Max Hole Angle = 42.75 deg. @ 6,000’ TREE & WELLHEAD Tree 5M FMC 4-1/2”” Wellhead 11” 5M FMC - Phase w/4.5” FMC Tubing Hanger GENERAL WELL INFO API: 50-029-21328-00-00 Drilled and Cased by AUD #3 - 5/9/1985 ESP RWO by Nabors 4ES – 8/24/1996 ESP RWO by Nabors 4ES – 7/10/2005 ESP RWO by Nabors 4ES – 4/21/2009 ESP RWO by Doyon 16 – 12/30/2012 ESP RWO by Nordic 3 – 4/25/2015 OPEN HOLE / CEMENT DETAIL 9-5/8”Cmt w/1,120 sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 8-1/2”Cmt w/ 310 sx Class G 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 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate Li Pull Tubing U Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate D Alter Casing❑ Change Approved Program D Plug for Redd! ❑ :rforate New Pool ❑ Repair Well ❑� Re-enter Susp Well❑ Other: ESP Change-out Q 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number: Hdcorp Alaska,LLC Development 0 Exploratory ❑ 185-067 3.Address Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dnve,Suite 1400,Anchorage AK,99503 50-029-21328-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025516 Milne Pt.Unit KR C-13 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River ON MAY 2 V c 2015 11.Present Well Condition Summary: Total Depth measured 8,270 feet Plugs measured N/A feet0GCC true vertical 7,309 feet Junk measured WA feet Effective Depth measured 8,144 feet Packer measured N/A feet true vertical 7,215 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8' 115' 115' 1,730psi 740psi Surface 4,779' 9-5/8' 4,779' 4,623' 3,520psi 2,020psi Intermediate Production 8,236' r 8,236' 7,284' 7,240psi 5,410psi Liner ANn Perforation depth Measured depth See Attached Schematic feet s�.M�NE) z;U N '� 2 U I J True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 3.5' 9.2/L-80/IBT 7,480' 6,709' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,220 5 Subsequent to operation: 244 87 994 80 - 188 14.Attachments(required per 20 MC 25.070,25.071,a 25263) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Q Service D Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ 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 0 Exempt: 315-125 Contact Chris Kanyer Email ckanver( hilcora.com Printed Name Chris Kanyer Title Operations Engineer Signature r'(X Phone 777-8377 Date 5/26/2015 Form 10-404 Revised 5/2015 4 s--62 6-(J Submit Original Only / 6/0, RBDMS\ MAY Z 7 2015 • Milne Point Unit • 14 Well: MPC 13 SCHEMATIC Last Completed: 4/25/2015 Ililcorp Alaska,LLC PTD: 185-067 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' Size Type Wt/Grade/Conn Drift ID Top Btm 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' 2t7i [ :: L• 9 5/8" Surface 36/K-55/Btrc. 8.765 Surface 4,779' 7" Production 26/L-80/Btrc 6.151 Surface 8,236' 1 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surface 7,480' JEWELRY DETAIL No Depth Item 1 292' GLM w/Orifice Valve 2 7,199' GLM w/Dummy Valve 9-5/g. 3 7,351' XN-Nipple 4 7,405' Discharge Head 5 7,406' Upper Pump:161P11/PMSXD AR 6 7,428' Lower Pump:18P75/PMSXD 7 7,435' Gas Separator:GRSFTXARH6 8 7,440' Upper Tandem Seal Assembly:GSB3DBUT SB/SB PFSA 9 7,447' Lower Tandem Seal Assembly:GSB3DBUT SB/SB PFSA 10 7,453' Motor:CL5/MSP1-250/210hp/2,145V/59A 11 7,476' Sensor:Phoenix XT150 12 7,478' Centralizer-Bottom 7,480' PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Cl Sands 7,770' 7,786' 6,934 6,946 16 11/3/94 Open Cl Sands 7,770' 7,786' 6,934 6,946 16 5/85 Open B-Silt Sands 7,878' 7,881' 7,016 7,018 3 5/85 Open B-Silt Sands 7,890' 7,894' 7,025 7,028 4 5/85 Open B-Silt Sands 7,904' 7,910' 7,035 7,040 6 5/85 Open Est gam@ A3&A2 Sands 7,990' 8,055' 7,100 7,149 65 11/3/94 Open A3 Sands 7,991' 8,009' 7,101 7,114 18 5/85 Open A2 Sands 8,021' 8,056' 7,123 7,150 35 5/85 Open 2 OPEN HOLE/CEMENT DETAIL 9-5/8" Cmt w/1,120 sx Permafrost E/250sx Class G in a 12-1/2"Hole 8-1/2" Cmt w/310 sx Class G WELL INCLINATION DETAIL KOP @ 3,000' . Max Hole Angle=42.75 deg. @ 6,000' E I 4 TREE&WELLHEAD Tree 5M FMC 3-1/2"" 5&6 11" 5M FMC-Phase(1&2)w/3.5"FMC Tubing Hanger,3.5" Wellhead NSCT Threads,3"CIW BPV Profile ' lklilii '7 I s&s GENERAL WELL INFO API:50-029-21328-00-00 Drilled and Cased by AUD#3 -5/9/1985 10 ESP RWO by Nabors 4ES-8/24/1996 ESP RWO by Nabors 4ES-7/10/2005 ESP RWO by Nabors 4ES-4/21/2009 ®11 ESP RWO by Doyon 16-12/30/2012 12 a-E1 ESP RWO by Nordic 3-4/25/2015 =1 ,KUP Sands • r A TD=8,270(MD)/TD=7,313'(ND) PBTD=8,156'(MD)/PBTD=7,228'(TVD) Created By:TDF 5/26/2015 Hilcorp Alaska, LLC ,1:1,1,,.,.,., Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP C-13 50-029-21328-00-00 185-067 4/23/2015 4/25/2015 Daily Operations: 4/22/15-Wednesday No operations to report. 4/23/15-Thursday Accepted Rig. MIRU Nordic 3 and associated equipment.Spotted kill tank and RU hardline, loaded pits and tested hardline.SITP 1,200psi,SICP 1,200psi. Bled off to Opsi. Lined up manifold to reverse circulate.Started pumping at report time. 4/24/15 Friday Continue reverse circultaing hot seawater at 4bpm,broke circulation at 125bbls,continued pumping,well on vacuum. Totals:425bbls pumped, 178bbls returned,247bbls lost. Blew lines dry,set BPV, ND tree,sealed off around hanger and penetrator, ND tree/NU BOP's and connected lines. Pulled BPV and installed TWC,filled stack and performed shell test (250-3000psi) 1 failure.Tested BOPE with AOGCC Witness,Rams 250-3000psi,Valves 250-3000psi.Annular 20-3000psi, charted for 5 mins performed gas detection and kommey drawdown. 1 F/P recorded kommey airpump.Pulled TWC, MU landing jt,backed out lock down pins, pulled 130k to unseat tubing hanger and pulled to rig floor, meg. ESP cable- good. Decompleted hanger BO/LD same, pull stand and thread cable to spooler.TOOH w/ESP and 3-1/2" IBT completion to ESP assembly at report time. Tallied stands out. 4/25/15-Saturday PJSM,continued TOOH w/ESP completion, LD 3 jts 2 indentified bad from the PDS caliper log and 1 with bad pin end. Visually inspected all other jts-good. BO/LD ESP assembly,no body wear or soilds around pump or intake. MIRU SL, PU 2" pump bailer and RIH,tagged @ 8,097'. Bailed sample and POOH,sample of formation sand and trace of proppant. All perfs opened,RDMO SL.. PU/MU and service new ESP assembly,sting new cable over sheave. Make motor connection.TIH w/completion PU XN-nipple lower and upper GLM,checked cable every 2,000'.Continue RIH with ESP completion to hanger depth. Depths are as follows: Hanger, Pup,8 jts 9.2#IBT L-80 tbg,pup,GLM @ 292',221 jts tbg, pup GLM @ 7,199', 4 jts tbg,XN Nipple@ 7,351', pup. 1jt tbg discharge head @ 7,405',gas separator @ 7,435',tandem seals @ 7,440',motor @ 7,454', EOT centralizer @ 7,479'. PU/MU tubing hanger, PU landing joint. Install penetrator. Tested cable.Cut and splice cable connector install same. Meg.check connector. Landed string SW 125K up 105k down. Run in lock down screws. ND BOP/NU tree.Orient tree.Test all breaks and void 250/5000 psi. RDMO 4/26/15-Sunday No operations to report. 4/27/15-Monday No operations to report. 4/28/15-Tuesday No operations to report. OF Tiff., • re,�\\I%%/ cv THE STATE Alaska Oil and Gas °fALAS KA Conservation Commission 333 West Seventh Avenue ' GOVERNOR BILL WALKERAnchorage, Alaska 99501-3572 OF �� NC� �%r;,i i '9', ;o1,- Main: 907.279.1433 ALAS SCAN G Fax. 907 276.7542 www.aogcc.alaska.gov Chris Kanyer Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-13 Sundry Number: 315-125 Dear Mr. Kanyer: 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, P7t/-t Cathy P. oerster Chair DATED this /7' day of March, 2015 Encl. RECEIVED • STATE OF ALASKA MAR 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well D, Change Approved Program 0 Suspend p Plug Perforations ❑ Perforate❑ Pull Tubing❑✓ • Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. ESP Change-cut wr.. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development D.. 185-067 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-21328-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.432C Will planned perforations require a spacing exception? Yes El No E ' Milne Pt. Unit KR C-13 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025516 • Milne Point Field/Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft) 43 Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8,270 X313 47309- 8,144 - 7,215 • N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 4,779' 9-5/8" 4,779' 4,623' 3,520psi 2,020psi Intermediate Production 8,236' 7" 8,236' 7,284' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 3.5" 9.2*/L-80/IBT 7,442' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A / 12.Attachments: Description Summary of Proposal ❑✓ 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: 3/18/2015 Oil E+ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG Cl 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorD.com Printed Name /Chris Kanyer aTitle Operations Engineer _ Signature ,7( Phone 777-8377 Date 3/07-1315 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - 15--- ) 2.S) Plug Integrity ❑ BOP Test I/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _ — 4- 3 COD dos` Ear l.c..-s-i- ( /A./46 P = O 7,5 Spacing Exception Required? Yes ❑ No li Subsequent Form Required: /6 -1og-i l��1 APPROVEDMM S 3 ` //--/,5"- _,w3 /� Y Approved by: -1' ,J� COMMISSIONER THE COMMISSION Date: /� 41l6- rigs-ll-/-6 Submit Form and Form 10-403(Revised 10/2012) CrRdlaGlicitiNstr 12 months from the date of approve). Attachments i P u licate 3.Fls � ,y RBDMSMSR 1 2 2015 111 Well Prognosis Well: MPC-13 Hilcorp Alaska,1.1) Date:3/5/2015 Well Name: MPC-13 API Number: 50-029-21328-00-00 Current Status: SI Producer Pad: C Pad Estimated Start Date: March 18, 2015 Rig: Nordic 3 Reg.Approval Req'd? March 17, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-067 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1550109 Current Bottom Hole Pressure: —2,238 psi @ 7,000' TVD (Last BHP measured 2/4/2015) Maximum Expected BHP: —2,238 psi @ 7,000' ND (No new perfs being added) Max. Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 81% (0.419psi/ft)with an added safety factor of 1000' ND of oil cap) (J(c-- Brief Well Summary: The Milne Point C-13 well was drilled as a Kuparuk development well that TD'd at a depth of 8,270' and ran and cemented 7" production casing in May 1985. The well was perforated and Frac'd in the Kuparuk A, B, & C sands and initially completed with gaslift. Gaslift was pulled and replaced with an ESP in November 1994. ESP /pull and replacements were performed in 1995, 1996, 2005, 2009, and 2012. A successful 7" casing pressure 1 test was performed on 12/26/2012 to 2,500psi. The current ESP failed in November 2014 and has remained shut in ever since. There are no significant scale issues suspected in this well. No subsidence issues are expected in this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP& run 2-7/8" ESP completion. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg brine. Monitor well. 3. ND tree, NU 13-3/8" BOPE with 11" spool adapter and test to 250psi low/3,000psi high,annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 7,442'to surface and lay down same. 5. RIH with 7"cleanout BHA to+/-8,056'. POOH with same. 6. MU and RIH with ESP with gas separator on 2-7/8" 8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-7,442'. Land tubing hanger. 7. ND BOP, NU and tree. 8. RDMO workover rig and equipment. Well Prognosis Well: MPC-13 HilcorD Alaska,LI) Date•3/5/2015 9. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit -14 Well: MPC-13 SCHEMATIC Last Completed: 12/30/2012 llilcorp Alaska,LLC PTD: 185-067 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' Size Type Wt/Grade/Conn Drift ID Top Btm q. o M4 f. 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' 0 24 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 4,779' a 7" Production 26/L-80/Btrc 6.151 Surface 8,236' w TUBING DETAIL 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surf 7,442' v JEWELRY DETAIL i; iNo Depth Item t 1 295' Camco 3.5"x 1"KBUG GLM r % 2 7,173' Camco 3.5"x 1"KBUG GLM 9-5/8".4 le 3 7,325' 3.5"XN-Nipple TC-II(2.750 No-go ID) 4 7,379 Discharge Head GPHVDIS 3.5"EUE 8rd 5 7,379' Tandem Pumps:SXD 18-P75&137-P17 6 7,405' Gas Separator GRSFTX AR H6 7 7,410' Upper Tandem Seal Assembly 8 7,417' Lower Tandem Seal Assembly 9 7,424' MPS-1 Motor,168HP,3460 Volt,30 amp 10 _ 7,438' Phoenix PumpMate Sensor 11 7,440 Centralizer-Bottom=7,442' PERFORATION DETAIL / Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Cl Sands 7,770' 7,786' 6,934 6,946 16 11/3/94 Open Cl Sands 7,770' _ 7,786' 6,934 6,946 16 5/85 Open B-Silt Sands 7,878' 7,881' 7,016 7,018 3 5/85 Open B-Silt Sands 7,890' _ 7,894' 7,025 7,028 4 5/85 Open B-Silt Sands 7,904' 7,910' 7,035 7,040 _ 6 5/85 Open Est.TOC@ A3&A2 Sands 7,990' 8,055' 7,100 7,149 65 11/3/94 Open 6,900 A3 Sands 7,991' 8,009' 7,101 7,114 18 5/85 Open z A2 Sands 8,021' 8,056' 7,123 7,150 35 5/85 Open I. ; OPEN HOLE/CEMENT DETAIL r' 2 9-5/8" Cmt w/1,120 sx Permafrost E/250sx Class G in a 12-1/2"Hole 1 ;.48-1/2" Cmt w/310 sx Class G WELL INCLINATION DETAIL '. KOP @ 3,000' '< �-. Max Hole Angle=42.75 deg. @ 6,000' 3 .r TREE&WELLHEAD , • Tree 5M FMC 3-1/2"" hi .�,. }+ 11" 5M FMC-Phase(1&2)w/3.5"FMC Tubing Hanger,3.5" 5 Wellhead NSCT Threads,3"CIW BPV Profile Ilit. 6 GENERAL WELL INFO ..., a ':7 API:50-029-21328-00-00 ' Ili ',;8 Drilled and Cased by AUD#3 -5/9/1985 o{ ESP RWO by Nabors 4ES-8/24/1996 h '?9 ESP RWO by Nabors 4ES-7/10/2005 ;P ESP RWO by Nabors 4ES-4/21/2009 ;a NM ,a ESP RWO by Doyon 16-12/30/2012 t 1 10 11 l-' 1}KUP Sands IA 4; TD=8,270(MD)/TD=7,313'(TVD) / PBTD=8,156'(MD)/PBTD=7,2281TVD) Created By:TDF 12/31/2014 Milne Point Unit Well: MPC-13 . 14 PROPOSED Last Completed: 12/30/2012 flacon)Alaska,LLC PTD: 185-067 CASING DETAIL Orig.KB Elev.:35'/GL Elev.:17' ki Size Type Wt/Grade/Conn Drift ID Top Btm A .y ,4 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 115' y� 9-5/8" Surface 36/K-55/Btrc. 8.765 Surface 4,779' 20 V a io 7" Production 26/L-80/Btrc 6.151 Surface 8,236' r 1 : TUBING DETAIL 4 3-1/2" Tubing 9.2/L-80/IBT 2.867 Surf ±7,442' JEWELRY DETAIL No Depth Item 1 ±295' GLM :% 2 ±7,173' GLM 9-5/8".4 3 ±7,325' XN-Nipple 4 ±7,379' Discharge Head 5 ±7,379' Tandem Pumps 6 ±7,405' Gas Separator 7 ±7,410' _ Upper Tandem Seal Assembly 8 ±7,417' _ Lower Tandem Seal Assembly 9 ±7,424' Motor 10 ±7,438' PumpMate Sensor . 11 ±7,440 Centralizer PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Cl Sands 7,770' _ 7,786' 6,934 6,946 16 11/3/94 Open Cl Sands 7,770' _ 7,786' 6,934 6,946 16 5/85 Open B-Silt Sands 7,878' 7,881' 7,016 7,018 3 5/85 Open B-Silt Sands 7,890' 7,894' 7,025 7,028 4 5/85 Open B-Silt Sands 7,904' 7,910' 7,035 7,040 6 5/85 Open • A3&A2 Sands 7,990' 8,055' 7,100 7,149 65 11/3/94 Open Est.TOC@ A3 Sands 7,991' 8,009' 7,101 7,114 18 5/85 Open 6,900 ; A2 Sands 8,021' 8,056' 7,123 7,150 35 5/85 Open y; t; OPEN HOLE/CEMENT DETAIL 2 9-5/8" Cmt w/1,120 sx Permafrost E/250sx Class G in a 12-1/2"Hole i .,e4 8-1/2" Cmt w/310 sx Class G WELL INCLINATION DETAIL w i KOP @ 3,000' c Max Hole Angle=42.75 deg. @ 6,000' t 3 1,, a TREE&WELLHEAD I 4 Tree 5M FMC 3-1/2"" 11" 5M FMC-Phase(1&2)w/3.5"FMC Tubing Hanger,3.5" 5 Wellhead NSCT Threads,3"CIW BPV Profile 6 GENERAL WELL INFO 7 API:50-029-21328-00-00 8 Drilled and Cased by AUD#3 -5/9/1985 ESP RWO by Nabors 4ES-8/24/1996 ESP RWO by Nabors 4ES-7/10/2005 ,� 9 ESP RWO by Nabors 4ES-4/21/2009 ;� ESP RWO by Doyon 16-12/30/2012 0 11 q KIP Sands 7'.a t it TD=8,270(MD)/TD=7,313'(TVD) PBTD=8,156'WO)/PBTD=7,228'(TVD) Created By:TDF 1/5/2015 - MPU BOP Stack r � O O idrAl i ii Hydril 13 5/8 5M (111 iiii i, C 13 5/8 5M ] i, l_* 2 7/8"-5-%z" variables I11PNWNW Mg Spacer spool 13 5/8 5M Al _ ____ 13 5/8 M II=1)—• Blinds 0 II I-' - ■ I • in -III ,_i ,i ., . r . 1 {'i �1' ,� Cin c I Ilk 1114 *Inr l Spacer spool 13 5/8 5M 13 5/8" 5MX11" 5M DSA ' ' Jul WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ¡8'ó p¡;,l Well History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA RECEIVED •SKA OIL AND GAS CONSERVATION •MISSION JAN 2 4 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other 12 Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 185 - 067 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 21328 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 047434 & 025516 MPC - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary: Total depth: measured 8270 feet Plugs:(measured) None feet true vertical 7309 feet Junk: (measured) None feet Effective depth: measured 8156 feet Packer: (measured) None feet true vertical 7224 feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 - 3/8" 35' - 115' 35' - 115' 1740 750 Surface 4743' 9 -5/8" 36' - 4779' 36' - 4623' 3520 2020 Intermediate Production 8202' 7" 34' - 8236' 34' - 7284' 7240 5410 Liner Perforation Depth: Measured Depth: 7770' - 8055' feet True Vertical Depth: 6934' - 7149' feet Tubing (size, grade, measured and true vertical depth): 3-1/2", 9.3# L -80 7442' 6681' Packers and SSSV (type, measured and true vertical depth): None None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: SCANNED APR 19 Z013 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 93 238 373 280 168 Subsequent to operation: 192 116 1579 300 168 14. A ttac hm e n ts : ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ❑ Stratigraphic Development ❑ Service ® Daily Report of Well Operations ® Well Schematic Diagram 16. Well Status after work: ® Oil ❑ Gas ❑ WDSPL ❑ 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: Contact: Noel Nocas, 564 -4667 N/A Email: Noel.Nocas @bp.com Printed Na e: �`�' Joe Las fk Title: Drilling Technologist ,L Signature: iN Phone: 564 -4091 Date: I /3.4115 Form 10 -404 R ' d 10/2012 MS JAN 2 8 Z013� 1/L �/ Submit Original Only 4 ) 1101 )3 l'P S • North Operation Summary OP • Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149°31'24.485'W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/22/2012 19:30 - 22:00 2.50 MOB P PRE PJSM FOR RIG MOVE WITH TOOL PUSHER, WSL AND CREW. - DSO DECLINED TO WITNESS PULLING OFF WELL. - JACKUP RIG, PULL FOWARD. - POSITION RIG MATS IN FRONT OF RIG TO MANIPULATE RIG TURN WHILE PULLING OFF WELL. 22:00 - 00:00 2.00 MOB P PRE MOVE RIG TO OTHERSIDE OF PAD. - LAY RIG MATS FOR BACKING OVER MPC -13. - LINE UP RIG TO BACK OVER WELL. 12/23/2012 00:00 01:30 1.50 MOB P PRE PJSM FOR BACKING RIG OVER WELL. - DSO DECLINED TO WITNESS BACKING OVER WELL. - ALIGN RIG ON MATS INTO POSITION TO BACK OVER WELL. - SPOT RIG ON MPC -13. - IIA= 1200 PSI. O /A= 120 PSI. 01:30 - 03:00 1.50 RIGU P PRE PJSM, SHIM AND LEVEL RIG. - R/U KILL MANIFOLD AND CIRC LINES. - FUNCTION ALARM AND SECURE BAFFLE ON FLOWBACK TANK - SPOT CUTTINGS BOX. - SET RIG EQUIPMENT. - HARDLINE CREW SPOT FLOWBACK TANK. - ACCEPT RIG ON MPC-13 AT 0300 HRS. 03:00 - 04:15 1.25 RIGU P PRE CONTINUE TO RIG UP CIRC LINES. - TAKE ON 120 DEG 9.1 PPG KWF TO PITS. - CLEAR RIG MATS FROM AROUND MPC -24A . - DSO REMOVE CHAIN AND LOCK FROM WING VALVE. 04:15 - 04:30 0.25 RIGU P PRE CONDUCT RIG EVAC DRILL, METHANE GAS IN CELLAR. - RIG CREW REPORT TO MUSTER AREA. - HARDLINE CREW RESPONDED QUICKLY TO MUSTER AREA. - LOADER OPERATOR BLOCK ENTRANCE TO PAD. - VAC TRUCK DRIVERS REMAINED AT PAD ENTRANCE. - EVERONE PRESENT AND ACCOUNTED FOR. - AAR - GOOD RESPONSE TIME, DRILLER AND FLOORHAND DONNED AIR PACKS. - FLOORHANDS LEAVING RIG GRABBED ESCAPE PACKS. - GOOD DRILL. 04:30 - 06:30 2.00 KILLW P DECOMP PJSM, FILL LINES WITH DIESEL. - PRESSURE TEST KILL MANIFOLD AND LINES TO 250/3500 PSI 5 MIN EA. CHARTED. - (1) CHECK VALVE FAILED ON KILL MANIFOLD. - INSPECTED AND CLEANED, FAILED RE TEST. Printed 1/7/2013 1:19:39PM Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149°31'24.485'W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 08:30 2.00 KILLW P DECOMP PJSM. PICK UP LUBRICATOR. - TEST LUBRICATOR 250 / 3500 5 MIN EACH GOOD TEST. 08:30 - 10:30 2.00 KILLW P DECOMP PJSM. CHANGE OUT CHECK VALVE. - PRESSURE TEST LINES & CHECK VALVE, 250 / 3500 PSI, OK. 10:30 - 11:00 0.50 KILLW P DECOMP PJSM. PULL BACK PRESSURE VALVE. - 1200 PSI SHUT IN TUBING PRESSURE, 1200 PSI SHUT IN CASING PRESSURE. 11:00 - 12:00 1.00 KILLW P DECOMP SERVICE RIG. - INSPECT AND LUBRICATE EQUIPMENT. - 0/A PRESSURE `= 120 PSI. 12:00 - 13:00 1.00 KILLW P DECOMP RIG EVACUTION DRILL, FIRE IN MOTOR ROOM. - ALL HANDS EVACUATED TO WELL SITE LEADER SHACK. - AAR, GOOD DRILL, WINDY AND LIMITED VISIBILITY CONDITIONS. 13:00 - 17:00 4.00 KILLW P DECOMP PRE KILL MEETING, STRESS GOOD COMMUNICATION. JOB ASSIGNMENTS, FLUID MANAGEMENT, VALVE ALIGNMENT. - SIGNS POSTED, MILNE PT BASE ADVISED OF GAS VENTING. - LINE UP AND BLEED GAS OFF OF VA THRU CHOKE TO FLOW BACK TANK. - BLEED FOR (5) MINUTES, BLEED TO 200 PSI, FLUID BACK. - LINE UP AND PUMP 9.1 HE ATED BRINE DOWN TUBING. (65 BBLS) P IMIP @ d I-'Sl, ICP, HOLDING 500 PSI ON CHOKE. - PUMP 65 BBLS, SHUT IN CHOKE AND BULLHEAD @ 5 BPM / 850 PSI MAX. (35 BBLS) - OPEN CHOKE AND PUMP DOWN TUBING @ 3 BPM / 325 PSI, 50 BBLS. - SHUT DOWN AND SHUT IN, STRAP AND EMPTY FLOW BACK TANK. - TUBING IS ON A SLIGHT VACUUM, 55 BBLS RECOVERED FROM FLOW BACK TANK. - RESUME PUMPING DOWN TUBING @ 3 BPM / 325 PSI. - PUMP A TOTAL OF 310 BBLS AFTER BULLHEADING. - 9.1 PPG BRINE BACK, 210 BBLS RECOVERED FROM FLOW BACK TANK. - SHUT DOWN AND SHUT IN WELL. - CALLED WTL AND NOTIFIED OF INTENT TO STOP OPERATIONS. - PHASE II IN PRUDHOE, PHASE III IN KUPARUK. WIND INCREASING. Printed 1/7/2013 1:19:39PM @ • 1, ry " • W Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149°3124.485'W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 19:30 2.50 KILLW P DECOMP MONITOR WELL FOR 30 MIN. I /A =50 PSI. TBG =50 PSI - AT WSL DIRECTION BLEED OFF TBG AND VA TO 0 PSI TO FLOW BACK TANK. - SHUT IN WELL, BLOW DOWN FLOW BACK TANK LINE. MONITOR VA AND TBG PRESSURE FOR 30 MIN. 0 PSI - TBG ON SLIGHT VAC. WELL IS DEAD. 19:30 - 21:30 2.00 WHSUR P DECOMP PJSM, R/U TO TAKE RETURNS FROM VA THROUGH CHOKE AND GAS BUSTER. - TEST LINE, OTECO CLAMP LEAKING. SWAP LINES. - PRESSURE TEST TO 250/3500 PSI 5 MIN EA. CHARTED. 21:30 - 00:00 2.50 WHSUR P DECOMP OPEN WELL, PUMP 9.1 PPG KWF 3 BPM 250 , PSI DOWN TESL WITH RETURNS OUT VA THROUGH CHOKE AND GAS BUSTER. - TOOK 7 BBLS TO FILL HOLE. PUMP 77 BBLS. - ESTABLISH LOSS RATE 60 BPH WHILE CIRC. - SHUT DOWN PUMP AND MONITOR WELL. CONTINUES ON VAC. USE CONTINUOUS HOLE FILL DOWN VA WITH 9.1 PPG BRINE 20 BPH. - LOSS TO WELL LAST 12 HRS= 173 BBLS 9.1 PPG BRINE. 12/24/2012 00:00 - 05:00 5.00 WHSUR N WAIT DECOMP WAIT ON WEATHER, PHASE CONDITIONS. - MONITOR WELL, TBG AND VA CONTINUE ON VAC. - USE CONTINUOUS HOLE FILL DOWN VA 20 BPH 9.1 PPG BRINE. 05:00 - 08:00 3.00 WHSUR N WAIT DECOMP CONTINUE TO WAIT ON WEATHER. - MILNE PT IS AT PHASE I LEVEL III - PERMISSION GRANTED FROM WTL TO PROCEED AHEAD. - FMC HAND ARRIVED AT RIG VIA CONVOY. - WELL SUPPORT WILL BE OUT AS SOON AS LEVEL II IS IN EFFECT. 08:00 - 10:00 2.00 WHSUR P DECOMP MILNE NOW AT PHASE I LEVEL II. f � - WELL SUPPORT ARRIVES, PICK UP rl LUBRICATOR. - TEST LUBRICATORta_25n i s5n0 5 MIN FAGH / CHARTED, OK. r . - SET TW�jY DOWN LUBRICATOR 10:00 - 11:30 1.50 WHSUR P DECOMP PERFORM ROLLING TEST ON TWO WAY CHECK VALVE. - PUMP @ 2 BPM / 3 1/2 BBLS PUMPED TO CATCH FLUID. - 500 PSI ACHIEVED FOR 10 MINUTES / CHARTED, PUMPED 40 BBLS AWAY. - TEST FROM ABOVE, 250 / 3500 PSI, 5 MIN / CHARTED, OK. 11:30 - 12:00 0.50 WHSUR P DECOMP PJSM. BLOW DOWN, BREAK DOWN LINES. - LOSSES TO WELL LAST (12) HRS = 148 BBLS 9.1 PPG BRINE. - 0/A = 0 PSI. Printed 1/7/2013 1:19:39PM Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149°31'24.485'W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 WHSUR P DECOMP PJSM. SUCK OUT TREE, RIG DOWN LINES ON KILL MANIFOLD. - RIG UP SECONDARY KILL LINE & CEMENT LINE F/ HOLE FILL. 13:00 - 15:00 2.00 WHSUR P DECOMP PJSM. BLEED VOID. - NIPPLE DOWN TREE, INSPECT HANGER. CHECK THREADS IN HANGER, SCREW IN CROSS OVER, OK. 15:00 - 17:30 2.50 BOPSUR P DECOMP PJSM. NIPPLE UP BOPE. - NIPPLE UP 13 5/8" 5M (4) PREVENTOR STACK. - CONTINUOUS 20 BPH HOLE FILL THROUGHOUT ALL OPERATIONS. 17:30 - 00:00 6.50 BOPSUR P DECOMP PJSM TESTING BOPS EQUIPMENT. AQGCC JEFF,LONIES WP1.VEQ �(\ WITNESS TO BOP TEST. R/U TEST EQUIPMENT. Xv - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 3 1/2" TEST JOINT TO 250/3500 PSI 5 MIN EA. TEST UPPER AND LOWER 2 7/8" X 5" VARIABLE RAMS WITH 3 1/2" AND 4" TEST JOINTS TO 250/3500 PSI 5 MIN EA. - TEST BLIND RAMS, FLOOR VALVES AND CHOKE MANIFOLD TO 250/3500 PSI 5 MIN EA. - TEST WITH FRESH WATER. - CHART RECORD ALL TESTS. - CONTINUOUS 20 BPH HOLE FILL THROUGHOUT ALL OPERATIONS. - LOSSES TO WELL LAST 12 HRS= 103 BBLS. 12/25/2012 00:00 - 00:30 0.50 BOPSUR P DECOMP PJSM FOR TESTING BOPE. - PERFORM ACCUMULATOR DRAW DOWN TEST. - USE CONTINUOUS HOLE FILL WITH 9.1 PPG BRINE. - WELL CURRENTLY TAKING 10 -12 BPH. 00:30 - 01:00 0.50 BOPSUR P DECOMP R/D TESTING EQUIPMENT. - BLOW DOWN CHOKE AND KILL LINE. - SUCK OUT STACK AND CLEAN TOP TWC. 01:00 - 02:30 1.50 BOPSUR P DECOMP PJSM WITH DSM AND CREW. - R/U OFF CENTER LUBRICATOR. - CLOSE ANNULAR. - PRESSURE TEST LUBRICATOR TO 250/3500 PSI 5 MIN EA. CHARTED. - PULL TWC. TBG ON VAC. - OPEN ANNULAR, UD LUBRICATOR. - USE CONTINUOUS HOLE FILL WITH 9.1 PPG BRINE. 02:30 - 03:00 0.50 PULL P DECOMP PJSM, HANG ESP SHEAVE. - R/U TRUNK. Printed 1/7/2013 1:19:39PM • Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- OOWTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149 °31'24.485 "W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Le Date From - To Hrs Task Code NPT vel) NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:30 1.50 PULL P DECOMP SM FOR - PJ M/U LANDING JT WITH FOSV HANGER. . - FMC BOLDS. - UNSEAT HANGER 120K, INCLUDES 40K TOP DRIVE WT. PULL HANGER TO RIG FLOOR AN _D TO BOTTOM OF 1ST JT AT CLAMP. - CUT ESP CABLE ABOVE CLAMP. RBIH WITH SLICK PIPE ACROSS BOP. L/D LANDING JT. M/U FOSV AND HEADPIN. - R/U CIRC HOSE. - CLOSE ANNULAR. 04:30 - 05:30 1.00 PULL P DECOMP CITTOMS .1 RINE 3 BPM RC 31 PSI. - TAKING RETURNS UP THROUGH PUMPING 9 CHOKE PPG B AND GAS BUSTER. - LOSS: RATE TOO HIGH, PUMPED (20) BBLS, LOST (7) © 3, BPM / 350 PSI. - CLOSE IN AND BULLHEAD @ 3 BPM / 725 PSI. (65) BBLS. 05:30 - 07:00 1.50 PULL P DECOMP PJSM. MONITOR W - FORMATION CHARGED FROM BULLHEADING. WATCH RETURNS DECLINE, 17 BBLS BACK TOTAL. - I/A ON SLIGHT VACUUM. - WATCH FOR ADDITIONAL 20 MINUTES, WELL STABLE. 07:00 - 08:00 1.00 PULL P DECOMP PJSM. BREAK OUT AND LAY DOWN TUBING HANGER. - BLOW DOWN CHOKE LINE AND CHOKE MANIFOLD. - FILL OLE DOWN VA, 7 BBLS TO FILL, TUBING FLOWING OVER. 08:00 - 09:00 1.00 PULL P DECOMP PJSM. MIX AND PUMP DRY JOB. -,PUMP (1 0) BBLS 9.4 PPG BRINE DOWN TUBING. 09:00 - 10:00 1.00 PULL P DECOMP PJSM. COMPLETION. POOH / 3 1/2" BTC ESP W - PULL FROM 7534' - 7245', STANDING BACK I TUBNG. - CONTINUOUS HOLE FILL, LOSS RATE = 10 - 12 BPH. 10:00 - 12:00 2.00 PULL P DECOMP ALLOWED CREW TO GO IN AND CALL RELATIVES. - CHRISTMAS STAND DOWN. (2 HRS). 12:00 - 12:30 0.50 PULL P DECOMP SERVICE AND INSPECT EQUIPMENT. - LUBRICATE AND MAINTAIN RIG. 12:30 - 16:30 4.00 PULL P DECOMP PJSM. CONTINUE TO POOH W /3 1/2"BTC ESP COMPLETION. - PTJLL T'ROT]f7245' TO 4442' - CONTINUOUS HOLE FILL, 10 - 12 BPH LOSS RATE. 16:30 - 18:00 1.50 PULL P DECOMP FIRE DRILL, PIPE SHED, ALL HANDS RESPONDED, FIRE SUPPRESSED. - DSO NOTIFIED, GOOD RESPONSE TIME, WELL SECURED. - ALLOW CREW TO GO TO MILNE PT BASE CAMP. - HAVE A NICE CHRISTMAS DINNER. Printed 1/7/2013 1:19:39PM y Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End • Date: 12/28/2012 X4- OOWTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149 °31'24.485 "W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 22:30 4.50 PULL P DECOMP CONTINUE TO POOH W/ 31/2" BTC ESP COMPLETION :pm ROM ' SURFACE TES BEFORE ONITOR WELL 10 URF MINU LLING 4442 BHA THRU TO BOP 22:30 00:00 1.50 PULL P DECOMP PJ, UD AND MOTOR RECOVERED 240 SM CANNON CLAMPS 3 FLAT GUARDS - 5 PROTECTOLIZERS - OA =0 PSI - 24 UR O TO W = 209 BBLS OF 9-.1 PPG HO BRINE. L SSES 12/26/2012 00:00 - 01:30 1.50 PULL P DECOMP PJSM, MAKE SAFETY AND ELL SPCC CHECKS - CONT. -LD ESP MOTOR AND PUMP ASSY - OA = 0 PSI AT 24:00 HRS 01:30 - 02:30 1.00 PULL P DECOMP RD ESP CABLE AND SPOOL INTO SPOOLING UNIT R/D ESP SHEAVE AND TRUNK 02:30 - 04:30 2.00 PULL P DECOMP MOVE UT VAC OUT SPOOLING SPOOL DRI REMOVE SPOOL FROM PAN IT UN WITH j CENTRILIFT FORK LIFT pMOVE SPOOLING UNIT OUT OF WAY TO ROVIDE ROOM FOR SWS RIG UP - KICK WHILE DRILLING DRILL, GOOD RESPONSE TIME. - WELL SECURED, ALL HANDS ON STATIONS. AAR. - STATIC LOSS RATE = 8 BPH 04:30 06:30 2.00 EVAL P DECOMP PJSM, R/U SWS S - SPOT SWS INTO LICK PLACE LINE UNIT - R/U SLICK L UNIT . INE - OA = 0 PSI @ 06:00 06:30 - 08:30 2.00 EVAL P DECOMP PJSM. R/U DUTCH RISER. - RIG UP SCHLUMBERR WIPER - PICK UP PDS LOGGING GE TOOLS. 08:30 - 09:30 1.00 EVAL P DECOMP RIH W/ PDS LOGGING TOOL. CALIPER LOG, (MEMORY), FROM 1000 '__TO ____. SURFACE„ -B POOH W/ LOGGING TOOLS. - CONTINUOUS HOLE FILL, WELL TAKING 6 - 8 PH. 09:30 - 11:00 1.50 EVAL P DECOMP PJSM. LAY DOWN LOGGING TOOLS, RIG DOWN SLICK LINE AND UD DUTCH RISER. - INSTALL WEAR RING, 7" ID. CASING P -P BLOW DOWN KILL LINE. 11:00 12:00 1.00 DECOMP JSM. BRING PACKER TO FLOOR. PICK UP HALLIBURTON 7" CHAMP PACKER. - CONTINUOUS HOLE FILL, 6 - 8 BPH LOSS RATE. - 67 BBLS 9.1 PPG BRINE LOST TO WELL LAST (12) HRS. 12:00 13:00 1.00 CASING P DECOMP SERVICE AND LUBRICATE RIG. INSPECT RIG EQUIPMENT. Printed 1/7/2013 1:19:39PM Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149 °31'24.4869 Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 16:00 3.00 CASING P DECOMP RIH WITH 7" CHAMP PACKER - RIH WITH 3 1/2" TUBING FROM DERRICK TO 4700' MD - M/U FOSV AND HEAD PIN 16:00 - 17:30 1.50 CASING P DECOMP CIRCULATE 3 BPM = 200 PSI - SET PACKER AT 47B MD COE 20K DOWN WT !� 17:30 - 19:00 1.50 CASING P DECOMP PJSM, TEST 7" CASING TO 2500 PSI �.r - R/U TEST EQUIPMENT i - PRESSURE TEST TO 2500 PSI, 30 MINUTES, C�" CHARTED�GOOD TEST - NOTIFY WTL FOR AUTHORIZATION TO PROCEED - OA = 0 PSI DURING TEST - RELEASE PACKER - MONITOR WELL FOR 10 MINUTES - STATIC LOSS RATE = 2.5 BPH - DISCUSS LOSS RATE WITH TOWN ENGINEER 19:00 - 20:00 1.00 CASING P DECOMP CBU 1X, 4 BPM = 360 PSI - LOSS RATE DURING CIRCULATION = 18 BPH - MONITOR WELL 10 MINUTES STATIC LOSS RATE AFTER CIRCULATION = 8.5 BPH 20:00 - 00:00 4.00 CASING P DECOMP PJSM, POOH WITH PACKER FROM 4700' TO SURFACE - L/D 7" CHAMP PACKER - CLEAR RIG FLOOR -OA =0 PSI - 24 HOUR FLUID LOSS = 152 BBLS 12/27/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM, MAKE SAFETY AND SPCC CHECKS - PULL WEAR RING 00:30 - 02:00 1.50 RUNCOM P RUNCMP HANG ESP SHEAVE - MOBILIZE CENTRILIFT ESP EQUIPMENT AND CLAMPS TO RIG FLOOR 02:00 - 06:00 4.00 RUNCOM P RUNCMP PJSM, CENTRILIFT EQUIPMENT AND PROCEDURES - M/U ESP MOTOR AND PUMP ASSY - STRING ESP CABLE FROM SPOOLING UNIT THRU SHEAVE TO RIG FLOOR - CONNECT ESP CABLE TO MOTOR AND PUMP ASSY, INSTALL CLAMPS - CHECK CONDUCTIVITY AND TEST ESP CABLE 06:00 - 07:30 1.50 RUNCOM P RUNCMP RIH WITH 3 1/2" 9.2# L80 IBT ESP COMPLETION - SET DOWN ON STRING, UNABLE TO PASS 261' - POOH, CALL AND DISCUSS OPTIONS WITH TOWN ENGINEERS - DETERMINE THAT OD OF THE 1 1/2" GLM'S AND ESP CABLE ARE TOO TIGHT TO PASS THRU THE 7" CASING 07:30 - 09:00 1.50 RUNCOM P RUNCMP LOAD 1" GLM'S INTO PIPE SHED - CALL OUT SWS TO DRESS GLMS WITH DUMMY AND DSOV VALVES Printed 1/7/2013 1:19:39PM ' F , ,,.. Common Well Name M -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 00WTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °2925.778 "8 Long: 0149 °31'24.485'W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 12:00 3.00 RUNCOM P •1 RUNCMP RIH WITH 3 V2" 9.2# L80 IBT ESP -- _. - FROM 106' TO 2617' K CONDUCTIVITY E V 20' - CHECK PUMP 5 C BBLS AT DUCTIV 1 BP O CLEAR ERY PM P - INSTALL CANNON CLAMPS ON EVERY JOINT 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM CHANGE SERVICE RIG, OUT INSPECT CREWS G EQUIPMENT RI 12:30 21:00 8.50 RUNCOM P RUNCMP RIH WITH RUNCOM V2" 9.2# L80 IBT ESP COMPLETION - FROM 2617' TO 7418' PUMP 5 BBLS - CHECK CONDUCTIVITY EVERY 2000' AT 1 BPM = 1430 PSI AT 7000', TO CLEAR PUMP - INSTALL CANNON CLAMPS ON EVERY JOINT 21:00 - 22:00 1.00 RUNCOM P RUNCMP M/U - M/U HANGER P P ER FMC REP. INSTALL LANDING PENETRATOR JOINT IN HANGER 22:00 00:00 2.00 RUNCOM RUNCMP TERMINATE ESP CABLE - CUT TAIL TO PREVENT SPLICE FROM LANDING ON COLLAR - TIE IN ESP CABLE TO HANGER PENETRATOR OA =0 PSI - O = BB 12/28/2012 00:00 02:00 2.00 RUNCOM P RUNCMP PJSM H , MAKE UR SPCC FLUID LOSS AND EQ UIPMENT LS CHECKS - COMPLETE ESP SPLICE CHECK CONDUCTIVITY - LAP IN ESP CABLE TO HANGER PENETRATOR 02:00 - 03:00 1.00 RUNCOM P RUNCMP LAND TUBING HANGER - PUWT = 111 K, SOWT = 103K - RUN IN LOCK DOWN SCREWS - L/D LANDING JOINT - CANNON CLAMPS = 237 - PROTECTOLIZERS = 5 - FLAT GUARDS = 3 03:00 - 05:30 2.50 WHSUR P RUNCMP INSTALL TWC PERFORM TWC ROLLING TEST FROM BELOW TO 4 BPM, 500 PSI, 10 MIN, CHARTED - PUMPED TOTAL - FORMATION CHARGED OF 58 BBLS M FRO BULLHEADING. - RETURNS DECLINE TO SLIGHT VAC, 24 WATCH BBLS BACK TOTAL MONITOR WELL 10 MINUTES - TEST TWC FROM ABOVE, 250, 3500 PSI, 5 MIN, CHARTED 05:30 - 06:30 1.00 BOPSUR P ■- POST PJSM. NIPPLE DOWN BOPS. - DISCONNECT LINES, SECURE STACK IN CELLAR. Printed 1/7/2013 1:19:39PM � f Common Well Name: MPC -13 AFE No Event Type: WORKOVER (WO) Start Date: 12/22/2012 End Date: 12/28/2012 X4- 0OWTY -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/15/2009 12:00:00AM Rig Release: 12/28/2012 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °29'25.778 "8 Long: 0149 °31'24.485 "W Active Datum: ORIG KELLY BUSHING @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 10:00 3.50 WHSUR P POST PJSM. N/U TREE. - N/U ADAPTER FLANGE & TREE. - FMC PRESSURE TEST TUBING HEAD © 250 PSI / 5 MIN / CHARTED. - PRESSURE TEST @ 5000 PSI / 30 MIN / CHARTED, TEST WITH DIESEL. FILL TREE WITH DIESEL AND TEST © 250 / 3500 PSI / 5 MIN EACH. CENTRILIFT CONDUCTED FINAL TEST ON ESP CABLE, OK. 10:00 - 12:00 2.00 WHSUR P POST PJSM. PICK UP LUBRICATOR. - PRESSURE TEST LUBRICATOR @ 250 / 3500 PSI, 5 MIN EACH / C HARTED. - PULL TWO WAY CHECK VALVE. 12:00 - 13:00 1.00 WHSUR P POST WELL SUPPORT CHANGED OUT TOOLS. - M/U LUBRICATOR AND PRESSURE TEST @ 250 / 3500 PSI, 5 MIN EACH. - SET BPV, RIG DOWN LUBRICATOR & UD TOOLS. 13:00 - 13:30 0.50 WHSUR P POST PJSM. PERFORM ROLLING TEST. - TEST BPV FROM BOTTOM, PUMPING INTO WELL. 4 -5 BBLS /MIN @500 PSI, 10 MIN / CHARTED, GOOD TEST. - PUMPED 52 BBLS AWAY DURING ROLLING TEST. 13:30 - 15:00 1.50 RIGD P POST PJSM. RIG DOWN LINES IN CELLAR. - FLUSH MUD PUMP, CLEAN / EMPTY BRINE FROM PITS. - EMPTY SLOP TANK, REMOVE WORKING VALVES FROM 0/A. - 125 BBLS OF 9.1 PPG BRINE LOST TO WELL SINCE MIDNITE. - AOGCC NOTIFIED OF IMPENDING BOPE TEST ON MPC-01 - 24 HOUR NOTICE GIVEN @ 1:22 PM COMMUNICATING INTENT TO TEST @ 20:00 HRS ON 12/29. (30 1/2 HRS FROM NOW). 15:00 - 18:00 3.00 RIGD P POST SECURE TREE AND CELLAR AREA - REMOVE CUTTINGS TANK AND FUEL TRAILER - STAGE MATS AROUND MPC-01 - WELL SUPPORT REMOVED WELL HOUSE FROM MPC-21 - RELEASE RIG AT 18:00 HOURS Printed 1/7/2013 1:19:39PM TREE: 3 1/8" - 5M FMC OKB. E LEV = 52' (Audi 3 ) MP 1 11" C 3 ( WELLHEAD: 11 5M FMC ase 1 &2) ORIG. GL. ELEV = 17' (Audi 3) w/ 3.5" FMC Tubing Hanger, 3.5" NSCT Threads, 3.0" CIW BPV profile 0 f 0 0 13 3/8" 48 #/ft H-40 115' I 0 / y - / 4, / i 2 • l R F Camco 3.5" x 1" KBUG GLM I 295' I 9 5/8", 36 # /ft, 4779' . , � 1 K -55 Butt P P, KOP @ 3000' t MAX HOLE Angle P 42.75 DEG AT 6000' MD P Camco 3.5" x 1" KBUG GLM 1 7173' 3.5" , 9.2" #/ft , L -80 IBT P ( id 2.992" .0087 bbls / ft) XN Nipple 3.5" TC - II 7325' I 7" 26 # /ft, L -80 BTC Casing P (id 6.276" cap = .0383 bpf) / Discharge Head GPHVDIS 1 7379' (cap w/ 2 7/8" tbg inside = .02758 3.5 EUE 8RD t Tandem Pumps: SXD, 1 7379' / 18 -P75 & 137 -P17 j .. Gas Separator GRSFTXAR H6 7405' I 0 Upper Tandem Seal Assembly 7410' Lower Tandem Seal Assembly 7417' MPS -1 Motor I 7424' ORIGINAL PERFORATION SUMMARY I . 168 HP, 3460 v/ 30 amp SIZE SPF INTERVAL OPEN /SQZ'D 5" 12 7770' - 7786' OPEN Phoenix PumpMate 7438' I 5" 12 7878' - 7881' OPEN 5 " 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN p 2 -5/8" 4 7991' - 8009' OPEN g 11/3/94 PERFORATION SUMMARY n SIZE I SPF I INTERVAL OPEN/ SQZ'D i j I I I I 3 -3/8" 16 7770' - 7786' I OPEN II 3 -3/8" 6 7990' - 8055' OPEN 4 -ES PBTD 8/22/96 @ 8,144' r — ORIG. PB I 8,156' 7" 26 #, L -80, BTRS I 8,236' I DATE REV. BY COMMENTS MILNE POINT UNIT 8 / 24 / 96 MDO ESP RWO 4 ES WELL MPC -13 7/10/05 Lee Hutme ESP RWO 4 ES API NO: 50- 029 -21328 4/21/09 Lee Hulme ESP RWO 3S 12/30/12 Richardson ESP RWO Doyon 16 BP EXPLORATION (AK) ~,E,~~~~° STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ ARR ~ ~~~ORT OF SUNDRY WELL OPERATIONS 1. Operations j d n ~~ppVell ^ Plug Perforations ^ Stimulate^ Other , Performed: ~Pi Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ ACID Change Approved Progr perat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ JOB 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 185-0670 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-21328-00-00 8. Property Designation (Lease Number) : 9. Well Name and Numbe~ ~ ADLO-025516 MPC-13 10. Field/Pool(s): MILNE POI NT FIELD KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 8273 feet Plugs (measured) None feet true vertical 7311.67 feet Junk (measured) None feet Effective Depth measured 8156 feet Packer (measured) true vertical 7224 feet (true vertical) Casing Length Size MD ND Burst Collapse Structural Conductor 80 13-3/8" 48# H-40 SURFACE - 115 SURFACE - 115 1740 750 Surface 4743 9-5/8"36# K-55 SURFACE - 4779 SURFACE - 4623 3520 2020 Intermediate Production 8202 7"26# L-80 SURFACE - 8202 SURFACE - 7284 7240 5410 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1 /2" 9.3# LL-80 30 - 7485 30 - 6714 Packers and SSSV (type, measured and true vertical depth) NONE _ r~K ~~!~~~-~a ~ Q~ , ,r . , 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 139 188 428 188 Subsequent to operation: 157 196 404 188 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Wetl Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 4/2/2010 ~,,,, ,~-,~~ ,.~.,,~. „~~~~ RBDtNS APR 0 5 zuw S~ ~- ~ sip ~.,'~~~,~l~v MPC-13 185-067 PFRF ATTArI-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-13 5/8/85 PER 7,770. 7,786. 6,933.92 6,946.05 MPC-13 5/8/85 PER 7,878. 7,881. 7,015.58 7,017.85 MPC-13 5/8/85 PER 7,890. 7,894. 7,024.67 7,027.7 MPC-13 5/8185 PER 7,904. 7,910. 7,035.27 7,039.81 MPC-13 5/8/85 PER 7,991. 8,009. 7,100.94 7,114.47 MPC-13 5/8/85 PER 8,021. 8,056. 7,123.49 7,149.72 MPC-13 11/3/94 APF 7,770. 7,786. 6,933.92 6,946.05 MPC-13 11/3/94 APF 7,990. 8,055. 7,100.19 7,148.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPC-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/25/2010 T/I/0=300/280/380 Acid Treatment Pumped 10 bbls crude, 11 bbls 10% DAD [ Acid, 3 bbls 60/40 methanol & 57 bbls crude down Tbg. Pumped 4 bbls crude €down FL. DSO Notified well support on well upon LRS departure. FW HP's=200/200/80 I FLUIDS PUMPED BBLS 71 CRUDE 11 DAD ACID 3 60/40 METH 2 TOTAL i r TREE: 3 118" - 5M FMC WELLHEAD: 11" 5M FMC (Phase ~ w! 3.5" FMC Tubing Hanger, 3.5" NSCT Threads, 3.0" CIW BPV profile 13 3/8" 48#/ft H-40 115' 9 5/8", 36#/ft, 4779' K-55 Butt KOP @ 3000' MAX HOLE Angle 42.75 DEG AT 6000' MD 3.5" , 9.2" #/ft , L-80 IBT (id 2.992" .0087 bbls / ft ) 7" 26 #/ft, L-80 BTC Casing (id 6.276" cap = .0383 bpt7 (cap w/ 2 718" tbg inside = .02758 ( ORIGINAL PERFORATION SUMMA SIZE SPF INTERVAL OPENISO: 5,~ 12 7770' - 7786' OPEN 5" 12 7878' - 7881' OPEN 5" 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN 2-5/8" 4 7991' - 8009' OPEN 11/3/94 PERFORATION SUMMARY SIZE I SPF I INTERVAL OPEN/ SOi 3-3/8" I 6 7770' - 7786' ~ OPEN 3-318" 6 7990' - 8055' I OPEN DATE EV. BY I,,,IIIIIIIIIIIII COMMENTS 11 /7/94 D B R RWO __ 8 / 24 / 96 MDO ESP RWO 4 ES 7/10105 Lee Hulme ESP RWO 4 ES 4/21/09 lee Hulme ESP RWO 3S ORIG. KB~// = 52' (Audi 3) ORIG. GL. ELEV = 17' (Audi 3) mco 3.5" x 1" KBUG GLM 147' mco 3.5" x 1" KBUG GLM 298' I mco 3.5" x 1" KBUG GLM 7293' I Nipple (2.813 packing ID) 7445' I 75 no-go ID) harge Head GPHVDIS 7468' iem Pumps: SXD, ' 17 & 68-G31 7469 Separator GRSFTX AR H s 7496' lem Seal Assembly 7501' )B UT/LT SBlSB PFSA itrilift KMH Motor 7515' HP, 23025 v / 60 amp enix PumpMate 7534' I Sensor Depth = 6752' TVD 4-ES PBTD 8/22/96 @ 8,144' ORIG. PB 8 156' 7" 26#, L-80, BTRS g 236' MILNE POINT UNIT WELL MPC-13 API NO: 50-029-21328 BP EXPLORATION MPC-13 STATE OF ALASKA F,,",` t, s ALA OIL AND GAS CONSERVATION CO SION ~ ~, ~ ?OQ9 5-~~-~ REPORT OF SUNDRY WELL OPE TIONS 'a`;,.,~ ~ ~ ,; k, €~~~ ~o~s. Commission 1. Operations Performed: r"`` ~~$~~ ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: . BP Exploration (Alaska) Inc. ®Development ^ Exploratory 185-067- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21328-00-00 - 7. KB Elevation (ft): 52, 9. Well Name and Number: MPC-13 - 8. Property Designation: 10. Field /Pool(s): _ ADL 025516 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8270 - feet true vertical 7309 feet Plugs (measured) N/A Effective depth: measured 8156 feet Junk (measured) N/A true vertical 7224 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 115' 115' 1740 750 Surface 4743' 9-5/8" 4779' 4623' 3520 2020 Intermediate Production 8202' 7" 8236' 7284 7240 5410 Liner Perforation Depth MD (ft}: 7770' - 8055' Perforation Depth TVD (ft): 6934' - 7149' 3-1/2", 9.3# L-80 7538' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): WC~~~ S'~,,,1 ~ \0- O~ ~'~~'~~ `~ ~` ~ /~ _~ ` Treatment description including volumes used and final p ressure: ~~ 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1080 Subsequent to operation: 191 70 1110 300 160 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram -® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name. Sondra Stewman Title Drilling Technologist ''' .~ Prepared By Name/Number: e(]t Signatufe Phone 564-4750 Dat c; Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006'-° ~' `~' ~, l~~ul" ~ {j [UQ4 ~ Submit Original Only TREE: 3 1!8" - 5M FMC M P C -13 WELLHEAD: 11" 5M FMC (P 1&2) ORI~. ELEV = 52' (Audi 3) w/ 3.5" FMC Tubing Hanger, 3.5" NSCT ORIG. L. ELEV = 17' (Audi 3) Threads, 3.0" CIW BPV profile 13 3/8" 48#/ft H-40 115' 9 5/8", 36#/ft, 4779' K-55 Butt KOP @ 3000' MAX HOLE Angle 42.75 DEG AT 6000' MD 3.5" , 9.2" #/ft , L-80 IBT (id 2.992" .0087 bbls / ft } 7" 26 #/ft, L-80 BTC Casing (id 6.276" cap = .0383 bpf) (cap w/ 2 7/8" tbg inside = .02758 ( ORIGINAL PERFORATION SUMMARY SIZE SPF INTERVAL OPEN/SOZ'D 5" 12 7770' - 7786' OPEN 5" 12 7878' - 7881' OPEN 5" 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN 2-5/8" 4 7991' - 8009' OPEN 11/3/94 PERFORATION SUMMARY SIZE I SPF I INTERVAL OPEN/ SOZ'D 3-3/8" I 6 7770' - 7786' I OPEN 3-3/8" 6 7990' - 8055' I OPEN DATE REV. BY COMMENTS 11/7194 DBR RWO 8124 / 96 MDO ESP RWO 4 ES 7/10/05 Lee Hulme ESP RWO 4 ES 4/21/09 Lee Hulme ESP RWO 3S Camco 3.5" x 1" KBUG GLM 147 Camco 3.5" x 1" KBUG GLM 298' Camco 3.5" x 1" KBUG GLM 7293' XN Nipple (2.813 packing ID) 7445 (2.75 no-go ID) Discharge Head GPHVDIS 7468' Tandem Pumps: SXD, ' 79-P17 & 68-G31 7469 GaS Separator GRSFTX AR H6 7496' Tandem Seal Assembly 7501' GS83D8 UT/LT SB/SB PFSA Centrilift KMH Motor 7515' 2282 HP, 23025 v / 60 amp Phoenix PumpMate 7534' Sensor Depth = 6752' TVD 4-ES PBTD 8122/96 @ 8,144' ORIG. PB 8 156' 7" 26#, L-80, BTRS g 236' MILNE POINT UNIT WELL MPC-13 API NO: 50-029-21328 BP EXPLORATION -~ J MPC-13 Well History Date Summary • 01/10/09 T/I/O 250/360/350 Bleed OA. Bled OA from 350 psi to 100 psi in 4 minutes and 1/4 bbl fluid. Final WHP'S = 250/360/100 01/24/09 Freeze Protect 01/25/09 T/I/0=200/300/0 Freeze Protect Tbg & FL Pumped 15 bbls diesel down Tbg & 6 bbls 60/40 methanol down FL. FW HP's=400/300/0 swab shut wing shut ssv closed master open IA open OA open 01/26/09 RUN 1.75" LIB S/D C~ 7313' SLM, TAP DOWN FAL THROUGH S/D C~ 7450' SLM UNCLEAR ABOUT MARKS RUN 5' x 2.25" PUMP BAILER S/D 037484' SLM, BAILER EMPTY RUN 1.75" LIB S/D C 7482' SLM, IMP OF SHA SET WHIDDON CATCHER C~3 7304' SLM PULURUN 1" DPSOV C«~ 2983' SLM PULU 1" DPSOV C~ 113' SLM, LRS PUMPED 5 BBLS NEET METH T/I/0=500/460/0 Assist S-Line Pumped 5 bbls neat down Tbg. FWHP's=500/460/0 S-Line on well upon LRS departure 01/27/09 SET DPSOV IN STA #3 C~3 125' MD 02/03/09 T/I/0=200/400/100 IA Flush Pumped 100 bbls crude down IA. FWHP's=200/120/60 swab shut, wing ssv master is oa open 02/12/09 T/I/0= 780/780/0 Freeze Protect Tubing and Lateral Pumped 22 bbls diesel down tubing. Pumped 10 bbls diesel and 10 bbls 60/40 methanol down lateral line. Pad op to wait for thermal expansion and close lateral and bleed flowline to 0 psi. FWHP= 680/680/0 Master, IA, OA, and wing open. Swab and SSV closed. 03/28/09 PULL 1" BK-DGLV FROM STA#1 @ 7303' MD, LEFT OPEN 03/29/09 PULLED BK-DPSOV FROM STA# 2 Q 2983' MD AND STA# 3 C~3 125' MD SET BK-DGLV IN STA #2 C«1 2983' MD AND STA #3 C~ 125' MD RUN DUAL SPARTEK GAUGES MAKE STOPS AS FOLLOWS: 15MIN Q 6950' SLM ~'~C~~ 3HR C~ 7940' SLM SET BPV 04/03/09 MPU Well ST demobed well house flow lines and foundation, Note BPV had all ready been set. 04/23/09 MPU Wells ST Re-hooked Well. Set foundation flow lines and well house, and piping from the wing to the root valve was PT to 3600 psi for 10 mins with diesel. All valves TO to spec, well houses back was left off ~S~ 04/23/09 per AES, and also the insulation for piping. NOTE: BPV removed. T/I/0= 0/0/0 Freeze protect. Pump 58 bbls crude down IA and 22 bbls crude down tbg. Swab, wing, r; ~ / ssv,mst , I, O closed. NOVP. FWHP=O/0/0 T/I/O 350/280/100 ll i O E 04/27 09 gas. nd ng T/I/O 350/280/980 Bleed down A from 980 psi to 100 psi in 7mins a Page 1 of 1 • BP EXPLORATION Page 1 of 4 Operations Summary Report (Legal Well Name: MPC-13 Common Well Name: MPC-13 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To ' Hours ' Task Code NPT I Spud Date: 4/15/2009 Start: 4/15/2009 End: 4/21 /2009 Rig Release: 4/21/2009 Rig Number: N3S Phase j Description of Operations 4/16/2009 18:00 - 19:30 1.50 RIGD P PRE Scope and lay over derrick. 19:30 - 22:30 3.00 RIGD P PRE Disconnect electrical to pipe shed and pit mod. Blow down steam from rig modules and carrier. Jack and pull away shed and pits. Roll tires on carrier. 22:30 - 00:00 1.50 RIGD P PRE Pull carrier off well slot with pad operator witness. Remove mats and herculite from well and pull BOP cradle from behind well 4/17/2009 00:00 - 03:00 3.00 MOB P PRE Move rig from F-pad to C-pad. 03:00 - 06:00 3.00 MOB P PRE Spot camp, shop, Gen skid and parts house. Spot mats and heculite, set BOP cradle behind well. Move carrier over well slot at 0600 hrs with pad operator witness. 06:00 - 10:00 4.00 MOB N RREP PRE Engines fuel lines frozen. RU heater trunks to thaw out lines. Changeout fuel filters. 10:00 - 12:00 2.00 MOB P PRE Adjust carrier over hole. Spot pipe shed and pits. Jack down into position. 12:00 - 14:00 2.00 RIGU P PRE Raise and scope Derrick. 14:00 - 15:00 1.00 RIGU P PRE Rig up Derrick board and floor. Hook up electrical lines between modules. Connect steam, air and water lines. Accept rig at 1500 hrs on 4-17-09. 15:00 - 17:00 2.00 KILL P DECOMP Rig lines to kill well from tree to kill manifold. RU Tiger tank hardline. Connect double annulus valve to IA. 17:00 - 18:00 1.00 KILL P DECOMP Pump open SSV and intall fusible cap. PU lubricator and MU to tree. Test to 500 psi with diesel. Pull BPV. Initial pressures: TBG = 1070 psi, IA = 1100 psi, OA = 200 psi. 18:00 - 20:00 2.00 KILL P DECOMP Pressure test lines for well kill. Test surface lines to 3,500 psi and 500 psi down stream of choke. 20:00 - 00:00 4.00 KILL P DECOMP Open well and bleed down IA from 1100 psi to 250 psi, tubing fell from 1070 psi to 950 psi. Bleed tubing from 950 psi to 200 psi. Break circulation down tubing with 140 degF seawater taking returns from IA thru choke to Tiger tank at 3 BPM / 140 psi and 290 psi on IA. Circulate 70 bbls with FCP of 3.5 BPM / 50 psi and 350 psi on IA. Returned 47 bbls to Tiger tank (67% Close choke and bullhead 60 bbls of 140 degF seawater down tubing at 3 BPM / 110 psi and IA built from 350 psi to 560 psi. Shut in and monitor for 15 min. Tubing on vac and IA charge pressure fell to 470 osi. Open well and circulate 140 degF seawater max rate in conjunction with LRS at 6 BPM / 320 psi down tubing taking returns thru choke to Tiger tank. Circulate 168 bbls at 6 BPM / 490 psi, loss rate to Tiger tank at 36%. Reduce rate and continue to circulate wit rig pump a .5 BPM / 220 psi until returns visibly cleaned up to good sewater. Returns were crude and gas. Circulated 406 bbls thru IA and returned 175 bbls to Tiger tank (43% returns). Total volumes circulated 476 bbls with 232 bbls returned (overall 49% returns). 4/18/2009 00:00 - 01:00 1.00 KILL P DECOMP Monitor well for 40 min. Tubing and IA on good vac. Blow down lines. 01:00 - 03:30 2.50 WHSUR P DECOMP PU T-bar and drV rod TWC with FMC. Test TWC from above to 3,500 psi for 10 min -charted. Test TWC from below to by injecting down IA, took 10 bbls to catch fluid (-260' fluid level). Printed: 5/4/2009 11:43:29 AM • BP EXPLORATION Operations Summary Report Page2of4~ Legal Well Name: MPC-13 Common Well Name: MPC-13 Spud Date: 4/15/2009 ,Event Name: WORKOVER Start: 4/15/2009 End: 4/21/2009 ',Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2009 I~ Rig Name: NABOBS 3S Rig Number: N3S Date From - To Hours I Task I Code NPT .Phase Description of Operations 4/18/2009 01:00 - 03:30 2.50 WHSUR P DECOMP __ Pop-it on TWC leaking by. Work pump to seat pop-it. Test i TWC from below at 5.1 BPM / 350 psi for 10 min -charted. ', Pumped a total of 91 bbls. 03:30 - 04:30 1.00 WHSUR P DECOMP Blow down and rig down lines from tree. Remove kill manifold from cellar. Suck out tree. 04:30 - 07:00 2.50 WHSUR P DECOMP ND tree and adapter flange. Secure in cellar. Inspect hanger threads with 3-1/2" NSCT pup. 07:00 - 12:00 5.00 BOPSU P DECOMP Set DSA. NU BOPE. 12:00 - 16:30 4.50 BOPSU P DECOMP Test BOPE 250 si low / 3,500 si hi h. Test witnessed by WSL and Toolpusher. AOGCC John Crisp waived the state's right to witness at 0745 hrs at 4-16-09. Test with 3-1/2" test joint. Complete Koomey draw down test. Blow down lines. 16:30 - 18:00 1.50 BOPSU P DECOMP MU Opso-Lopso and lo-torque with XO and screw into hanger. MU lubricator and PT to 500 psi with diesel. Pull TWC. LD lubricator and Opso-Lopso. Tubing and IA on vac. 18:00 - 20:00 2.00 PULL P DECOMP MU landing joint and TIW valve. Screw into hanger. Check IA thru 2", well on vac. BOLDS with FMC. Pull hanger off seat with 95K. PU hanger 3' with up weight to 82K. 20:00 - 22:30 2.50 PULL P DECOMP MU circulating hose. CBU at 3.2 BPM / 190 psi, took 35 bbls to catch returns (-1,100' fluid level). Circulate a total of 300 bbls (annulus volume + 50% losses), returned crude traces back to pits. os s wring circulation. 22:30 - 00:00 1.50 PULL P DECOMP Pull hanger to floor with 82K. Pull penetrator with FMC and disconnect ESP cable with Centrilift. LD hanger and inspect. 4/19/2009 00:00 - 03:00 3.00 PULL P DECOMP PJSM with crew and Centrilift rep. POH with 3-1/2" ESP completion standing back in Derric onnections pu ing tight and having to warm up connec ions prior to breaking out. ESP cable showing signs of external wear on armor sheath, enough to expose cracks and even blow outs on cable. Take pictures and put in folder. Top GLM gas lift valve packing tore and bulging out port holes. Gravity feed well -20 bbl/hr during dis lacement. Found IA valve to not function correctly, ca Wells Support for service. 03:00 - 04:00 1.00 PULL P DECOMP Held safety discussion focusing on hammering tight connections prior to breaking out. 04:00 - 11:30 7.50 PULL P DECOMP Continue to POH with 3-1/2" tubing standing back in Derrick. Pulled 117 stands and 2 singles. Pulled 484 bands (485 bands on original tally), could see where 1 band was missing. Continuous hole fill at -20 bbl/hr. 11:30 - 16:30 5.00 PULL P DECOMP LD ESP assembly. Swap out tongs. RD elephant trunk and swap out ESP equipment. Start to PU new ESP as per Centrilift. Valve crew on location to evaluate problem inner IA valve that rig double annulus valve is connected to. Valve not functioning and unable to service on wellhead needs to be removed. Call town and discuss valve removal and barriers needed to proceed. 16:30 - 19:30 3.00 WHSUR N WAIT DECOMP Wait on Orders and plan from town and wait on FMC Tech and equipment. Call for VR plug and RTTS for barriers. Call for Drill Collars that are on MPF-pad. 19:30 - 21:00 1.50 WHSUR C DECOMP Set VR plug as per FMC rep. Test thru annulus valve to VR plug to 5,000 psi for 10 min -charted. 21:00 - 00:00 3.00 WHSUR C DECOMP Prep rig floor and shed for Drill collars and RTTS make up. PJSM for loading pipe in shed and picking up pipe. Load 12 Printed: 5/4/2009 11:43:29 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPC-13 Common Well Name: MPC-13 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 3S Date I From - To ~ Hours ~ Task Code NPT 4/19/2009 21:00 - 00:00 3.00 WHSUR C 4/20/2009 00:00 - 01:30 1.50 WHSUR C Start: 4/15/2009 Rig Release: 4/21/2009 Rig Number: N3S Page3of4~ Spud Date: 4/15/2009 End: 4/21 /2009 Phase Description of Operations DECOMP ea. 4-3/4" DC in shed. Strap, ID and OD Drill Collars. DECOMP PUMU 12 ea 4-3/4" Drill collars and RIH. Continuous hole fill 01:30 - 03:00 1.50 WHSUR C DECOMP PUMU RTTS as er Halliburton rep. RIH and set 39' below table, PUW = 22K, SOW = 22K. Fill stack thru kill line and shut annulur. RU test equipment. Unable to test RTTS.. Unsling from RTTS and shut blind rams, stinger o-rings appear to be in ood shape. Test RTTS from above to 1,000 si for 10 min -charted. 03:00 - 04:30 1.50 WHSUR C DECOMP Remove double annulus and IA valve. Install new IA valve and double annulus. Test casing valves to 5,000 psi for 10 min - 04:30 - 05:00 0.50 WHSUR C DECOMP RIH and sting into RTTS. Tubing on vac. Unseat RTTS and Dull uo several feet and watch fluid from stack ao on vac. SE 05:00 - 06:00 1.00 WHSUR C DECOMP LD RTTS as per Halliburton rep. LD Drill collars 1x1 in shed. Remove collars from shed. Continuous hole fill at -20 BPH. 06:00 - 07:00 1.00 BUNCO P RUNCMP Clean and clear rig floor. RU to pickup ESP assembly. 07:00 - 11:00 4.00 BUNCO P RUNCMP PUMU ESP assembly as per Centrilift rep. Service pump and tie in cable. Test conductivity of ESP cable. 11:00 - 14:00 3.00 BUNCO P RUNCMP RIH with 3.5", 9.3# L-80 completion as per running order. RIH with 3.5" tubing out of Derrick. Check conductivity of ESP cable every 2,000' while running in hole. Use Cannon Cross Collar clamps on every joint. Use Best-O-Life pipe dope and MU torque = 3,000 ft-Ibs as per Nabors Casing (buttress mark rubbed off). Flush pump and circulate 10 bbls at .5 BPM / 400 psi. 14:00 - 18:00 4.00' BUNCO P RUNCMP RIH to 45 stands. crude started comin4 over pipe stump. IA with no returns. Circulate 35 bbls at 1 BPM / 1150 psi to clear tubing. Flow check well and tubing both on vac. Pump across top of hots and obtain static loss rate of 18 bbl/hr. Monitor well for 30 min - no change. 18:00 - 00:00 6.00 BUNCO P RUNCMP Continue to RIH with 3.5", 9.3# L-80 completion as per running order. RIH with 3.5" tubing out of Derrick. Check conductivity of ESP cable every 2,000' while running in hole. Use Cannon Cross Collar clamps on every joint to surface. Use Best-O-Life pipe dope and MU torque = 3,000 ft-Ibs. Flush pump and circulate 10 bbls at 1 BPM / 1200 psi.. Losses while pumping across hole = 18 bbl/hr. 4/21/2009 00:00 - 02:30 2.50 BUNCO RUNCMP ontinue to run ESP comp etion as per tally. Ran a total of 235 joints, 3 GLM's, 1 XN assembly, 240 Cannon clamps, 480 Cannon pins, 6 protectilizers, and 3 flat guards. MU circulating pin and pump 10 bbls for final rate and pressure at 1 BPM / 1180 psi. Losses = 18 bbl/hr. 02:30 - 03:30 1.00 BUNCO P RUNCMP PU landing joint with TIW valve and MU tubing hanger to string. Tubing spool does not have alignment pin. Took plumb-bob measurments in cellar and rig floor to align hanger with IA valve. Install penetrator and inspect hanger with FMC. 03:30 - 05:00 1.50 BUNCO P RUNCMP Conduct ESP penetrator splice with Centrilift rep. Conduct competancy safety meeting with rig crew and discussion around accountability. Conductivity checks: BHP = 2,967 psi, BHT = 133.9 degF, Phase to Phase = 3.0 ohms, Phase to Printed: 5/4/2009 11:43:29 AM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPC-13 Common Well Name: MPC-13 Spud Date: 4/15/2009 Event Name: WORKOVER Start: 4/15/2009 End: 4/21/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/21/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To ~ Hours j Task Code; NPT I Phase ~ Description of Operations -_ _ _ _ ` I __ _ - _` _ - _ ---- - 4/21/2009 03:30 - 05:00 1.50 BUNCO RUNCMP Ground = 1 Gig ohms. 05:00 - 06:00 1.00 BUNCO P RUNCMP Final weights: PUW = 80K, SOW = 62K. Land hanger. RILDS with FMC rep. BOLD landing joint. 06:00 - 08:00 2.00 WHSUR P RUNCMP Set TWC and test rom above to 3500 psi for 10 charted minutes. Test from below by injecting down IA C~3 4 BPM with 08:00 - 12:30 4.50 WHSUR P RUNCMP Blow down lines an ram stack. N D BOP's set on craddle and lay over. Remove DSA. 12:30 - 14:30 2.00 WHSUR P RUNCMP NU tree and adapter flange. Centrilift conduct final checks: BHP = 2937 psi, BHT = 145.6 degF, phase to phase = 3.0 ohms, phase to ground = 1 gig ohms. 14:30 - 15:30 1.00 WHSUR P RUNCMP Test hanger void with FMC to 5,000 psi for 30 min -passed. Test tree with diesel to 5,000 psi for 5 min -charted. 15:30 - 17:00 1.50 WHSUR P RUNCMP PUMU lubricator with Wells Support and test to 500 psi with diesel. Pull TWC. Set BPV with lubricator. Final pressures: TBG =vac, IA, =vac, OA = 0 psi. 17:00 - 18:00 1.00 WHSUR P RUNCMP Remove double annulus. Release rig at 1800 hrs on 4-21-09. Printed: 5/4/2009 17:43:29 AM STATE OF ALASKA 11/1x/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit fio: Contractor: Nabors Rig No.: 3S DATE: 4/18/2009 Rig Rep.: J. Greco / R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: O. Coyne / V.Volpe Field/Unit & Well No.: MPC-13 PTD # 1850670 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Workover: X Weekly: Annular. 250/3500 TEST DATA Test Result Test Result Location Gen.: P Well Sign P Housekeeping: P Drt. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantty Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/$ X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 31/8-2 1/16" P Kill Line Valves 1 2 1/16" 5000 P Check Vabe 0 NA MUD SYSTEM: V'~sual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Mein Gas Detector P P H2S Gas Detector P P Test Results Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Re Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3100 P Pressure After Closure 1750 P 200 psi Attained 21 sec P Full Pressure Attained 2 min 30 sec P Blind Switch Govers: Ali stations P Nitgn. Bottles (avg): 2030 psi Number of Failures: 0 Test Time: 4 Hours Comaonents tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Test Against 2 Way Check valve /Test w/ 31/2" test it 24 HOUR NOTICE GIVEN YES x NO Waived By John Cri Date 04/16/09 Time 7:30 Witness O.Go elJimm Greco Test start 12:00 Finish 16:00 BOP Test (for rigs) BFL 11/14/07 Nabors 3s BOP Test MPC-13 4-18-2009 .xls FW: MPC-13 State Test ~ • Page 1 of 1 Maunder, Thomas E (©tJA) From: Crisp, John H (DOA} ~~, Sent: Monday, July 23, 2007 6:06 AM , ~~ ~ ~ `~ \. To: Regg, James B (DOA} Cc: Scheve, Charles M (DOA}; Noble, Robert C (DOA); Jones, Jeffery B (DOA}; Grimaldi, Louis R (DOA); Maunder, Thomas E (DOA} Subject: FW: MPC-13 State Test I had a meeting with Well Ops Leader John Cubon after we finished MPU C & B. I requested they send the investigation report that BP will generate from MPU C-13 failed LPP & successful retest. This is the first failure of this type I had encountered @ Milne. Mr. Cubon indicated BP would be in contact with AOGCC Inspectors Supervisor. From: MPU, Well Operations Supervisor [mailto:welloperationssupervisor@BP.com] Sent: Sunday, July 22, 2007 4:57 PM To: Engel, Harry R; Crisp, .john H (DOA); Crisp, John H (DOA) Cc: MPU, Area Manager Subject: FW: MPC-13 State Test ~'~'~~~ N~~ ~ $ 20~~ John 1 Harry, Attached is a statement from Brian Bixby concerning the failed SSV test at MPC-13 yesterday. f will fofiow,up with a call to Jim Regg in the morning. ~ ~ _ ,-- . -._'-~`'-"•~-~""'"'~`"`~`~' _ Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 From: MPU, VECO Wells Support Supv Sent: Sunday, July 22, 2007 8:17 AM TQ: MPU, Wel{ Operations Supervisor Subject: MPC-13 State Test John, Here is the summary of events that took place regarding testing of the C-13 Pilot and SSV. We had just finished testing the first well of the day (C-14) and everything went great. We moved over to C-13 and rigged up to test the Pilot first and after bleeding it to zero the pilot did not trip. The state representative (John Crisp} and myself went. to the C-pad module because that is where the pilot is located for this wet! to look and make sure it we all lined up correctly. We found that every was lined up correctly and that no valves were blocked in or bypassed. We then contacted the C-pad operator (Jahn Gibb) and he confirmed that everything was lined up correctly. The operator contacted the systems tech. And they found a problem in the programming. The tech reset and it tested fine. Brian 10/16/2007 ~, STATE OF ALASKA, ALASKA )L AND GAS CONSERVATION cO....~ISSION REPORT OF SUNDRY WELL OPERATIRt!tEi\lE[) ^U êhlJ JuQQ~p 1. Operations Performed: o Abandon o Alter Casing o Cha nge Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 025516 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 0 Operation Shutdown 0 Perforate aD Othe'Alaska Oil & Gas Cons. Cm'i'Wì1iuiQI1 o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspend~Åc'fYtW~ge aD Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 52' 8270 7309 8156 7224 80' 4743' 8202' 4. Current Well Class: aD Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 185-067 6. API Number: 50-029-21328-00-00 99519-6612 9. Well Name and Number: MPC-13 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 13-3/8" 115' 115' 1740 750 9-518" 4779' 4623' 3520 2020 7" 8236' 7284 7240 5410 SCAj\lNED J~UG 11 20.05 7770' - 8055' 6934' - 7149' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 3-1/2",9.3# L-80 7534' Treatment description including volumes used and final pressure: RBDMS 8Ft AUG 1 5 2005 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run aD Daily Report of Well Operations aD Well Schematic Diagram 15. Well Class after proposed work: o Exploratory aD Development 0 Service 16. Well Status after proposed work: aD Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 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: Contact David Reem, 564-5743 Printed Name Sondra Stewman Si9~~-l£~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Date D~ - \ I-os Prepared By Name/Number: Sondra Stewman, 564-4750 Submit Original Only 564-4750 TREE: 31/8" - 5M FMC WELLHEAD: 11" 5M FMC )e 1 &2) wI 3.5" FMC Tubing Hanger, 3.5" NSCT Threads, 3.0" CIW BPV profile 13 3/8" 48#/ft H-40 I-I 115' KOP @ 3000' MAX HOLE Angle 42.75 DEG AT 6000' MD 9 5/8". 36#/ft, K-55 Butt r 4779' I - j 3.5" , 9.2" #/ft , L-80 IBT ( id 2.992" .0087 bbls 1 ft ) T' 26 #/ft, L-80 BTC Casing (id 6.276" cap = .0383 bpf) (cap wi 2 7/8" tbg inside = .02758 MPC-13 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 I I I I I I I I I I I I I I I I I I ORIGINAL PERFORATION SUMMARY SIZE SPF INTERVAL OPEN/SQZ'D ( "-~, 5" 12 7770' -)786' OPEN 5" 12 787(\,- - 7881 ' OPEN 5" 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN ï .,. / 2-5/8" 4 7991' - 8009' OPEN I I I / 11/3/94 PERFORATION SUMMARY I / I I ¿ "" I I ï SIZE I SPF I INTERVAL OPENI SQZ'D I I I I I I I I 3-3/8 " I 6 7770' - 7786' OPEN I I 7990' - <~ i ~ I 3-3/8" 6 OPEN ~. I DATE REV. BY COMMENTS 11/7/94 DBR RWO 8 I 24 / 96 MOO ESP RWO 4 ES 7f1 0105 Lee Hulme ESP RWO 4 ES i/ / / / / ..- (" )KB. ELEV = 52' (Audi 3) Or-..,-,. GL. ELEV = 17' (Audi 3) · ~CFIV~D Cameo 3.5" x 1" KBß~ 125' AU J 1 1 200~ Alaska Oil & Gas Cons. c. mmission Anchorage Camco 3.5" x 1" KBUG GLM I 29831 I . Camco 3.5" x 1" KBUG GLM I 73031 XN Nipple (2.813 packing 10) I 74531 (2.75 no-go 10) MS-1 Pressure Head 74761 I Centrilift GC 1700 ESP, 74781 I series 513, GPMTAR1:1 Gas Separator GRSFTX AR H6 74951 I Tandem Seal Assembly 75001 I GSB3DB UT/L T AB/HSN PFSNFSA CL5 Centrilift KMH Motor 75141 I 152 HP, 2325 v / 40 amp Phoenix MS-1 Sensor I 75281 Sensor Depth = 6747' TVD 4-ES PBTD 8/22/96 @ 8,144' ORIG. PB I 8,156' 7" 26#, L-80, BTRS I 8,236' MILNE POINT UNIT WELL MPC-13 API NO: 50-029-21328 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) RECEIVt:U AUG 11 2005 Page 1 of 2 QpercïtiønsSummaryReport... .. . . .... . .. . . Alaska 011 &Gas Cons. CommIssion Anchorage Spud Date: 4/26/1985 End: 7/11/2005 BPEXPLORATION· MPC-13 MPC-13 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/8/2005 Rig Release: 7/11/2005 Rig Number: Date From- To Hours Task Cöde NPT Phase Description of Operations 7/8/2005 06:00 - 08:00 2.00 MOB P PRE Move Rig and support equipment from MPB-Pad to MPC-Pad. 08:00 - 09:00 1.00 RIGU P PRE Spot Sub Base, Pipe shed, Pits, and Camp. 09:00 - 10:00 1.00 RIGU P PRE Raise and scope Derrick. 10:00 - 11 :00 1.00 RIGU P DECOMP Spot Tiger Tank. Lay Lines. NU HCR Valve. Pump open Actuator Valve. 11 :00 - 12:00 1.00 RIGU P DECOMP Pick-up Lubricator and attempt to pull BPV...ice in Master Valve. Thaw with Meth. Pull BPV. Lay down same. Tbg Press = 1975 psi. Annu Press = 1450 psi. 12:00 - 12:30 0.50 RIGU P DECOMP Take on warm Sea Water in Pits. Spot Lil' Red Unit. 12:30 - 13:00 0.50 KILL P DECOMP PJSM with All. Discuss Well Kill and general work scope of the program. 13:00 - 14:00 1.00 KILL P DECOMP Test Lines to 3500 psi. Finish off-loading Sea Water. Finish RU LiI'Red Unit. 14:00 - 19:30 5.50 KILL P DECOMP PJSM R/U Little Red pump to Tbg 1 R/U rig pump to Csg simultaniusly bullhead a total of 600 bbls of 8.5 heated sea water. LRS rate 2.5/1.5 bpm down Tbg at -2500 psi. Rig Pump rate at 5.0 bpm at 2500 psi. Monitor well until stable 1 Order out 12.1 kill wieght fluid 19:30 - 00:00 4.50 KILL P DECOMP Wait on re-cycled 11.1 Brine from MPU that was stored at MI to be weighted up at MI and shiped back to location 7/9/2005 00:00 - 07:30 7.50 KILL DECOMP Waiting for KWB to be wieghted up at Mi plant having trouble mixing due to cold fluid, started loading trucks at 03:45, first load left at 04:20. 07:30 - 09:30 2.00 KILL DECOMP Offload 400 bbls of 12.1 KWB 09:30 - 13:00 3.50 KILL DECOMP PJSM Tbg pressure 1070 psi Bullhead 65 bbls down Tbg at 6 bpm 1 1600 psi; Bullhead 210 bbls down annulas at 6 bpm 1 1700 psi 13:00 - 16:00 3.00 KILL DECOMP Monitor well surface at 340 psi 1 16:00 - 18:00 2.00 KILL DECOMP Check fluid in Tbg down to holes at 2,500'. Reverse circulate 12.1 KWB to surafce 11 bbls. Returns from Tbg were 9.8 - 10.6 Ib/gal. Bullhead 50 bbls of 12.1 KWB 1 Monitor 1 Discuss plan forward with Anchorage and Slope. Order out 500 bbls of 12.1 KWB. 18:00 - 00:00 6.00 KILL DECOMP Wait on 12.1 KWB 7/10/2005 00:00 - 04:00 4.00 KILL P DECOMP Wait on 12.1 KWB weighted up at MI plant 04:00 - 05:30 1.50 KILL P DECOMP PJSM with rig crew and Little Red R/U Little Red to Tbg and Rig to Annulus. Tbg at 250 psi Pump and bull head 12.1 KWN simultaniusly pumping at 3 bpm 1 1875 psi through Tbg volume 120 bbls and 5 bpm 1 1900 psi through annulas volume 210 bbls Total of 330 bbls bull headed. Shut down pumps 05:30 - 06:00 0.50 KILL P DECOMP Monitor well allow to heal 1 pressure down to 250 psi in 30 min. Continue to monitor. 06:00 - 11 :30 5.50 KILL P DECOMP Continue to monitor Well. Pressure continues to decrease on both Tbg/Csg. Tbg = 20 psi. Csg = 40 psi. Flow Tbg side. Observe 10.1 Ib/gal - 11.0 Ib/gal fluid returns. Flow Csg side. Observe 9.1 Ib/gal - 11.0 Ib/gal fluid returns. SI Well and Monitor. Tbg = 10 psi. Csg = 20 psi. Bring pump on line at 1.5 bpm down Tbg with 12.1 Ib/gal Brine. Continue to circulate down Tbg through Tbg punch holes at 2,500' until returns weight 12.11b/gal (22 bbls). SD and monitor Well dead...with much joy! 11 :30 - 12:00 0.50 WHSUR P DECOMP Set and test TWC. 12:00 - 13:00 1.00 WHSUR P I DECOMP Nipple down Production Tree. Printed: 7/18/2005 11 :20:30 AM ) ) RECEIVED BPEXPLORATION Page2bf 2 . .. ...... .. AUG 11 Z005 Operation$·Sumrnary.Report. 0 .0 A~~ka on & Gas Cons. GommU;Slon Anchorage Spud Date: 4/26/1985 End: 7/11/2005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/1 0/2005 7/11/2005 MPC-13 MPC-13 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 13:00 - 14:00 1.00 BOPSUP P DECOMP 14:00 - 14:30 0.50 BOPSUR P DECOMP 14:30 - 18:00 3.50 BOPSUR P DECOMP 18:00 - 19:30 1.50 PULL P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 22:30 2.00 PULL P DECOMP 22:30 - 23:30 1.00 EVAL P DECOMP 23:30 - 00:00 0.50 PULL P DECOMP 00:00 - 04:00 4.00 PULL P DECOMP 04:00 - 04:30 0.50 PULL P DECOMP 04:30 - 06:00 1.50 RUNCOMP RUNCMP 06:00 - 08:00 2.00 RUNCOMP RUNCMP 08:00 - 15:00 7.00 RUNCOMP RUNCMP 15:00 - 15:30 0.50 RUNCOMP RUNCMP 15:30 - 17:00 1.50 RUNCOMP RUNCMP 17:00 - 17:30 0.50 WHSUR P TUBHGR 17:30 - 18:30 1.00 BOPSUP P WEXIT 18:30 - 19:30 1.00 WHSUR P POST 19:30 - 20:00 0.50 WHSUR P POST 20:00 - 21 :00 1.00 DEMOB P POST Start: 7/8/2005 Rig Release: 7/11/2005 Rig Number: Description of Operations Nipple up Double Stub Adaptor, Test Spool, and BOP Stack. Rig up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. State's right to witness test waived by J. Chrisp. Pump out stack P/U lubricator pull TWC PJSM Pick up Make up Landing Jt to hanger back out lock downs pull hanger (80K) Lay down hanger and landing Jt. POOH 3-1/2" ESP completion to 2500' and lay down perforated Jt. Circulate volume around 190 bbls to evaluate KWB got some gas back Fluid back clean I Monitor well fluid droping POOH 3-1/2" ESP completion POOH 3-1/2" 9.2# L-80 Tbg rack back by Stds 239 Jts recovered 476 steel bands Lay down ESP pump. All Bands recovered. Clean and clear rig floor R/U Spooling unit rout new cable. Begin to pick-up and service new ESP Assembly. Make cable connection test conductivity RIH ESP completion as per instructions with XN nipple and 3 gas lift mandrels Make up landing Jt. Cut cable. Rig down running equipment Clean rig. Make cable connection. Secure and test Land Hanger (P/U Wt. 70K) (S/O Wt.56K) Set TWC. Drain BOPE Nipple down BOPE Nipple up Tree Test to 5000 psi Pull TWC and set BPV Rig down lines secure equipment clean rig RIG RELEASED 21:00 Printed: 7/18/2005 11 :20:30 AM ('" ( BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 O"""",'jl"<",I":;,;~"",'.""'.'p" '·~~l~. - j~ ~~,'. ' ,:'~ ;1" ..~ .~ '''''' '1-';; II',? / ,I:'~I' ~J July 26, 2005 Mr. Winton Aubert, P .E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 RECEIVED JUL 2 8 2005 Alaska Oil & Gas Cons. Commissàon Anchorage Subject: MPC-13 (PTD 1850670) Application for Cancellation of Sundry #304-129 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304-129. The sundry was for a corrective action plan to eliminate sustained casing pressure in the IA. A workover to run a new completion and ESP was completed on 07/11/05, returning the well to normal status. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincety, ~~CLf ~ Anna Dube Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 SCANNED AUG 0 2 2005 o ¡ blNAL ( STATE OF ALASKA Î Q =CEIVED ALASKA OIL AND GAS CONSERVATION COMMISSrO\- .. REPORT OF SUNDRY WELL OPERATf~§ Z005 1. Operations Performed: AtaskaJlH & Gas t;ons. Commlssio!l Abandon D Repair Well 0 PluQ PerforationsD StimuTate TI Anchor~ge OtherŒ) Cancel Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD 10-403 Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended WenD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO 9. Well Name and Number: MPC-13 10. Field/Pool(s): Kuparuk River Fieldl Kuparuk River Oil Pool, Milne Point Unit Service D 5. Permit to Drill Number: 185-0670 6. API Number 50-029-21328-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 ExploratoryD 52.00 8. Property Designation: ADL-025516 11. Present Well Condition Summary: Total Depth measured 8270 feet true vertical 7309.4 feet Effective Depth measured 8156 feet true vertical 7224.4 feet Plugs (measured) None Junk (measured) None Casing CONDUCTOR SURFACE PRODUCTION Length 80 4746 8204 Size 13-3/8" 48# H-40 9-518" 36# K-55 7 Inch 26 Lb L-80 MD 35 115 33 - 4779 32 - 8236 TVD 35.0 115.0 33.0 - 4623.5 32.0 - 7284.1 Burst Collapse 3520 7240 2020 5410 Perforation depth: Measured depth: 7770 - 7786, 7878 - 7881, 7890 - 7894, 7904 - 7910, 7990 - 8056 True vertical depth: 6934 - 6946.1, 7016 - 7017.9, 7025 - 7027.7, 7035 - 7039.8, 7100 - 7149.7 TubinQ ( size, Qrade, and measured depth): 3-1/2 Inch 9.3 Lb L-80 @ 30 7485 Packers & SSSV (type & measured depth): No Packer or SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFt .~' -,', . -:111!'1 Oil-Bbl Representative Daily AveraQe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 13 Prior to well operation: Subsequent to operation: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GlNJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: 304-129 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders 1 Anna Dube Printed Name Joe #ders 1 Anna ~JJÞeQ) n . Signature -J><fA,A..Å-^o....,> (,- ~ Title Well Integrity Coordinator Phone 659-5102 Date 7/26/05 Form 10-404 Revised 4/2004 RBDMSBFLAUG 012005 0 RIG! NAL MPC-13 (PTD #1850670) Internal Waiver Cancellation ) " Su bject: MPC-13 (PTD # 1850670) Internal Waiver Cancellation . , ,',' I, " ,', ,',' .,', ,,',' From: "Dube, Anna T" <Anna.Dube@BP.com> -4 ·J..1:(!7f; Date: Tue, 26 Ju12005 15:53:58 -0800 :¡;, I , To: "AOGCC - Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. jim _regg@admin.state.ak.us CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Holt, Ryan P (VECQ)" <Ryan.Holt@BP.com> Winton and Jim, ,]g- The internal BP waiver for TxlA communication with a failed ESP on well MPC-13 (PTD #1850670) has 7 (?~ been cancelled. A rig workover to run a new completion and ESP was completed on 07/11/05. The well has been reclassified as normal. The application for cancellation of sundry #304-129 has also been sent by mail. Please let us know if it is not received in the next couple of days. Please let me know if you have any questions. Thank you, }1.nna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED AUG 0 9 2005 1 of 1 7/27/2005 9:55 AM ¡-"\ 1"'""\ BP Exploration (Alaska) Inc. 900 E. Benson Blvd Anchorage, Alaska 99519-6612 April 13, 2004 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: MPC-13 (PTO 1850670) SCP Corrective Action Plan Follow-up Dear Mr. Maunder: Attached is form 10-404 to conclude the proposed corrective action plan for well MPC- 13 as referenced in AOGCC Sundry# 304-052. The action plan as described in Sundry# 304-052 has been completed and a new action plan will be forthcoming to deal with the Sustained Casing Pressure occurring in well MPC-13. If you require any additional information or clarification, please contact Mark Sauve (907) 564-4660. j;;<¡í Mark sau~ Artificial Lift Coordinator RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1"""'\ 1"'""\ 1. Operations Performed: Abandon 0 Alter casingD Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionO Re-enter Suspended Well 0 Other 00 Well Evaluation Name: BP Exploration (Alaska), Inc. 5. Permit to Drill Number: 185-0670 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development Œ] Stratigraphic D 9. Well Name and Number: MPC-13 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit ExploratoryD ServiceD 6. API Number 50-029-21328-00-00 52.00 8. Property Designation: ADL-025516 11. Present Well Condition Summary: Total Depth measured 8270 feet feet Plugs (measured) Junk (measured) None true vertical 7309.4 feet Effective Depth measured 8156 None true vertical 7224.4 feet Casing Length Size MD TVD Burst Collapse Conductor 80 13-3/8" 48# H-40 35 115 35.0 - 115.0 1740 750 Production 8204 7" 26# L-80 32 - 8236 32.0 - 7284.1 7240 5410 Surface 4746 9-5/8" 36# K-55 33 - 4779 33.0 - 4623.5 3520 2020 Perforation depth: Measured depth: 7770 - 7786, 7878 - 7881, 7890 - 7894, 7904 - 7910, 7990 - 7991, 7991 - 8009, 8009 - 8021, 8021 - 8055, 8055 - 8056 True vertical depth: 6933.92 - 6946.05, 7015.58 - 7017.85,7024.67 - 7027.7,7035.27 - 7039.81,7100.19 - 7100.94,7100.94 - 7114.47 7114.47 - 7123.49,7123.49 - 7148.98,7148.98.7149.72 Tubing (size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 30 7485 RECEIVED APR 1 4 2004 Packers & SSSV (type & measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Averaae Production or Iniection Data Gas-Me! I Water-Bbl Casing Pressure 0.005 110 2650 Alaska Oil & Gas Cons. Commission Anchorage 13 Well Shut-In 2500 Tubing Pressure 267 575 Prior to well operation: Subsequent to operation: Oil-Bbl 32 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or N/A if C.O. Exempt: 304-052 Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name i:k 5~ve /:l Signature f/' ~ ~ Title Milne Point Artifical Lift Coordinator Phone 564-4660 Date 4/13/04 ORIGINAL II1II8 8FL R t 4 1004 Form 10-404 Revised 12/2003 " . ~ ~ MPC-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/17/04 TESTED SSV. UNABLE TO TEST THE PILOT UNTIL WELL IS OPENED TO SUPPLY PRESSURE. TAGGED ESP @ 7495' WLM. CLEAN IMPRESSION TAGGED X-OVER @7483' WLM. SET GAUGE ASSEMBLY @ TOP GAUGE 7479' MD, BOTTOM GAUGE 7481' MD TOP OF SLIP STOP @ 7478' WLM. GAUGES STARTED AT 15:27 ** RDMO* 04/03/04 T/I/O=425/2500/700. PUMP 23 BBLS MEOH DOWN TUBING, 2 BBLS MEOH DOWN FLOWLINE TO FREEZE PROTECT WELL. FT/I/O=575/2500/700. FLUIDS PUMPED BBLS 25 25 Methenal TOTAL Page 1 ... ." BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 April 13,2004 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: MPC-13 (PTD 1850670) SCP Corrective Action Plan Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 for the proposed corrective action plan for well MPC-13. This request documents our proposed action plan to eliminate sustained casing pressure in the IA. A description summary of the proposal is included for the well. If you require any additional information or clarification, please contact myself at (907) 564-4660. ~ Mark Sauve Milne Point Artificial Lift Coordinator Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) MPC-13 completion diagram RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage 0 q r G I ~r A L BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.00 KB 8. Property Designation: ADL-025516 Stratigraphic 0 Service 0 9. Well Name and Number: MPC-13 10. FieldlPool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft): Effective Depth MD (ft): IEffective Depth TVD (ft): 7309.4 8156 7172.4 Length S ze MD TVD 1. Type of Request: Abandon D Alter CasinQ D D Change Approved Program 2. Operator Name: 3. Address: 11. Total Depth MD (ft): 8270 Casing Conductor 80 Production 8204 Surface 4746 Perforation Depth MD (ft): I 7770 - 7786 7878 - 7881 7890 - 7894 7904 - 7910 7990 - 7991 7991 - 8009 8009 - 8021 8021 - 8055 8055 . 8056 Packers and SSSV Type: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~/1't-{)'i Suspend D RepairWell D Pull Tubing D Operation Shutdown 0 PluQ Perforations 0 Perforate New Pool 0 PerforateD WaiverD StimulateD Time ExtensionD Re-enter Suspended WellD Annular Disposal D Other[XI Well Evaluation 4. Current Well Class: 5. Permit to Drill Numbe,r: 185-0670 V 6. API Number ~ 50-029-21328-00-00 Development ŒI Exploratory 0 Plugs (md): None Burst Junk (md): None Collapse 13-3/8" 48# H-40 7" 26# L-80 9-5/8" 36# K-55 Perforation Depth TVD (ft): 6934 6946.1 7016 7017.9 7025 7027.7 7035 7039.8 7100 7100.9 7101 7114.5 7114 7123.5 7123 7149.0 7149 7149.7 top 35 32 33 bottom top 115 8236 4779 Tubing Size: 3.5 .. 7485 bottom 115.0 7284.1 4623.5 Tubing Grade: L-80 35.0 32.0 33.0 1740 7240 3520 Tubing MD (ft): 30 750 5410 2020 9.3 # Packers and SSSV MD (ft): None 12. Attachments: None Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D ExploratoryD Developmentl!] ServiceD 14. Estimated Date for CommencinQ Operation April 15, 2004 16. Verbal Approval: Date: Commission Representative: 15. Well Status after proposed work: Oil!!] GasD PluggedD AbandonedD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Signature ¡;;:¿ ;JZ- Title Phone MPU, Aritificial Lift Coordinator 564-4660 4/13/04 Conditions of approval: Notify Commission so that a representative may witness Commission Use Onrv I Sundry Numbe':3¿:> ¥'- p? ,./ RECI::IVt:U APR 1 4 2004 Form 10-403 Revised 12/2003 Mechanciallntegrity Test D L~on Clearance D 4.{ t S" - 0 (Q s? ~'1 bQ. ~ "'<"L ~id . ~ Alaska Oil~Ga ~ons Commission BY ORDER OF fA .~ THE COMMISSION Date: ,I I ORIGINAL AI'R? 1l~ . I8J11SBFL SUBMIT IN DUPLICATE ~ MPC-13 Description Summary of Proposal 04/13/04 Problem: Producer with Sustained Casing Pressure on the IA. Well History and Status: Well MPC-13 (PTD 1850670) is a shut-in ESP producer that exhibits Sustained Casing Pressure in the IA (lAP of 2400 psi on 2/16/04). The production casing at MPC-13 contains 7",26#, L-80 casing with a rated burst pressure of 7240 psi (45% of burst pressure is 3258 psi). The purpose of the proposed work outlined below is to eliminate the sustained casing pressure on the IA. The following is a brief history of well events: . 08/23/96: Ran ESP. . OS/24/97: ESP Failed. . 02/17/04: Notified the AOGCC of SCP in the IA. . 03/18/04: Put well on cycle production (as per Sundry# 304-052) . 04/1/04: Shut-in well Based on the inflow information obtained during the two week flow period (3/18- 4/01) we believe it may be possible to successfully reduce IA pressures by flowing the well and adding tubing perforations at a point higher than currently exist. The tubing perforations would have the dual effect of allowing pressures to equalize at a shallower point (lowering the maximum pressure differential between IA and tubing at surface) and acting as a potential entry point for gas-lift should it become necessary to help sustain flow from the well. Proposed Action Plan: 1. Shoot holes in the production tubing @ approximately 2500' MD. 2. Place well on production attempting to reduce the IA pressure to below threshold levels via sustained free flow or continuous gas-lift. 3. Notify AOGCC of success or failure of this plan of action and submit a way forward by May 15, 2004. ORIGINAL PERFORATION SUMMARY SIZE SPF INTERVAL OPEN/SQZ'D 5" 12 7770' - 7786' OPEN 5" 12 7878' - 7881' OPEN 5" 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN ï 2-5/8" 4 7991' - 8009' OPEN I I I ,. I ' 11/3/94 PERFORATION SUMMARY I ,. ( .- .ofi I I I OPENI SQZ'D SIZE I SPF I INTERVAL I I I I I I 3-3/8" I 6 7770' - 7786' ! OPEN I I I I 3-3/8" I I OPEN , I 6 7990' - 8055' 1', I I" / / / / ...Å- TREE: 3 1/8" - 5M FMC WELLHEAD: 11" 5M FMC (Phase 1&2) wI 3.5" FMC Tubing Hanger, 3.5" NSCT threads, 3.0" CIW BPV profile 133/8" 48#1ft H-40 I_, 115' KOP @ 3000' MAX HOLE Angle 42.75 DEG AT 6000' MD 95/8", 36#/ft, K-55 Butt 4779' I -. Cable #2 , DL-90 I 3.5", 9.2" #/ft , L-80 Btc. ( id 2.992" .0087 Bblsl ft ) **** Note: 4 (3/8" ) holes punched in (10') 2-7/8" pup. Holes were punched to free flow well. ESP cable has shorted. DATE 11/7/94 REV. BY OBR COMMENTS RWO 8124/96 MOO ;SP RWO 4 ES MPU C -13 ORIG. KB. ELEV = 52' (Audi 3) ORIG. GL. ELEV = 17' (Audi 3) Cameo 3.5" x 1" I sidepocket KBUG GLM 137' I ~ 27/8" x 10' Pup on top of ESP Centrilift GC 2200 ESP, series 513, GPMTARC, 103 Stg. Centrilift GSTDBHLB seal section I 7,485' I I 7.501' I Centrilift KME1 series, 165 1 7.513' I hp motor, 2230 v. / 43 amps. Centrilift PHD I 7.532' I 4-ES PBTD 8/22/96 @ 8,144' ORIG. PB I 8,156' 7" 26#, L-80, BTRS I 8,236' MILNE POINT UNIT WELL C-13 API NO: 50-029-21328 BP EXPLORATION (AK) Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer... 1"'\S~t'--~~~,- ~,\\..Q~ '\ (' ~Q \\ \ "'\<è.<::f\-\l ~ \\.'-.)~"t)~.. rSùSS(~c,\ \-\r.-,,,,-> \e:., \"-Còç\~-\ Ð.Ç-. 0.. "\)~~, a\-~ç¿~\ > ~~. ~\ \ \ -Ç.\",J.. S:"'o'-.)~ ro\\<:..~ O~ d-C~<L~" ~()'.A,,^,\\,,«' ~\\) o..~ '\:.~~ c..c'~\,~\\O\'~. \,,)b\"J~ Thanks John. I will look. for the hard copy of the MPC-13 sunc \ ~ o...D'¿ '~<"'()\,",~"I\'\C.o.:\-"~~ 0.\\ -\\...e \\ N\.<::.. '\"\-\,<";) c..u"~~rb- MPU, Wells Ops Coord wrote: ""h-o.\,þ\~ V'~~~'\'é~ ~\-\~S~ T '\ 'f'\ ~ \....\'( 'þ..., (It -rr1 J./"';).. 'S om, C-13 is the only well that was recently flowed with a failed ESP. Last year we had a well on E-pad that was also flowed with a failed ESP, but that well has been SI and freeze protected and will be locked out to prevent it from being returned to production. There are no other "cycle wells" being operated like MPC-13 and no other wells being flowed where the pump is operable but shut-down. If you have any other questions, or need any additional information, please let me know. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 SÇ¡~NED AU G 0 1 2.0D7 -----Original Message----- _, From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, February 20, 2004 11:24 AM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail); Sauve, Mark A Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP John, Your plan to insure that SSVs are in compliance is appropriate. Cycle wells can often drop through the cracks. In MPC-13's case, it is a cycle well that operates differently from most of the other wells out there at Milne. Assuring that, as best you can demonstrate, that ån SSV will function if the need should arise is very important. Part of your message is a little confusing. I looked at CO 390 which authorizes the installation of ESPs and eliminates packers in Milne Point Kuparuk wells. It would seem'tIiäfthere could be two "cases", one where the well produces with the pump operating as normal and the others where the pump has failed and the well 10f5 2/20/2004 1 :43 PM Re: MPC-13 (PTD #1850670) SI Artifiçial Lift Producer... '--, . . does not produce. MPC-13 gets into a gray area where the pump has failed, but where the reservoir conditions are such that sufficient energy is intermittently available to make the well capable of flowing. That case would seem to me to be beyond what the CO authorizes. If there are similar wells out there, I believe you should identify them to us and make a sundry request with regard to operating the well. Your message prompts two questions, are there other "cycle" wells being operated like MPC-13 and (based on the last sentence of the first paragraph), are there wells at Milne where the pump is operable but it is shut down and the well is being flowed?? Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Tom, As a follow-up to our phone conversation this morning - Our plan to assure that cycle wells will not miss their 6 month SSV test will be to lock-out the SSV when the well is switched to off cycle. This will assure that the operator cannot put a well on line without getting the Wells Operations Coordinator to verify the SSV is in compliance. Further, our operators have been informed that your interpretation of CO 390 is that in order to flow a well equipped with an ESP, the ESP must be functional (unless approval is granted by the AOGCC). If you have any questions, or need additional information, please don't hesisitate to contact either myself (1-907-670-3387) until 2/23/04, or Mark Sauve (1-907-564-4660) after 2/22/04. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, February 19, 2004 1:16 PM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail); MPU, Well Operations Supervisor; Sauve, Mark A; Cubbon, John R Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP 20f5 2/20/2004 1 :43 PM Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer... . , . . John, It would appear that the Commission should have been notified of the ability of this well to flow some time ago. 20 AAC 25.200(d) requires wells capable of unassisted flow be equipped with ...a packer. I also had the record on the SV tests pulled and we only have records for 3 tests since 1997. Do you have any other records?? All these tests were performed by the operator. Since the well was on and off during most of this time, is there a practice at Milne to test SV's for wells that have been SI and then brought back on?? If the tubing pressure builds up like the lA, it would appear that there would be sufficient pressure available to test the SV as the well is prepared for operation. 1850670 1850670 1850670 MILNE PT UNIT KR C-13 MILNE PT UNIT KR C-13 MILNE PT UNIT KR C-13 5/7/1997 6/6/2001 8/19/2003 11/6/1 12/6/2' 2/19/2, If there are other wells that are operated in similar fashion, please send us the information on each. I have received the electronic information you have sent for MPC-13 diagnostics. I will get back to you on that work. Please call with any questions. Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Tom, In response to your questions, the well will intermittently flow on its own. This area of the field is charged with injection gas and over time the WHP builds up enough that the well will flow for brief periods of time. As per our phone conversation earlier today, we will submit a form 10-403 outlining our plans to flow the well prior to performing the pressure buildup test and our plans for dealing with the SCP issue. If you have any additional questions, please feel free to contact me. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 -----Original Message----- 30f5 2120/2004 1 :43 PM Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer... . . . .' From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, February 17, 2004 11:59 AM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail); MPU, Well Operations Supervisor; Sauve, Mark A; Cubbon, John R Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP Hi John, Talked to Kevin yesterday and he said you were at Milne. With regard to the reporting for MPC-13 and any other wells that might come up, including them with the report Joe sends out is fine. Main thing is that we need the report. I looked at MPC-13's file. It appears that the present ESP completion was run August 1996. In your message you indicate the pump failed in 1997. How has the well been producing since then?? Has the well been gas lifted or is it capable of flowing?? Accoring to the production report I can access, the well has only had production in 24 discontinuous months in the last 6 years. Has there been some change in the operational characteristics of the well?? Thanks in advance for your reply. Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Hi Tom and Jim, Milne Point producer MPC-13 (PTD #1850670) has been found to have sustained casing pressure on the IA (T/I/O = SI/2400/200 psi; lAP < 45% of Pb). This well is a submersible pump completion (the submersible pump failed in 1997) . Our plan of action for this well is as follows: 1. Flow test the well up the tubing for a brief flow test (up to 14 days), followed by a pressure buildup test to evaluate reservoir properties and aid in the economic evaluation of a RWO or sidetrack. 2. Once the buildup test and economic evaluation has been completed, either secure the well for long term SI or repair. 40f5 2/20/2004 1 :43 PM Re: MPC-13 (PTD # 1850670) SI Artificial Lift Producer... . . . . In order to keep you up to date on the status of our diagnostics, the well will be included in the weekly AOGCC SCP report which is e-mailed to the AOGCC from Prudhoe Bay every Sunday evening. If you have any questions or prefer a different approach, please either contact myself (907-670-3387 from 2/17 - 2/23/04) or Mark Sauve (564-4660, after 2/23/04) . Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 50f5 2/20/2004 1 :43 PM e) . STATE OF ALASKA ALASKA OIL AND GAS CONSERV A nON COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: ) ) ) Milne Point Field: All Pools ) ) September 8, 2003 ) ) Conservation Order No. 496 Proposed Rules Regulating Sustained Casing Pressures in Development Wells in All Pools Within the Milne Point Field. IT APPEARING THAT: 1. On its own motion, the Alaska Oil and Gas Conservation Commission ("Commission" or "AOGCC") proposed to adopt rules regulating sustained annulus pressures in Milne Point Field development wells. 2. Notice of opportunity for a public hearing on the proposal was published III the Anchorage Daily News on June 30, 2003. 3. No request for a hearing was received. 4. No written comments on the proposal were received. FINDINGS 1. In considering proposed rules regulating sustained casing pressures in Milne Point Field development wells, the Commission reviewed: the annular pressure management policies submitted by the operator, BP Exploration (Alaska) Inc. (BPXA); Applied Drilling Engineering by Bourgoyne, et al.; the Halliburton Cementing Tables; the Commission well files for the wells on BPXA's "A-B3" status list and on BPXA's waived well list; an annular pressure simulator developed by the Commission staff as contained in an MS Excel spreadsheet; information on well pressures provided by the operator; and the hearing record in connection with Conservation Order No. 492. 2. Annulus pressure is common in development wells. Pressures may be purposely imposed, thermally induced or the result of leaks in tubing, casing, packer or other well components. 3. Excessive annular pressure can develop in wells as a result of thermal effects. Well startup can involve significant annular pressure increases due to fluid expansion as a well heats above ambient temperature. Changing produced fluid characteristics and production mechanisms can also create thermal conditions that affect annular pressures. . . . Conservation Order 496 September 8, 2003 Page 2 of 4 4. For service (injection) wells, AOGCC regulations require, unless superseded by a Commission order, an operator to notify the Commission by the next working day if an injection rate, operating pressure observation, or pressure test indicates pressure communication or leakage in any casing, tubing, or packer. The operator must implement corrective action or increased surveillance, as the Commission requires (20 AAC 25.252(e) and 20 AAC 25.402(t)). 5. Unless specifically authorized by the Commission, AOGCC regulations require all producing wells capable of unassisted flow to be completed with suitable tubing and packer that effectively isolates the tubing-casing annulus fTom fluids being produced. Wellhead equipment must include appropriate gauges and valves on the tubing, casing-tubing annulus and casing-casing annuli to show surface pressures and control flow for the range of conditions expected (20 AAC 25.200(c) and (d)). 6. No current AOGCC regulation or Commission order for the Milne Point Field establishes annular pressure management requirements for producing wells, similar to those for injection wells. However, Conservation Order No. 492 establishes such requirements for producing wells in the Prudhoe Bay Field. 7. Several practicable techniques are available to manage annular pressures including manual pressure bleeding and engineered solutions such as pressure controls and pressure relief systems. 8. Values of "burst pressure rating" and "minimum internal yield pressure" of well tubulars are numerically equal. 9. Pertinent characteristics of well construction in the Milne Point Field are similar to those in the Prudhoe Bay Field. 10. Pressure in an active Milne Point Field well not exceeding 45% of the burst pressure rating, or minimum internal yield pressure, of well tubulars is within the range of pressure that will not result in failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. 11. The operator relies on a well pressure limit waiver process to continue operating Milne Point Field wells that exhibit inner annulus pressure exceeding 2000 psig with two pressure bleeds per week, or outer annulus pressure exceeding 1000 psig with two pressure bleeds per week. CONCLUSIONS 1. There is a need for regulatory oversight of the management of Milne Point Field wells that exceed specific pressure thresholds, by administering rules regulating annular pressures. This methodology is consistent with similarly intended efforts by other regulatory agencies. 2. The objectives of rules regulating sustained annular pressures in Milne Point Field development wells are to conserve Alaska petroleum resources and protect human safety and the environment, through proper management of annular pressures. Proper annular pressure management aims to prevent failure of well integrity, uncontrolled release of fluid or pressure, or threat to human safety. . _·~'·c· . . . 135- 0 fo~7 Õ BP Exploration (Alaska) Inc. Post Office Box 196612 Mail Stop MB-4-2 Anchorage, Alaska 99519-6612 February 18, 2004 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. ih Ave. Anchorage, Alaska 99501 SCANNED AU G 0 1 Z007 , . ...;-~.... .. Subject: MPC-13 (prO 1850670) SCP Corrective Action Plan Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 for the proposed corrective action plan for well MPC-13. This request documents our proposed action plan to eliminate sustained casing pressure in the IA. A description summary of the proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either Mark Sauve (907) 564-4660 or John Cub bon at (907) 670-3387. g¡~ot John Cubbon Well Operations Coordinator Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Well bore Schematic FEB 2 3 2004 J\Îa5lHì ORIGINAL e) STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 to Áb"$ ~ ~~,/ 0;, <. StratigraphicD Service D 9. Well Name and Number: MPC-13 10. Field/Pool(s): Ku aruk River Field I Ku aruk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 7309.4 8156 7172.4 Size MD TVD 1. Type of Request: Suspend 0 Repair Well 0 Pull Tubing 0 Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 52.00 KB 8. Property Designation: ADL-025516 3. Address: 11. Total Depth MD (ft): 8270 ./ Casing Length Conductor Production Suñace Perforation Depth MD (ft): 1110 - 1186 1818 - 1881 1890 - 1894 1904 - 1910 1990 - 1991 1991 - 8009 8009 - 8021 8021 - 8055 8055 - 8056 Packers and SSSV Type: 80 8204 4146 13-318" 48# H-40 1" 26# L-SO 9-518" 36# K-55 Perforation Depth TVD (ft): 6934 6946.1 1016 1011.9 1025 1021.1 1035 1039.8 1100 1100.9 1101 1114.5 7114 7123.5 7123 7149.0 1149 7149.7 None 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commenci 0 ration 16. Verbal Approval: Commission Representative: March 1, 2004 Date: Operation Shutdown D Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Annular DisposalO OtherD PerforateD WaiverŒJ StimulateD Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Num r: 185-0670 Development ŒI Exploratory D 6. API Number 50-029-21328-00-00 Plugs (md): None Burst Junk (md): None Collapse to bottom to bottom 35 115 35.0 115.0 1740 750 32 8236 32.0 1284.1 1240 5410 33 4779 33.0 4623.5 3520 2020 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 " 9.3 # L-SO 30 7485 \t'\O~«:'\-o..-\\\$L tSY" '\ ( f ~S-~Sd- None 13. Well Class after proposed work: ExploratoryD DevelopmentŒJ ServiceD 15. Well Status after proposed work: Oil I!] GasO WAG D GINJO PluggedO AbandonedO WINJO WDSPLO Prepared by Garry Catron 5644657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact John Cubbon Title MPU Well 0 rations Coordinator Phone 4 Plug Integrity 0 Conditions of approval: Notify Commission so that a representative may witness ommlsslon Mechanciallntegrity Test 0 Location Clearance 0 C\ FEB 2 3 2004 \e~ ¢Q,~\'i~\"'>~-o\)Iè..~~'V\0t.cl \',4"5-(:)'-\ . ... .' , A1a"ka Oil & Gas Cons. Corm' BY ORDER OF . m:h THE COMMISSION Date: ORIGINAL l~8Fl su . ~~-.!o . . . MPC-13 Description Summary of Proposal 02118/04 Problem: Producer with Sustained Casing Pressure on the IA. Well History and Status: Well MPC-13 (PTD 1850670) is a shut-in ESP producer that exhibits Sustained Casing Pressure in the IA (lAP of 2400 psi on 2/16/04). The production casing at MPC-13 contains 7",26#, L-80 casing with a rated burst pressure of 7240 psi (45% of burst pressure is 3258 psi). The purpose of the proposed work outlined below is to eliminate the sustained casing pressure on the IA by either repairing the well or securing for long-term shut-in (L TSI). The following is a brief history of well events: · 08/23/96: Ran ESP. · OS/24/97: ESP Failed. · 02/17/04: Notified the AOGCC of SCP in the IA. This sundry request is to formally submit our action plan to evaluate the well for repair or L TSI. Proposed Action Plan: 1. Allow the well to flow up the tubing for a period of 14 days, followed by a pressure buildup test. The purpose is to evaluate reservoir properties for RWO or sidetrack. 2. Perform an economic analysis of workover and sidetrack options vs. securing the well for L TSI. 3. Notify AOGCC of plans to either repair or secure the well by April 15, 2004. -- 7 ~ '~ , TREE: 3 1/S" - 5M FMC WELLHEAO: 11" 5M FMCa.1&2) wi 3.5" FMC Tubing Hange~SCT threads, 3.0" CIW BPV profile 13 3/S" 48#1ft H40 115' 1- KOP @ 3000' MAX HOLE Angle 42.75 OEG AT 6000' MO 9 5/S", 36#/ft, K-55 Butt I 4779' I - Cable #2 , OL-90 3.5" , 9.2" #1ft , L-60 Btc. ( id 2.992" .0087 Bblsl ft ) **** Note: 4 (3/8" ) holes punched in (10') 2-7/8" pup. Holes were punched to free flow well. ESP cable has shorted. ORIGINAL PERFORATION SUMMARY SIZE SPF INTERVAL OPEN/SQZ'O 5" 12 7770' - 7786' OPEN 5" 12 7878' - 7881' OPEN 5" 12 7890' - 7894' OPEN 5" 12 7904' - 7910' OPEN 5" 12 8021' - 8056' OPEN 2-5/8" 4 7991' - 8009' OPEN 11/3/94 PERFORATION SUMMARY SIZE I SPF I INTERVAL OPEN! SQZ'O 3-3/8" I 6 7770' - 7786' OPEN 3-3/8" 6 7990' - 8055' OPEN OATE REV. BY 11/7/94 DBR RWO 8/24/96 MDO SPRWO 4ES MPU C -13 COMMENTS ORI. ELEV = 52' (Audi 3) OR ELEV = 17' (Audi 3) Cameo 3.5" x 1" sidepoeket KBUG GLM 137' 27/8" x 10' Pup on top of ESP Centrilift GC 2200 ESP, series 513, GPMTARC, 103 Stg. Centrilift GSTDBHLB seal section 7 ,485' 7.501' Centrilift KME1 series, 165 1 7.513' hp motor, 2230 v. /43 amps. Centrilift PHD 7.532' 4-ES PBTD 8/22/96 @ 8,144' ORIG. PB I 8,156' 7" 26#, L-80, BTRS I 8,236' MilNE POINT UNIT WEll C-13 API NO: 50-029-21328 Re: MPC-13 (PTD # 1850670) 81 Artificial Lift Producer... . . Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP From: Thomas Maunder <tom _maunder@admin.state.ak.us> Date: Fri, 20 Feb 2004 13:39:55 -0900 To: "MPU, Wells Ops Coord" <MPUWellsOpsCoord@BP.com> CC: Jim Regg <jim _regg@admin.state.ak.us> Thanks John. I will look for the hard copy of the MPC-13 sundry. MPU, Wells Ops Coord wrote: Tom, C-13 is the only well that was recently flowed with a failed ESP. Last year we had a well on E-pad that was also flowed with a failed ESP, but that well has been SI and freeze protected and will be locked out to prevent it from being returned to production. There are no other "cycle wells" being operated like MPC-13 and no other wells being flowed where the pump is operable but shut-down. If you have any other questions, or need any additional information, please let me know. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, February 20, 2004 11 :24 AM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail); Sauve, Mark A Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP John, Your plan to insure that SSV s are in compliance is appropriate. Cycle wells can often drop through the cracks. In MPC-13's case, it is a cycle well that operates differently from most of the other wells out there at Milne. Assuring that, as best you can demonstrate, that an SSV will function if the need should arise is very important. Part of your message is a little confusing. I looked at CO 390 which authorizes the installation of ESPs and eliminates packers in Milne Point Kuparuk wells. It would seem that there could be two "cases", one where the well produces with the pump operating as normal and the others where the pump has failed and the well lof5 2/27/20043:06 PM Re: MPC-13 (PTD #1850670) 81 Artificial Lift Producer... . . does not produce. MPC-13 gets into a gray area where the pump has failed, but where the reservoir conditions are such that sufficient energy is intermittently available to make the well capable of flowing. That case would seem to me to be beyond what the CO authorizes. If there are similar wells out there, I believe you should identify them to us and make a sundry request with regard to operating the well. Your message prompts two questions, are there other "cycle" wells being operated like MPC-13 and (based on the last sentence of the first paragraph), are there wells at Milne where the pump is operable but it is shut down and the well is being flowed?? Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Tom, As a follow-up to our phone conversation this morning - Our plan to assure that cycle wells will not miss their 6 month SSV test will be to lock-out the SSV when the well is switched to off cycle. This will assure that the operator cannot put a well on line without getting the Wells Operations Coordinator to verify the SSV is in compliance. Further, our operators have been informed that your interpretation of CO 390 is that in order to flow a well equipped with an ESP, the ESP must be functional (unless approval is granted by the AOGCC). If you have any questions, or need additional information, please don't hesisitate to contact either myself (1-907-670-3387) until 2/23/04, or Mark Sauve (1-907-564-4660) after 2/22/04. Thanks, John Cubbon MPU Well Operations Coordinator 1-907 -670-3387 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, February 19, 2004 1:16 PM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail); MPU, Well Operations Supervisor; Sauve, Mark A; Cubbon, John R Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP 20f5 2/27/20043:06 PM Re: MPC-13 (PTD #1850670) 81 Artificial Lift Producer... . . John, It would appear that the Commission should have been notified of the ability of this well to flow some time ago. 20 AAC 25.200(d) requires wells capable of unassisted flow be equipped with ...a packer. I also had the record on the SV tests pulled and we only have records for 3 tests since 1997. Do you have any other records?? All these tests were performed by the operator. Since the well was on and off during most of this time, is there a practice at Milne to test SV's for wells that have been SI and then brought back on?? If the tubing pressure builds up like the lA, it would appear that there would be sufficient pressure available to test the SV as the well is prepared for operation. 1850670 1850670 1850670 MILNE PT UNIT KR C-13 MILNE PT UNIT KR C-13 MILNE PT UNIT KR C-13 5/7/1997 6/6/2001 8/19/2003 11/6/1' 12/6/2' 2/19/2' If there are other wells that are operated in similar fashion, please send us the information on each. I have received the electronic information you have sent for MPC-13 diagnostics. I will get back to you on that work. Please call with any questions. Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: Tom, In response to your questions, the well will intermittently flow on its own. This area of the field is charged with injection gas and over time the WHP builds up enough that the well will flow for brief periods of time. As per our phone conversation earlier today, we will submit a form 10-403 outlining our plans to flow the well prior to performing the pressure buildup test and our plans for dealing with the SCP issue. If you have any additional questions, please feel free to contact me. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 -----Original Message----- 30f5 2/27/20043:06 PM Re: MPC-13 (PTD #1850670) 81 Artificial Lift Producer... . . From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, February 17, 2004 11:59 AM To: MPU, Wells Ops Coord Cc: Jim Regg (E-mail)¡ MPU, Well Operations Supervisor¡ Sauve, Mark A¡ Cubbon, John R Subject: Re: MPC-13 (PTD #1850670) SI Artificial Lift Producer with SCP Hi John, Talked to Kevin yesterday and he said you were at Milne. With regard to the reporting for MPC-13 and any other wells that might come up, including them with the report Joe sends out is fine. Main thing is that we need the report. I looked at MPC-13's file. It appears that the present ESP completion was run August 1996. In your message you indicate the pump failed in 1997. How has the well been producing since then?? Has the well been gas lifted or is it capable of flowing?? Accoring to the production report I can access, the well has only had production in 24 discontinuous months in the last 6 years. Has there been some change in the operational characteristics of the well?? Thanks in advance for your reply. Tom Maunder, PE AOGCC MPU, Wells Ops Coord wrote: '. Hi Tom and Jim, Milne Point producer MPC-13 (PTD #1850670) has been found to have sustained casing pressure on the IA (TjIjO = SIj2400j200 psi¡ IAP < 45% of Pb). This well is a submersible pump completion (the submersible pump failed in 1997) . Our plan of action for this well is as follows: 1. Flow test the well up the tubing for a brief flow test (up to 14 days), followed by a pressure buildup test to evaluate reservoir properties and aid in the economic evaluation of a RWO or sidetrack. 2. Once the buildup test and economic evaluation has been completed, either secure the well for long term SI or repair. 40f5 2/27/20043:06 PM Re: MPC-13 (PTD #1850670) 81 Artificial Lift Producer... . . In order to keep you up to date on the status of our diagnostics, the well will be included in the weekly AOGCC SCP report which is e-mailed to the AOGCC from Prudhoe Bay every Sunday evening. If you have any questions or prefer a different approach, please either contact myself (907-670-3387 from 2/17 - 2/23/04) or Mark Sauve (564-4660, after 2/23/04) . Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 50[5 2/27/2004 3 :06 PM B. P. EXPLORATION C PAD, WELL NO. MPC-13 MILNE POINT FIELD, NORTH SLOPE, ALASKA Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date: 16-JANUARY, 2001 Job number: AK0101GCE501 CONTENTS JOB NUMBER' AK0101GCE501 1. DISCUSSION , SURVEY CERTIFICATION SHEET 1 SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL Sm EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0101GCE501 Tool 938 was run in WELL# MPC-13 on SCHLUMBERGER 7/32" WIRELINE inside 3.5" TUBING. The survey was run without any problems. SURVEY CERTIFICATION SHEET ' JOB NUMBER' AK0101GCE501 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0101GCE501 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER WIRELINE LOCATION: C PAD WELL: MPC-13 LATITUDE: 70.50 N LONGITUDE: 149.1 W SURVEY DATE: 'SURVEY TYPE : 16-JANUARY, 2001 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 52.0' MAX. SURVEY DEPTH: 7450' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 0-7450' APl NUMBER: TARGET DIRECTION: 050-029-21328 150.51 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyrodata Directional Survey for B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 Run Date: 1/16/01 Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.490000 deg. N Sub-sea Correction from Vertical Reference: : Azimuth Correction: Gyro: Bearings are Relative to True North 52.00 ft. Proposed Well Direction: 150.510 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 0.0 0.00 0.00 0.00 100.0 0.15 70.33 0.15 200.0 0.16 122.77 0.14 300.0 0.09 357.80 0.22 400.0 0.02 16.92 0.08 500.0 0.20 54.67 0.19 600.0 0.24 66.71 0.06 700.0 0.21 22.50 0.17 800.0 0.19 73.13 0.17 900.0 0.32 63.77 0.14 1000.0 0.37 53.09 0.09 1100.0 0.30 65.10 0.10 1200.0 0.21 115.65 0.23 1300.0 0.27 139.21 0.11 1400.0 0.30 129.60 0.06 1500.0 0.34 120.10 0.06 1600.0 0.40 102.37 0.13 1700.0 0.43 83.78 0.14 1800.0 0.49 80.53 0.06 1900.0 0.45 80.05 0.04 2000.0 0.39 89.21 0.09 2100.0 0.38 94.51 0.04 2200.0 0.41 103.48 0.07 2300.0 0.36 123.46 0.14 2400.0 0.41 150.51 0.19 CLOSURE DIST. AZIMUTH feet deg. 0.0 -52.0 0.0 100.0 48.0 0.0 200.0 148.0 0.2 300.0 248.0 0.2 400.0 348.0 0.1 500.0 448.0 0.1 600.0 548.0 0.1 700.0 648.0 0.0 800.0 748.0 -0.1 900.0 848.0 -0.0 1000.0 948.0 -0.0 1100.0 1048.0 -0.0 1200.0 1148..0 0.1 1300.0 1248.0 0.5 1400.0 1348.0 1.0 1500.0 1448.0 1.5 1600.0 1548.0 2.0. 1700.0 1648.0 2.4 1800.0 1748.0 2.6 1900.0 1848.0 2.9 2000.0 . 1948.0 3.2 2100.0 2048.0 3.6 2200.0 2148.0 4.0 2300.0 2248.0 4.5 2400.0 2348.0 5.2 0.0 0.0 0.1 70.3 0.4 88.1 0.5 88.2 0.5 77.4 0.7 1.0 1.4 1.7 2.1 2.7 3.3 3.7 3.9 4.1 4.5 5.0 5.7 6.5 7.3 8.1 8.7 9.4 10.0 10.4 70.5 67.2 61.7 58.8 60.5 60.0 59:7 62.5 68.0 74.4 79..9 83.6 84.7 84,4 83.9 84.0 84.6 85.6 87.4 90.2 HORIZONTAL COORDINATES feet 0.00 N 0.04 N 0.01 N 0.02 N 0.11 N 0.22 N 0.40 N O.66 N 0.88 N 1.05 N 1.37 N 1.67 N 1.70 N 1.45 N 1.10 N 0.79 N 0.56 N 0.53 N 0.64 N 0.78 N 0.85 N 0.83 N 0.72 N 0.46 N 0.03 S 0.00 E 0.12 E 0.36 E 0.48 E 0.48 E 0.63 E 0.96 E 1.22 E 1.45 E 1.85 E 2.36 E 2.86 E 3.27 E 3.59 E 3.95 E 4.41 E 5.00 E 5.72 E 6.51 E 7.31 E 8.03 E 8.70 E 9.38 E 10.00 E 10.44 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number:- AK0101GCE501 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 0.12 148.00 0.29 2600.0 0.09 222.17 0.13 2700.0 0.18 223.17 0.09 2800.0 0.05 201.71 0.13 2900.0 0.18 25.86 0.24 3000.0 0.91 198.67 1.10 3100.0 3.45 176.28 2.63 3200.0 5.94 168.26 2.57 3300.0 8.68 163.69 2.80 3400.0 11.76 158.17 3.23 3500.0 15.28 158.61 3.52 3550.0 16.61 156.94 '2.83 3600.0 17.75 152.49 3.47 3650.0 18.77 149.45 2.79 3700.0 19.74 146.82 2.60 3750.0 20.69 147.04 1.92 3800.0 21.62 148.68 2.20. 3850.0 22.46 150.28 2.06 3900.0 23.34 150.82 1.81 3950.0 24.48 151.29 2.33 4000.0 25.79 151.90 2.67 4050.0 27.00 152.61 2.50 4100.0 28.26 153.45 2.64 4150.0 29.20 154.24 2.01 2500.0 2448.0 5.6 2600.0 2548.0 5.8 2700.0 2648.0 5.8 2800.0 2748.0 5.9 2900.0 2848.0 5.8 3000.0 2948.0 6.3 3099.9 .3047.9 9.5 3199.5 3147.5 17.2 3298.7 3246.7 29.4 3397.1 3345.1 46.9 3494.3 3442.3 70.0 3542.4 3490.4 83.7 3590.2 3538.2 98.4 3637.7 3585.7 114.0 3684.9 3632.9 130.5 3731.8. 3679.8 147.8 ' 3778.4 3726.4 165.8 3824.8 3772.8 184.5 3870.8 3818.8 204.0 3916.5 3864.5 224.3 10.7 92.3 10.7 93.1 10.5 94.0 10.4 94.9 10.5 94.4 10.4 11.4 17.5 29.4 47.0 70.3 84.0 98.8 114.4 130.8 147.9 165.9 184.6 204.1 224.3 3961.8 3909.8 245.5 245.6 4006.6 3954.6 267.7 267.8 4050.9 3998.9 290.9 291.0 4094.7 4042.7 314.9 315.0 97.8 116.9 139.2 150.2 154.1 155.5 155.9 155.7 155.0 154.2 153.3 152.7 152.4 152.2 152.1 152.1 152.1 152.2 152.3 0.43 S 0.57 S 0.74 S 0.90 S 0.80 S 1.41 S 5.17 S 13.24 S 25.56 S 42.26 S 63.99 S 76.70 S 90.04 S 103.73 S 117.72 S 132.20 S 147.48 S 163.64 S 180.58 S 198.32 S 217.00 236.67 257.34 278.92 10.67 E 10.67 E 10.52 E 10.39 E 10.45 E 10.26 E 10.20 E 11.45 E 14.62 E 20.53 E 29.13 E 34.33 E ,40.65 E 48.26 E 56.97 E 66.40 E 75.99 E 85.52 E 95.08 E 104.89 E 114.99 E 125.33 E 135.85 E 146.44 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number'. AK0101GCE501 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE DEPTH SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet feet deg. 100 ft. 4200.0 29.31 155.18 0.95 4138.3 4086.3 339.2 4250.0 29.73 155.82 1.06 4300.0 30.72 156.85 2.23 4350.0 31.73 158.00 2.34 4400.0 32.96 1.58.79 2.61 4450.0 33.91 159.38 2.00 4500.0 34.46 159.51 1.12 4550.0 34.50 159.80 0.34 4600.0 34.55 159.86 0.12 4650.0 34.55 160.05 0.22 4700.0 34.38 160.15 0.35 4750.0 33.71 160.32 1.35 4800.0 33.91 161.67 1.56 4850.0 34.19 161.40 0.64 4900.0 34.50 161.27 0.63 4950.0 34.99 160.96 1.05 5000.0 36.43 159.73 3.21. 5050.0 37.62 158.59 2.75 5100.0 38.13 158.18 1.14 5150.0 38.02 155.15 3.74 5200.0 38.04 153.76 1.72 5250.0 38.49 '153.54 0.94 5300.0 38.51 153.25 0.37 5350.0 39.00 153.33 0.98 4181.9 4129.9 363.8 4225.1 4173.1 388.8 4267.8 4215.8 414.5 4310.1 4258.1 441.0 4351.8 4299.8 468.3 339.4 152.5 364.0 152.7 389.2 152.9 415.0 153.2 441.6 153.5 469.1 153.8 4393.1 4341.1 496.0 497.0 4434.4 4382.4 524.0 525.2 4475.6 4423.6 551.9 553.4 4516.7 4464.7 579.9 581.7 4558.0 4506.0 607.8 609.9 4599.4 4547.4 635.4 637.8 4640.9 4588.9 662.8 665.5 4682.4 4630.4 690.2 693.3 4723.6 4671.6 717.9 721.4 4764.7 4712.7 746.0 749.8 4805.3 4753.3 774.7 778.9 4845.2 4793.2 804.5 809.0 4884.7 4832.7 834.9 839.7 4924.1 4872.1 865.5 870.5 4963.5 4911.5 896.3 901.3 5002.7 .. 4950.7 5041.8 4989.8 5080.8 5028.8 927.2 958.3 989.5 932.2 963.3 994.5 154.2 154.5 154.7 155.0 155.2 155.4 155.7 155.9 156.1 156.3 156.5 156.6 156.6 156.6 156.6 156.5 156.4 156.3 HORIZONTAL COORDINATES feet 301.01S 323.42 S 346.48 S 370.41S 395.28 S 421.02 S 447.32 S 473.86 S 500.47 S 527.10 S 553.71S 580.05 S 606.35 S 632.91S 659.64 S 686.60 S 714.08 S 742.21S 770.75 S 799.06 S 826.85 S 854.60 S 882.43 S 910.39 S 156.88 E 167.09 E 177.19 E 187.14 E 196.98 E 206.82 E 216.68 E 226.52 E 236.29 E 246.01E 255.64 E 265.10 E 274.16 E 283.03 E 292.06 E 301.28 E 311.10 E 321.82 E 333.12 E 345.33 E 358.62 E 372.36 E 386.30 E 400.37 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. A Gyrodata Direction. al Survey VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 5400.0 39.55 153.38 1.10 5119.5 5067.5 1021.1 5450.0 39.99 153.37 0.89 5158.0 5106.0 1053.1 5500.0 40.59 153.61 1.24 5196.1 5144.1 1085.4 5550.0 41.00 153.54 0.83 5234.0 5182.0 1118.0 5600.0 41.21 153.57 0.42 5271.6 5219.6 1150.8 5650.0 41.41 153.67 0.42 5309.2 5257.2 1183.8 5700.0 41.43 153.34 0.44 5346.7 5294.7 1216.8 5750.0 41.27 152.06 1.72 5800.0 41.13 151.06 1.34 5850.0 41.49 151.00 0.73 5900.0 41.96 150.98 0.95 5950.0 42.13 151.11 0.38 6000.0 42.49 151.07 0.72 6050.0 42.88 151110 0.77 6100.0 43.46 151.06 1.17 6150.0 43.05 150.03 1.63 6200.0 41.88 148.05 3.56 5384.2 5332.2 1249.8 5421.9 5369.9 1282.7 5459.4 5407.4 1315.7 5496.7 5444.7 1349.0 5533.9 5481.9 1382.5 5570.8 5518.8 1416.2 5607.6 5555.6 '1450.1 5644.1 5592.1 148413 5680.5 5628.5 1518.5 5717.4 5665.4 1552.3 6250.0 42.33 147.43 1.22 5754.5 5702.5 1585.8 6300.0 41.67 147.37 1.33 5791.6 5739.6 1619.2 6350.0 39.88 146.80 3.65 5829.5 5777.5 1651.7 6400.0 39.94 .146.51 0.39 5867.8 5815.8 1683.8 6450.0 39.69 146.99 0.79 5906.2 5854.2 , 1715.7. 6500.0 39.43 147.76 1.11 6550.0 39.60 147.87 0.36 5944.8 5892.8 1747'.5 5983.4 5931.4 1779.3 CLOSURE DIST. AZIMUTH feet deg. 1026.1 156.2 1058.1 156.1 1090.4 156.0 1123.0 155.9 1155.9 155.9 1188.9 155.8 1221.9 155.7 1254.9 155.7 1287.7 155.6 1320.6 155.4 1353.8 155.3 1387.2 155.2 1420.8 155.1 1454.6 155.0 1488.7 155.0 1522.9 154.9 1556.5 154.7 1589.8 154.6 1623.0 154.4 1655.3 154.3 1687.1 154.1 1718.9 154.0 . 1750.5 153.9 1782.2 153.8 HORIZONTAL COORDINATES ~et 938.68 S 967.27 S 996.20 S 1025.46 S 1054.89 S 1084.46 S 1114.06 S 1143.41S 1172.37 S 1201.25 S 1230.35 S 1259.65 S 1289.11S 1318.78 S 1348.73 S 1378.56 S 1407.51S 1435.85 S 1464.04 S 1491.45 S 1518.24 S 1545.01S 1571.83 S 1598.76 S 414.56 E 428.90 E 443.33 E 457.87 E 472.51E 487.17 E 501.93 E 517.08 E 532.76 E 548.75 E 564.89 E 581.10 E 597.37 E 613.76 E 630.30 E 647.15 E 664.51E 682.40 E 700.42 E 71'8.17 E 735.80 E 753.35 E 770.52 E 787.47 E A Gyrodata Directional Survey B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 6600.0 38.37 147.74 2.47 6022.2 5970.2 1810.7 6650.0 37.74 147.39 1.34 6061.6 6009.6 1841.5 6700.0 37.93 147.30 0.41 6101.1 6049.1 1872.1 6750.0 38.54 147.10 1.24 6140.4 6088.4 1903.0 6800.0 38.96 147.02 0.85 6179.4 6127.4 1934.2 6850.0 38.97 147.06 0.06 6218.2 6166.2 1965.6 6900.0 39.03 146.98 0.15 6257.1 6205.1 1997.0 6950.0 38.89 146.91 0.29 6296.0 6244.0 2028.4 7000.0 38.71 146.67 0.47 6334.9 6282.9 2059.7 7050.0 38.47 146.52 0.51 6374.0 6322.0 2090.8 7100.0 38.43 146.51 0.09 6413.2 6361.2 2121.8 7150.0 38.70 146.59 0.55 6452.3 6400.3 2152.9 7200.0 38.58 146.66 0.24 6491.3 6439.3 2184.0 7250.0 38.44 '146.59 0.31 6530.4 6478.4 2215.1 7300.0 38.66 146.65 0.44 6569.5 6517.5 2246.2 7350.0 38.35 146.72 0.62 6608.7 6556.7 2277.2 7400.0 38.70 146.44 0.78 6647.8 6595.8 2308.3 7450.0 38.78 146.30 0.24 6686.8 6634.8 2339.5 CLOSURE DIST. AZIMUTH feet deg. 1813.5 153.7 1844.1 153.6 1874.6 153.5 1905.4 153.4 1936.5 153.3 1967.7 153.2 1999.0 153.1 2030.3 153.0 2061.4 152.9 2092.4 152.8 2123.3' 152.7 2154.3 152.6 2185.4 152.5 2216.4 152.4 2247.4 152.4 2278.3 152.3 2309.3. 152.2 2340.5 152.1 HORIZONTAL COORDINATES ~et 1625.38 S 1651.39 S 1677.21S 1703.22 S 1729.49 S 1755.87 S 1782.27 S 1808.62 S 1834.83 S 1860.87 S 1886.80 S 1912.81S 1938.88 S 1964.88 S 1990.90 S 2016.91S 2042.90 S 2068.95 S 804.23 E 820.76 E 837.30 E 854.07 E 871.09 E 888.19 E 905.32 E 922.47 E 939.63 E 956.80 E 973.95 E 991.13 E 1008.31E 1025.44 E 1042.58 E 1059.68 E 1076.83 E 1094.16 E Final Station Closure: Distance: 2340.46 ft Az: 152.13 deg. A Gyrodata Directional Survey for B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 Run Date: 1/16/01 Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.490000 deg. N Sub.sea Correction from Vertical' Reference: Azimuth Correction: Gyro: Bearings are Relative to True North 52.OO fi. Proposed Well Direction: 150.510 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. -52.0 0.00 0.00 0.00 48.0 0.15 70.33 0.15 148.0 0.16 122.77 0.14 248.0 0.09 357.80 0.22 348.0 0.02 16.92 0.08 448.0 0.20 54.67 0.19 548.0 0.24 66.71 0.06 648.0 0.21 22.50 0.17 748.0 0.19 73.13 0.17 848.0 0.32 63.77 0.14 948.0 0.37 53.09 1048.0 0.30 65.10 1148.0 0.21 115.65 1248.0 0.27 139.21 1348.0 0.30 129.60 0.09 0.10 0.23 0.11 0.06 1448.0 0.34 120.10 0.06 1548.0 0.40 102.37 0..13 1648.0 0.43 83.78. 0.14 1748.0 0.49 80.53 0.06 1848.0 0.45 80.05 0.04 1948.0 0.39 89.21 0.09 2048.0 0.38 94.51 0.04 2148.0 0.41 103.48 0.07 2248.0 0.36 123.46 0.14 2348.0 0.41 150.51 0.19 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 0.0 0.0 0.0 0.0 100.0 0.0 0.1 70.3 200.0 0.2 0.4 88.1 300.0 0.2 0.5 88.2 400.0 0.1 0.5 77.4 500.0 0.1 600.0 0.1 700.0 0.0 800.0 -0.1 9OO.O -0.0 1000.0 -0.0 1100.0 -0.0 1200.0 0.1 1300.0 0.5 1400.0 1.0 0.7 70.5 1.0 67.2 1.4 61.7 1.7 58.8 2.1 60.5 2.7 3.3 3.7 3.9 4.1 1500.0 1.5 4.5 1600.0 2.0 5.0 1700.0 2.4 5.7 1800.0 2.6 6.5 1900.0 2.9 7.3 2000.0 3.2 8.1 2100.0 3.6 8.7 2200.0 4.0 9.4 2300.0 4.5 10.0 2400.0 5.2 10.4 60.0 59.7 62.5 68.0 74.4 79.9 83.6 84.7 84.4 83.9 84.0 84.6 85.6 87.4 90.2 HORIZONTAL COORDINATES feet 0.00 N 0.04 N 0.01 N 0.02 N 0.11 N 0.22 N 0.40 N 0.66 N 0.88 N 1.05 N 1.37 N 1.67 N 1.70 N 1.45 N 1.10 N 0.79 N 0.56 N 0.53 N 0.64 N 0.78 N 0.85 N 0.83 N 0.72 N 0.46 N 0.03 S 0.00 0.12 0.36 0.48 0.48 0.63 0.96 1.22 1.45 1.85 2.36 2.86 3.27 3.59 3.95 4.41 5.00 5.72 6.51 7.31 8.03 8.70 9.38 10.00 10.44 B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2448.0 0.12 148.00 0.29 2548.0 0.09 222.17 0.13 2648.0 0.18 223.17 0.09 2748.0 0.05 201.71 0.13 2848.0 O. 18 25.86 0.24 2948.0 0.91 198.67 1.10 3047.9 3.45 176.28 2.63 3147.5 5.94 168.26 2.57 3246.7 8.68 163.69 2.80 3345.1 ' 11.76 158.17 3.23 3442.3 15.28 158.61 3.52 3490.4 16.61 156.94 2.83 3538.2 17.75 152.49 3.47 . 3585.7 18.77 149.45 2.79 3632.9 19.74 146.82 2.60 3679.8 20.69 147.04 1.92 3726.4 21.62 148.68 2.20 3772.8 22.46 150.28 2.06 3818.8 23.34 150.82 1.81 3864.5 24.48 151.29 2.33 3909.8 25.79 151.90 2.67 3954.6 27.00 152.61 2.50 3998.9 28.26 153.45 2.64 4042.7 29.20 154.24 2.01 2500.0 5.6 10.7 92.3 2600.0 5.8 10.7 93.1 2700.0 5.8 10.5 94.0 2800.0 5.9 10.4 94.9 2900.0 5.8 10.5 94.4 3000.0 6.3 10.4 97.8 3099.9 9.5 11.4 116.9 3199.5 17.2 17.5 139.2 3298.7 29.4 29.4 150.2 3397.1 46.9 47.0 154.1 3494.3 70.0 70.3 155.5 3542.4 83.7 84.0 155.9 3590.2 98.4 98.8 155.7 3637.7 114.0 114.4 155.0 3684.9 130.5 130.8 154.2 3731.8 147.8 147.9 153.3 3778.4 165.8 165.9 152.7 3824.8 184.5 184.6 152.4 3870.8 204.0 204.1 152.2 3916.5 224.3 224.3 152.1 3961.8 245.5 245.6 152.1 4006.6 267.7 267.8 152.1 4050.9 290.9 291.0 152.2 4094.7 314.9 315.0 152.3 0.43 S 0.57 S 0.74 S 0.90 S 0.80 S 1.41 5.17 13.24 25.56 42.26 63.99 76.70 90.04 103.73 117.72 132.20 147.48 163.64 180.58 198.32 217.00 236.67 257.34 278.92 10.67 10.67 10.52 10.39 10.45 10.26 E 10.20 E 11.45 E 14.62 E 20.53 E 29.13 E 34.33 E 40.65 E 48.26 E 56.97 E 66.40 E 75.99 E 85.52 E 95.08 E 104.89 E 114.99 E 125.33 E 135.85 E 146.44 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 4086.3 29.31 155.18 0.95 4129.9 29.73 155.82 1.06 4173.1 30.72 156.85 2.23 4215.8 31.73 158.00 2.34 4258.1 32.96 158.79 2.61 4299.8 33.91 159.38 2.00 4341.1 34.46 159.51 1.12 4382.4 34.50 159.80 0.34 4423.6 34.55 159.86 0.12 4464.7 34.55 160.05 0.22 4506.0 ' 34.38 !" 160.15 0.35 4547.4 33.71 160.32 1.35 4588.9 33.91 161.67 1.56 4630.4 34.19 161.40 0.64 4671.6 34.50 161.27 0.63 4712.7 34.99 160.96 1.05 4753.3 36.43 159.73 3.21 4793.2 37.62 158.59 2.75 4832.7 38.13 158.18 1.14 4872.1 38.02 155.15 3.74 4911.5 38.04 153.76 1.72 4950.7 38.49 153.54 0.94 4989.8 38.51 153.25 0.37 5028.8 39.00 153.33 0.98 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 4138.3 339.2 339.4 152.5 4181.9 363.8 364.0 152.7 4225.1 388.8 389.2 152.9 4267.8 414.5 415.0 153.2 4310.1 441.0 441.6 153.5 4351.8 468.3 469.1 153.8 4393.1 496.0 497.0 154.2 4434.4 524.0 525.2 154.5 4475.6 551.9 553.4 154.7 4516.7 579.9 581.7 155.0 4558.0 607.8 609.9 155.2 4599.4 635.4 637.8 155.4 4640.9 662.8 665.5 155.7 4682.4 690.2 693.3 155.9 4723.6 717.9 721.4 156.1 4764.7 746.0 749.8 156.3 .4805.3 774.7 778.9 156.5 4845.2 804.5 809.0 156.6 4884.7 834.9 839.7 156.6 4924.1 865.5 870.5 156.6 4963.5 896.3 901.3 156.6 5002.7 927.2 932.2 156.5 5041.8 958.3 963.3 156.4 5080.8 989.5 994.5 156.3 HORIZONTAL COORDINATES feet 301.01S 323.42 S 346.48 S 370.41S 395.28 S 421.02 S 447.32 S 473.86 S 500.47 S 527.10 S 553.71S 580.05 S 606.35 S 632.91S 659.64 S 686.60 S 714.08 S 742.21S 770.75 S 799.06 S 826.85 S 854.60 S 882.43 S 910.39 S 156.88 E 167.09 E 177.19 E 187.14 E 196.98 E 206.82 E 216.68 E 226.52 E 236.29 E 246.01E 255.64 E 265.10 E 274.16 E 283.03 E 292.06 E 301.28 E 311.10 E 321.82 E 333.12 E 345.33 E 358.62 E 372.36 E 386.30 E 400.37 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0101GCE501 SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 5067.5 39.55 153.38 1.10 5106.0 39.99 153.37 0.89 5144.1 40.59 153.61 1.24 5182.0 41.00 153.54 0.83 5219.6 41.21 153.57 0.42 5257.2 41.41 153.67 0.42 5294.7 41.43 153.34 0.44 5332.2 41.27 152.06 1.72 5369.9 41.13 151.06 1.34 5407.4 41.49 151.00 0.73 5444.7 41.96 150.98 0.95 5481.9 42.13 151.11 0.38 5518.8 42.49 151.07 0.72 5555.6 42.88 151.10 0.77 5592.1 43.46 151.06 1.17 5628.5 43.05 150.03 1.63 5665.4 41.88 148.05 3.56 5702.5 42.33 147.43 1.22 5739.6 41.67 147.37 1.33 5777.5 39.88 146.80 3.65 5815.8 39.94 146.51 0.39 5854.2 39.69 146.99 0.79 5892.8 39.43 147.76 1.11 5931.4 39.60 147.87 0.36 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 5119.5 1021.1 1026.1 156.2 5158.0 1053.1 1058.1 156.1 5196.1 1085.4 1090.4 156.0 5234.0 1118.0 1123.0 155.9 5271.6 1150.8 1155.9 155.9 5309.2 1183.8 1188.9 155.8 5346.7 1216.8 1221.9 155.7 5384.2 1249.8 1254.9 155.7 5421.9 1282.7 1287.7 155.6 5459.4 1315.7 1320.6, 155.4 5496.7 1349.0 1353.8 155.3 5533.9 1382.5 1387.2 155.2 5570.8 1416.2 1420.8 155.1 5607.6 1450.1 1454.6 155.0 5644.1 1484.3 1488.7 155.0 5680.5 1518.5 1522.9 154.9 5717.4 1552.3 1556.5 154.7 5754.5 1585.8 1589.8 154.6 5791.6 1619.2 1623.0 154.4 5829.5 1651.7 1655.3 154.3 5867.8 1683.8 1687.1 154.1 5906.2 1715.7 1718.9 154.0 5944.8 1747.5 1750.5 153.9 5983.4 1779.3 1782.2 153.8 HORIZONTAL COORDINATES feet 938.68 S 967.27 S 996.20 S 1025.46 S 1054.89 S 1084.46 S 1114.06 S 1143.41S 1172.37 S 1201.25 S 1230.35 S 1259.65 S 1289.11S 1318.78 S 1348.73 S 1378.56 S 1407.51S 1435.85 S 1464.04 S 1491.45 S 1518.24 S 1545.01S 1571.83 S 1598.76 S 414.56 E 428.90 E 443.33 E 457.87 E 472.51E 487.17 E 501.93 E 517.08 E 532.76 E 548.75 E 564.89 E 581.10 E 597.37 E 613.76 E 630.30 E 647.15 E 664.51 E 682.40 E 700.42 E 718.17 E 735.80 E 753.35 E 770.52 E 787.47 E B.P. Exploration Well: MPC-13, 3.5"TBG Location: C PAD, MILNE POINT FIELD, ALASKA Job Number:.AK0101GCE501 SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 5970.2 38.37 147.74 2.47 6009.6 37.74 147.39 1.34 6049.1 37.93 147.30 0.41 6088.4 38.54 147.10 1.24 6127.4 38.96 147.02 0.85 6166.2 38.97 147.06 0.06 6205.1 39.03 146.98 0.15 6244.0 38.89 146.91 0.29 6282.9 38.71 146.67 0.47 6322.0 38.47 146.52 0.51 6361.2 38.43 146.51 0.09 6400.3 38.70 146.59 0.55 6439.3 38.58 146.66 0.24 6478.4 38.44 146.59 0.31 6517.5 38.66 146.65 0.44 6556.7 38.35 146.72 0.62 6595.8 38.70 146.44 0.78 6634.8 38.78 146.30 0.24 A Gyrodata Directional Survey VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. 6022.2 1810.7 1813.5 153.7 6061.6 1841.5 1844.1 153.6 6101.1 1872.1 1874.6 153.5 6140.4 1903.0 1905.4 153.4 6179.4 1934.2 1936.5 153.3 6218.2 1965.6 1967.7 153.2 6257.1 1997.0 1999.0 153.1 6296.0 2028.4 2030.3 153.0 6334.9 2059.7 2061.4 152.9 6374.0 2090.8 2092.4 152.8 6413.2 2121.8 2123.3 152.7 6452.3 2152.9 2154.3 152.6 6491.3 2184.0 2185.4 152.5 6530.4 2215.1 2216.4 152.4 6569.5 2246.2 2247.4 152.4 6608.7 2277.2 2278.3 152.3 .6647.8 2308.3 2309.3 152.2 6686.8 2339.5 2340.5 152.1 HORIZONTAL COORDINATES feet 1625.38 S 1651.39 S 1677.21S 1703.22 S 1729.49 S 1755.87 S 1782.27 S 1808.62 S 1834.83 S 1860.87 S 1886.80 S 1912.81S 1938.88 S 1964.88 S 1990.90 S 2016.91S 2042.90 S. 2068.95 S 804.23 E 820.76 E 837.30 E 854.07 E 871.09 E 888.19 E 905.32 E 922.47 E 939.63 E 956.80 E 973.95 E 991.13 E 1008.31E 1025.44 E 1042.58 E 1059.68 E 1076.83 E 1094.16 E Final Station Closure: Distance: 2340.46 ft Az: 152.13 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK0101GCE501 TOOL NUMBER: 938 MAXIMUM GYRO TEMPERATURE: 80.50 C MAXIMUM AMBIENT TEMPERATURE: MAXIMUM INCLINATION: AVERAGE AZIMUTH: 68.05 _ 43.46 152.13 WlRELINE REZERO VALUE: 0' Inrun REZERO ERROR/K: CALIBRATION USED FOR FIELD SURVEY: 3637 CALIBRATION USED FOR FINAL SURVEY: 3637 PRE JOB MASS BALANCE OFFSET CHECK: .21 POST JOB MASS BALANCE OFFSET CHECK~: .34 USED .00 CONTINUOUS CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: UPON COMPLETION OF SURVEY' OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 7400 38.75 144.0 6651.7 -2007.8 1126.5 FINAL SURVEY 7400 38.70 146.44 6647.8 -2042.9 1076.8 FUNCTION ,TEST JOB NUMBER · AK0101GCE501 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3500 15.28 15.28 15.28 15.28 15.28 AZIMUTH M.D. ft 1 2 3 4 5 3500 158.76 158.64 158.72 158.70 158.61 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0101GCE501 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 938 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 520 GYRO SECTION DATA SECTION POWER SECTION A0260 C0159 C0207 A0212 C0207 C0197 COMPUTER POWER SUPPLY DCG INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE -A0527 A0107 A0001 A0143 A0467 A0038 A0029 A0166 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.25" HOUSING W/ECCENTRIC BAR TOTAL LENGTH OF TOOL: 29' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 210 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK0101GCE501 SUNDAY, 01/14/01 10:48 LEAVE ANCHORAGE 12:15 ARRIVE DEADHORSE 19:00 CHECK TOOLS O.K. MONDAY, 01/15/01 05:30 LOAD TOOLS, TO LOCATION 06:30 JOB DELAYED, RIG CIRCULATING OUT KICK ON NEARBY WELL. 12:00 CHECK TOOLS O.K. TUESDAY, 01 / 16/01 06:00 TO LOCATION 07:30 ARRIVE CAMP · 08:45 09:15 11:30 12:30 13:00 13:45 14:00 15:15 16:15 17:00 17:30 19:15 22:00 SAFETY ORIENTATION TO LOCATION WARM UP TOOL, WAIT ON TRIPLES AND SCAFFOLDING TOOL DOWN, OPEN, CHECK O.K. PU TOOL( DOWN AGAIN), LD TOOL CO ELECTRONICS, SWIVEL CK TOOL O.K. PU TOOL/MU LUBRICATOR SURVEY to 3500' SURVEY TO 7450' SURVEY OUT TO 3500' POOH/LD TOOL/RD WIRELINE RETURN TO DEADHORSE CHECK TOOLS, PROCESS SURVEY WEDNESDAY, 01/17/01 09:00 TO MILNE WITH RESULTS 16:00 ORGANIZE WORK AREA AT CAMCO 17:30 TO ANCHORAGE . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.7:) DATE: July 12, 2000 Commissioner' tf /I~bc,) THRU: Blair Wondzell, ~~ P. I. Supervisor ,9'1(00 FROM: Jeff Jonei, t1t¡- SUBJECT: Safety Valve Tests Petroleum I sp c r Milne Point Unit B & C Pads July 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 8-22 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 8P's MPU 8 & 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. 260/0 failure rate. j J1,1O... r~~5i- 21 well houses were inspected, no failures. .".. Attachments: SVS MPU 8-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 Rep: Jeff lanes Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 ~ ,/ . (Well iJaiti".':,:~;.>< ," :.>..:~,,'~?':':, ::,::'.~~:'.;: '~,':,~'..., Pildis';.:.'.~.~>? ,:~~tMff~:t<\\': ::;;;\-8 V;~i_; '.'SSV". f~~\t~_~,*~;;~~\ ~lli~ll.i~1jE~~}):'. : : ~; ,...;..,~.;. ~ 1- . '. .~ ./~5 ¡.,~. tf". .':,,'L.I_' "...".. . l:ã.. I ,:". ,.i...;":: ....'. ,,,~'. ¡r:.~ .'''''''.Þ -t-..-.f..'f 11'\ ~.~\.,Io '" . Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE '.~Ø'lT¥\,.!<"l 1811430 140 100 95 P P OIL 1i ' . ',",-' . /,','" C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Components: 23 Failures: 6 Failure Rate: 26.00/0090 Day Wells: Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap a-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7 lOa Page 1 of 1 VI v7irqm.xls STATE OF ALASKA .,-_.~- ALAS~IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate []Pull Tubing F-IAIter Casing ~] Repair Well [~Other ESP Completion 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 954' NSL, 2169' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 1240' SNL, 899' WEL, Sec. 15, T13N, R10E, UM At effective depth 1440' SNL, 743' WEL, Sec. 15, T13N, R10E, UM At total depth 1501' SNL, 698' WEL, Sec. 15, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic I--I Service 6. Datum Elevation (DF or KBE) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-13 9. Permit Number / Approval No. 85-67 94-277 10. APl Number 50-029-21328 11. Field and Pool Kuparuk River Field/Kuparuk River 12. Present well condition summary Total depth: measured 8270' feet true vedical 7313' feet Effective depth: measured 8156' feet true vertical 7228' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) ORIGINAL Cemented MD TVD 80' 16" To surface 4743' 9 5/8" 1120 sx PF 'E'/250 sx 'G' 8202' 7" 310 sx Class 'G' 115' 115' 4779' 4623' 8236' 7288' Perforation depth: measured 7770'-7786', 7878'-7881', 7890'-7894', 7904'-7910', 8021'-8056', 7991'-8009' true vertical 6938'-7022',7019'-7031', 7029'-7031',7039'-7044',7127'-7154',7105'-7118' Tubing (size, grade, and measured depth) 3 1/2" 9.2# L-80 to 7532' Packers and SSV (type and measured depth) None RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MAR 25 1998 Alaska 0il & Gas Cons, Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord _,~~ ~/' ~ Title Engineering Supervisor Casing Pressure Tubing Pressure Form 10-404 Rev. 06/15/88 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Date ~[f~(P~ Prepared By Name/Number: Mary Youngers 564-5242 Submit In Duplicat~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MP C-13 Rig Name: N-4ES AFE# 339021 Accept Date: 8/20/96 Spud Date: - Release Date: 8/23/96 AUGUST 20, 1996 RIG ACCEPTED @ 1300 HRS. AUGUST 21, 1996 SCOPE & LOWER DERRICK & MOVE RIG TO MUP C-13 SPOT RIG RAISE & SCOPE DERRICK & BERM RIG RIG UP TO TREE & TEST LINES TO 3500 PSI PULL BPV TBG = 1240 PSI ANNULUS = 2090 PSI KILL WELL W/10.9 PPG BRINE TAKING OIL & GAS INFLUX TO TT SET TWO WAY CK & ND TREE & NU BOPS RISER & FLOW LINE TEST BOPS TO 250 LOW & 5000 PSI HIGH (TEST WAIVED BY BOBBY FOSTER W/A.O.G.C.) REVE CIRC 10.6PPG BRINE IN TBG UNTIL RETURN ARE 10.9 PPG INST LANDING JT BOLDS PULL HANGER & LD SPOT 20 BBL XANVIS PILL W/5PPB LIQUID CSG (LOSS MINIMAL) POOH W/ESP COMPLETION (HOLE BEGAN TAKING MORE FLUID HOLD FILL INCREASED TO 5.5 BBL PER 5 STDS (RATHER THAN 1.6 BBL) AUGUST 22, 1996 CIRCULATE @ 7525' BALANCE BRINE WT @ 10.7 PPG MONITOR WELL OK POOH W/ESP STAND BACK TUBING 239 JTS 3 'Y2" 9.2# L-80 BTC TUBING LD PERF JT OF TUBING & ESP - LOST 7 BANDS IN HOLE TIH W/BHA #1, MULE SHOE ON TUBING & CASING SCRAPER SLOP 42' DRILL LINE CONTINUE TIH USING 3 ~ DRILL PIPE TO PBTD @ 8144' DPM NO FILL REVERSE CIRCULATE 40 BBLS XANVIS SWEEP AROUND POOH LD DRILL PIPE TO 8059' - 50' BELOW PERF SPOT XANVIS PILL FOR LCM POOH TO 7570' - 200' ABOVE PERF CIRCULATE WHILE WAITING ON FILTERED BRINE FROM BAROID MUD PLANT PUMP 20 BBLS XANVIS SWEEP FOLLOWED BY 40 BBLS SWEEP FOLLOWED BY CLEAN FILTERED 10.7 PPG BRINE - REVERSE CIRCULATE IN CASING WASH & CLEAN BRINE - 35 NTU RETURNS. AUGUST 23, 1996 FINISH REVERSE CIRCULATING TO CLEAN 10.7 PPG BRINE WATER MONITOR WELL OK POOH FOR ESP COMPLETION PULL 20 STANDS CIRCULATE BU BRINE CUT 10.7 TO 10.4 PPG MONITOR WELL SLIGHT FLOW CIRCULATE & INCREASE BRINE WT 10.7 TO 10.8 PPG MONITOR WELL OK POOH FOR ESP COMPLETION FLUSH FLOW LINE, MAKE UP & SERVICE ESP TIH W/ESP COMPLETION - RUN 239 JTS 3 1&" 9.2# L-80 BU'I-I- TUBING & ONE GLM MU TUBING HANGER & MAKE SPLICE @ HANGER- RAN 479 BAND ON ESP CABLE LAND TUBING SET TWC ND BOP STACK NU 11" X 3 1/8" ADAPTER SPOOL, NU Page FMC 3 1/8" 5000# TREE TEST TREE & HANGER PACK OFF TO 5000 PSI OK PULL TWC TAKE ON SOURCE WATER IN PITS & PREPARE TO DISPLACE DOWN ANNULUS AND RECOVER BRINE REVERSE CIRCULATE & DISPLACE WELL TO 8.4 PPG SOURCE WATER - CONTINUE REVERSING 53 BBL OF DIESEL DOWN ANNULUS FOR FREEZE PROTECTION - BULL HEAD 17 BBLS DIESEL DOWN TUBING FOR FREEZE PROTECTION - MONITOR WELL - SITP 1200 PSI, SICP 2170 PSI 225 BBLS 10.8 PPG BRINE RETURNED TO BAROID FOR CREDIT SET BPV SECURE WELL CLEAN PITS - RIG RELEASED @ 1700 HRS. RECEIVED Anchorage Page 2 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU C-13 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/18/95 06:00 SPUD: RELEASE: 07/24/95 03:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 07/19/95 ( 1) TD: 8236 PB: 8156 07/20/95 ( 2) TD: 8235 PB: 8156 07/21/95 ( 3) TD: 8235 PB: 8156 07/22/95 ( 4) TD: 8235 PB: 8156 07/23/95 (5) TD: 8235 PB: 8156 KILL WELL MW: 0.0 RD MOVE RIG F/ C-09 - C-13. ACCEPT RIG @ 1800 HRS ON 07/18/95. RU LINES TO TREE AND TIGER TANK. TEST LINES. PULL BPV. LOAD PITS W/ SOURCE WATER AND HEAT TO 150 DEG. BULL HEAD 80 BBLS SOURCE WATER DOWN TBG. MONITOR WELL. L/D HANGER MW: 0.0 CIRC 150 DEG SOURCE WATER THROUGH GLM @ 7391'. SHUT IN AND OBSERVE WELL. BLEED GASS OFF ANNULUS. RESUME CIRC. SWITCH RETURNS TO PITS. MIX AND SPOT 40 BBL XANVIS PILL DUE TO HIGH FLUID LOSS. OBSERVE WELL. SET BPV. ND TREE, NU BOPE. TEST BOPE. DRAIN BOP. RU LANDING JT AND LUBRICATOR. REPAIR AIR PUMP ON ACCUMULATOR. TEST ACCUMULATOR. PULL 2 WAY CHECK. INSTALL LANDING JT. BOLDS. SHEAR BAKER PKR. FLUID LOSS EXCESSIVE. MIX AND SPOT 40 BBL XANVIS PILL TO PERF. CIRC. LD HANGER. POH W/ 3 1/2" PRODUCTION STRING. WASH OVER PKR MW: 0.0 SERVICE RIG. POH W/ 3 1/2" TBG AND ESP. LEFT 10 PREFORMED BANDS IN HOLE. LD ESP ASSY. CLEAR FLOOR. RU TO TUN 3 1/2" DP. INSTALL WEAR BUSHING. STRAP AND RIH W/ BHA ON 3 1/2" DP T077632'. PUMP 40 BBL XANVIS PILL AND MILL ON PKR F/ 7632 - 632.5' RIH W/ MILL AND SCRAPER MW: 0.0 CUT OVER PKR F. 7632 - 7636'. CBU. PUSH PKR TO 8056' DRESS TOP OF FISH. POH. LD SHOE. CLEAN JB'S. MU AND RIH W/ OVERSHOT. SLIP AND CUT DRLG LINE. TAG FISH. WORK FREE. POH W/ PKRAND SCREEN. FULL RECOVERY. HAD SMALL HOLE IN BOTTOM OF SCREEN AND 1 BAND INSIDE OF SCREEN. RIH W/ MILL AND JUNK BASKET ASSY. RIH W/ ESP MW: 0.0 FINISH RIH W/ BHA. TAG FILL @ 8086'_ CLEAN FRAC SAND TO 8139'. CIRC OUT FRAC SAND. PUMPED 3-40 BBL XANVIS SWEEPS. CIRC UNTIL CLEAN. REVERSE CIRC XANVIS SWEEP. POH LD DP TO 5000'. CBU. DISPLACE WELL W/ CLEAN SOURCE WATER. POH LD DP AND BHA. MU PORTED SUB AND FLUSH OUT BOPS. RU TO TUN ESP. MU AND SERVICE ESP. WELL : MPU C-13 OPERATION: RIG : NABORS 4ES PAGE: 2 07/24/95 (6) TD: 8235 PB: 8156 RELEASE RIG MW: 0.0 SERVICE RIG. RIH W/ 3 1/2" TBG AND ESP ASSEMBLY. MU HANGER. MAKE PIG TAIL SPLICE. LAND TBG. RILDS. LD LJ. SET TWC. CLEAR FLOOR. ND BOPE. NU TREE AND TEST. PULL TWC. FREEZE PROTECT ANNULUS W/ 53 BBLS DIESEL AND TBG W/ 18 BBLS DIESEL. SET BPV. SECURE TREE AND CELLAR AND CLEAN PITS. RELEASE RIG @ 0300 HRS ON 07/24/95. SIGNATURE: (drilling superintendent) DATE: RECEIVED 1998 AJa~ka 0]] & Gas Oo~s. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 22 November 1994 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: W LL D SCRIPTIO ~PC-~ ~~ ECC No. Run # 1 6297.00 Please sign and return ~~s Wireline/~ervices ~u~e Anchorage, AK 99518~'- Attn Rodney D. Paulson O~ FAX to (907) 563-7803 Received by ~~~j/~l_~_~ Date: .,,,_. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate x Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 954' NSL, 2169' WEL, SEC. 10, T13N, RIOE At top of productive interval 1240' SNL, 899' WEL, SEC. 15, T13N, RIOE At effective depth At total depth 1501' SNL, 698' WEL, SEC. 15, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 4743' Intermediate Production 8202' Liner 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 52' 7. Unit or Property name Milne Point Unit 8. Well number MPC-13 9. Permit number/approval number 85-67/94-277 10. APl number 50-029-21328 11. Field/Pool Kuparuk River Field/Kuparuk River 8270 7313 8156 7228 Size feet feet feet feet Plugs (measured) Junk (measured) ORIGINAL Cemented Measured depth True vertical depth 16" 9-5/8" To Surface 115' 115' 112o sx PF "E"/25O sx "G" 4 779' 4623' 7" 310 sx Class "G" 8236' 7288' Perforation depth' measured 7878'-7881', 7890'-7894', 7029'-7031', 7904'-7910', 8021'-8056', 7991'-8009', 7770'-7786' (isolated with dummy valves 11/92) true vertical 7019'-7022', 7029'-7031', 7039'-7044', 7127'-7154', 7105'-7118' 6938'-6950' (isolated with dummy valves 11/92) Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing to 7586' MD w/ESP @ bottom; 3-1/2", L-80 tubing tail to 7670' MD feet Packers and SSSV (type and measured depth) HES TRSV @ 651' MD; Baker 'FB-1' PaI~E~. ~ ~JbE D 13. Stimulation or cement squeeze summary Please see attached Intervals treated (measured) Treatment description including volumes used and final pressure NOV 1 7 1994- 0il & Gas Cons. Commission Anch0r~.,~ 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil x Gas Suspended tha~e,f~reg.,oin~is__~,,,,,,, true an.~r correct to the best of my knowledge. 17. I hereby certify Signed ,,~ ~--~ ~("- Title Service --orm 10-404 Rev 06/15/88 Drilling En~tineer Supervisor Date SUBMIT IN DUPLIdA~- MP C-13 10/27/94 8,236' SCOPE DOWN DERRICK AND PREP RIG TO MOVE. LD DERRICK. MOVE F. C-14 TO C-13. RAISE AND SCOPE UP DERRICK. RU LUBRICATOR. PULL BPV. RD LUB. TAKE ON MP SOURCE WATER IN PITS. BUILD BERM AND SET KILL TANK. RU HARD LINE TO TANK AND TO TREE. HEAT WATER W/ HOT OIL TRUCK. PUMP OPEN SSSV. BLEEDING GAS OFF ANNULUS. 10/28/94 8,236' BLEED GAS OFF ANNULUS. CIRC HEATED SOURCE WATER DOWN TUBING, TAKING RETURNS through CHOKE TO KILL TANK. RETURNS TO PITS AFTER FLUID CLEANED UP. CIRC, AND HEAT FLUID W/HOT OIL TRUCK. CLOSE CHOKE. PUMP DOWN TUBING AND SHEAR PUMP OPEN PLUG @ 7652'. BULL HEAD 20 BBL'S DOWN TUBING. MONITOR. WELL DEAD. CLOSE SSSV. SET BPV. ND TREE AND ADAPTER FLANGE. PUMP OPEN AND PLUG SSSV. NU BOP. PULL BPV AND SET TWC. TEST BOPE. RAMS MANIFOLD AND VALVES. RU LANDING JT. PULL TWC. MAKE UP LANDING JT IN HANGER. WELL STARTED FLOWING WHILE MAKING UP LANDING JT. SHUT IN TUBING. START REVERSE CIRC. 10/29/94 8,236' REVERSE CIRC. MONITOR WELL. TBG AND ANNULUS FLOWING. SHUT IN. ClRC AND INCREASE WT. MONITOR WELL. FLOWS, BUT NO PRESSURE. INCREASE WT TO 8.5. STARTED LOSING + 35 BPH WHILE PUMPING. WELL FLOWS WHEN NOT PUMPING. SPOT 40 BBL XANVIS PILL DOWN TO OPEN GLM @ 7561'. MONITOR WELL. STILL FLOWS. BULLHEAD 25 BBL'S OF PILL BELOW PACKER. MONITOR WELL. NO FLOW. FLUID DROPPING VERY SLOWLY. BOLDS. PULL TBG HANGER TO FLOOR. MONITOR WELL. LD HANGER. POH STANDING BACK 3.5" TBG. DRIFT AND SLM. RECOVERED 120 SS BANDS. CIRC TBG VOLUME THROUGH SSSV. LD SSSV. CONTINUE POH. LD GLM'S. 10/30/94 8,236' SERVICE RIG. FINISH POH W/3.5" TBG, GLM'S, & SEAL ASSEMBLY. RU E-DP. CBU THROUGH GAS BUSTER. TAG PACKER ~ 7583' DPM. LATCH SAME. STRAIGHT PULL IN INCREMENTS TO 120K~ OVER STRING ~. COCK JARS. HIT ONE LICK ~ 90K~ OVER AND PULLED FREE. CBU THROUGH GAS BUSTER. ClRC OUT GAS F/UNDER PACKER. CHECK FLOW, Ok. SPOT 20 BBL XANVIS PILL ON BOSOM. POH W/3.5" DP. LD FISH. RECEIVED NOV 1 7 1994 0il & Gas CODS. Commission Anchom. ,9 10/31/94 8,236' SERVICE RIG. FINISH LD FISH AND FTA #1. STRAP AND PU FTA #2. START RIH ON 3.5" DP. CUT 84' AND SLIP 42' OF DRLG LINE. RIH TO 7888'. CBU THROUGH GAS BUSTER. MONITOR WELL- FLOWS. CIRC ADDITIONAL BU. MONITOR WELL- FLOWS. SHUT IN - NO PRESSURE. CHECK FO FLOW, OK. MILL PKR F/7923 - 7925'. SPINNING ON LAST 6". UNABLE TO MAKE ANY HOLE LAST 6 HR'S. RELEASE PRT SPEAR. CHECK FOR FLOW, OK. START POH. 11/01/94 8,236' SERVICE RIG. FINISH POH W/FTA #2. MILL 70% WORN. OUTER ROW OF CUTTERS GONE. CLEAN BOOT BASKETS. WO TRISTATE TOOLS. MU FTA #3. PU 6 ADDITIONAL 4.75" DC. RIH TO 7890'. CBU THROUGH GAS BUSTER. MONITOR WELL, OK. TAG PACKER @ 7924- 7925'. PACKER LOOSE. TAG UP @ 7942'. CBU THROUGH GAS BUSTER. MONITOR WELL, WELL FLOWS. ClRC ADDITIONAL BU, WELL STILL FLOWS. SHUT IN. NO RECORDABLE PRESSURE. ClRC AND WT UP FROM 8.7# TO 8.9#. MONITOR WELL, OK. POH W/FTA #3. 11/02/94 8,236' SERVICE RIG. FINISH POH. LD 6 4.75" DC, PKR AND TAILPIPE AND FISHING TOOLS. PU BHA #4. RIH. TAG FILL @ 8064'. PU TO 8032'. CBU. SMALL AMOUNT OF GAS ON BOTTOM. WASH FILL F/8064 - 8136' RKB. CIRC AND COND. ATTEMPT TO REVERSE CIRC. LOSING 1 BPM WHILE PUMPING 3 BPM @ 300 PSI. CIRC 50 BBL XANVIS SWEEP DOWN TBG AND AROUND. MONITOR WELL. LIGHT FLOSS. CIRC AND INCREASE WT F/ 8.9#- 9#. MONITOR WELL, OK. POH. LD BHA. RU SHOOTING FLANGE AND LUBRICATOR RISER. RU ATLAS WIRELINE. TEST LUBRICATOR, OK. RIH W/ 3 3/8" PERF GUNS W/6 SPF, 22GM RDX BIG HOLE CHARGES. TIE IN TO DRESSER ATLAS GR/CCL DATED 5/7/85. TAG BOTTOM @ 8151' 11/03/94 8,236' POH W/GUN #3, FLUID LOSS 5 BBL. RUN #4 7770 - 7788'. RIG DOWN ATLAS. NIPPLE DOWN PERF FLG NIPPLE UP FLOW NIPPLE. RIH W/5 STDS, TBG AND 3 1/2" DP TO 8136'. CIRC AND COND HOLE. RIG UP BJ. TEST LINES. POH 4 STDS TO 7751'. WAIT ON SD TO SETTLE. RIH TAG SAND @ 7940', POH TO 7877'. CIRC WHILE MIXING BJ. MIX SAND SLURRY. PUMP SAND PLUG @ 7877'. PUT IN PLACE W/RIG PUMP. POH TO 7500'. WAIT ON SAND TO SETTLE. RIH AND TAG FILL @ 7820', POH. PU BAKER C-1 FULL BORE TENSION PKR AND RIH AND SET AT 500', TEST TO 1000 PSI ON 3 1/2"X 7" ANNULUS. WAIT ON WEATHER TO BEGIN FRAC JOB. RECEIVED NOV 1 ? i99~ Oil & Gas Cons. Commission Anchorr_ ,~ 11/04/94 8,236' WAIT ON WEATHER TO COMMENCE FRAC. RELEASE PKR @ 500' AND MONITOR WELL. POH W/PKR, LAY DOWN SAME. TEST ALL BOP EQUIPMENT. RIH TO 500' AND SET BAKER C-1 FULL BORE TENSION PKR. WAIT ON WEATHER TO COMMENCE FRAC. 11/05/94 8,236' WAIT ON WEATHER AND GETTING FRAC EQUIPMENT TO LOCATION. RIG UP BJ FRAC EQUIPMENT. TEST BJ LINES. PERFORM FRAC TREATMENT ON KUPARUK "C" SANDS IN STEPS INJECTIVITY TEST. DESIGN RATE 20 BPM. DATA FRAC PUMP 100 BBL'S TO PERFS. JOB WENT GOOD. MONITOR FRAC. START BLEED OFF. 11/06/94 8,236' CONTINUE TO BLEED FRAC OFF. RELEASE PKR AND CIRC. INFLUX FROM UNDERNEATH PKR AT 500'. POH AND LAY DOWN BAKER PKR. M/U MULE SHOE AND RIH TO 6466' TAG CARBOLITE. LAY DOWN 2 JTS DP. CIRC. REVERSE CIRC WELL VOLUME GETTING LOTS OF CARBOLITE IN RETURNS. CIRC. RIH W/14 STANDS AND SINGLE. TAG CARBOLITE @ 7512'. REVERSE CARBOLITE OUT OF 7" CSG. REVERSE CIRC. XANVIS SWEEPS TO CLEAN CARBOLITE AND FILTER BRINE. MONITOR WELL BORE. FLOWING SLIGHTLY. 11/07/94 8,236' MONITOR WELL. CIRC BRINE THROUGH CHOKE MANIFOLD. MONITOR WELL FLOW CONTINUES. MONITOR WELL, SLIGHT FLOW CONTINUOUS. RAISE BRINE WT TO 9.6 IN SURFACE VOLUME. CIRC. MONITOR WELL. 10 STD SHORT TRIP. HOLE TOOK CALCULATED FILL PLUS 8 BBL OVER. CIRC BOTTOMS UP. NO INFLUX. POH. NIPPLE DOWN FLOW NIPPLE AND NIPPLE UP SHOOTING FLG. RIG CAMCO WIRE LINE AND TEST LUBRICATOR. RIH WITH 6" O.D. GR/JB TO 7725'. POH NO RECOVERY NO PROBLEMS. RIG DOWN CAMCO EQUIPMENT. NIPPLE DOWN SHOOTING FLANGE AND NIPPLE UP FLOW NIPPLE. M/U BAKER FB-1, PERM PKR W/ SCREEN 20 GAUGE AND PXN PLUG INSTALLED. BREAK ClRC @ 7640' AND DROP 1 7/16" SETTING BALL. SET PKR. PULL 18000# OVER NORMAL PU WT TO SET AND RELEASE FROM PKR AND SCREEN. REVERSING OFF TOP OF PKR WITH XANVIS SWEEP. 11/08/94 8,236' REVERSE CIRC. XANVIS SWEEP ON TOP OF SCREEN (HOLE CLEAN). POH LAYING DOWN 3 1/2" DP. H2S DRILL AND SAFETY MEETING. CONT LAYING DOWN DP. RIG UP AND HOLD MEETING AND RIH WITH ESP COMPLETION. P~ E ¢ E iV E D NOV 1 7 '~994 Oil & Gas Cons. Commission Anchorc ~s 11/09/94 8,236' SPLICE ESP CABLE TO PKR BO'I-I-OM. PU SSSV SPLICE ESP CABLE TO PKR TOP. RU AND INSTALL CONTROL LINE TO SSSV AND TEST. CONT RIH WITH ESP COMPLETION. PU HGR AND LANDING JT. INSTALL PENETRATOR AND SPACE OUT ESP CABLE CUT AND SPLICE SAME. LAND HGR, RILDS AND LAY DOWN LANDING JT. INSTALL BPV. NIPPLE DOWN BOPS AND NIPPLE UP FMC TREE. WITH LUB PULL BPV AND INSTALL 2 WAY CHECK. TEST TREE. TEST SSSV, PULL 2 WAY CHECK. BRK ClRC DOWN TBG. CLOSE SSSV PUMP DOWN 3 1/2"X 7" ANNULUS TAKING RETURNS THROUGH TBG. SSSV WOULD NOT CLOSE. PRESSURE UP ON LINE AND BLEED OFF SEVERAL TIME TO ATTEMPT TO GET SSSV TO FUNCTION PROPERLY. NO RESULTS. WAIT UP 35 BBL BRINE. RIG UP CAMCO AND RIH W/WIRE BRUSH AND NO GO TO SSSV AND POH AND RIG DOWN SAME. ATTEMPT TO CLOSE SSSV. REVERSE CIRC. SSSV NOT WORKING. 11/10/94 8,236' NIPPLE UP BOPS. PULL BPV SET 2 WAY CHECK. TEST BOPS. PULL 2 WAY CHECK. RIH W/LANDING JT. BOLDS. PULL HGR TO FLOOR. LOCATED SMASHED CONTROL LINE @ 1ST COLLAR BELOW HANGER. REPAIR SAME AND TEST. RE-LAND TBG. RILDS LAY DOWN LANDING JT. SET BPV, ND BOPS, NU TREE AND TEST. PULL 2 WAY CHECK. FREEZE PROTECT WELL 60 BBL MEOH 60/40 3 1/2" X 7" ANNULUS AND 18 BBL'S DIESEL IN TBG. RIG UP CAMCO EQUIP. TEST LUBRICATOR. RIH WITH 2 7/8" KICK OVER TOOL THROUGH PKR TO VERIFY NO PROBLEMS WITH SMALLER 1 .D. POH AND LAY DOWN TOOL. RIH TO BAKER CT-ESP PKR PROFILE AND LOCATE NO GO SET PLUG AND SET PKR. POH AND RIG DOWN CAMCO. MU LUBRICATOR AND SET BPV. FILL TREE WITH DIESEL AND SECURE SAME. RELEASE RIG @ 1900 HR'S ON 11/09/94. RECEIVED ~,OV ] ? 199a,: A~g~ 0ii ° Gas Cons. 6ommissio~ , Anchor~ ,~'- BP EXPLORATION (ALASKA) INC. PRUDHOE BAY PRODUCTION ENGINEERING DEPARTMENT TO' Rossberg FROM' C. Michel DATE' 11/4/94 RE: MPC-13 SERVICE CO'S.: / IBE / Hendrix / Warnken DATA FRAC AND FRAC (Kuparuk C) BJ, Peak, Rig 4ES JOB SUMMARY INJECTIVITY TEST Design Rate, Bbls Max Rate, Final ISIP2, NWB Treat grad, BPM Pumped bpm STP2r psi PSI frictionr psi psi/ft 20 41.3 2955 2460 495 0.80 DATA FRAC Bbls Bbls XL Time XL gel Final STP, ISIP, psi NWB Treat Pumped gel to on perfs psi friction, grad, Perfs psi psi/ft 1 00 1 00 5.1 3220 2610 300 0.82 Sand Lead prop Tail prop Design total pumped, behind behind behind Liner Job was M# piper M# piper M# piper M# Sandy M# Tailoffr M# Flush 130M# 123 M# 53 M# 7.1 M# N/A 16/20 Ft of Estimated Final ISIP, psi ISIP Incr Actual TSO, TSO, sand In sand top STP, over sand:pad design, Nolte Pipe psi datafrac ratio min Plot 323 7447 3270 3085 475 78 4.53 10.0 Operational problems First attempt- wind and blowing snow shut us down. Rig measured 72 mph at a point 20 ft above the ground; sorry, but this job could not be done safely, cleanly, and without considerable quality risks. R E C E IV E D 1:16 PM SENT VIA MICROSOFT MAIL ~OV ] 7 Oil & ~as Cons. Commission Anehnrr PUM SUMMARY RATE STAGE CUM COMMENTS BPM BBL BBL Second attempt- 36 hours later- some problems with blender; paddle mixer was on an angle due to snow under one side: this caused us to run out of FLA early on datafrac. Frac-had some pump truck problems, had to switch pumps; one densimeter crapped out, had to run around and switch cords. Comments A smooth job. Really packed it in, although we could have pumped anothr 50 M# easily. Seems like, if it goes it goes. If it doesn't then screen-out! Wellbore fluid ahead of frac pad obviously created extra area, which was why we put so much away. Nolte was late, T$O started at 11 min rather than design of 4.5. Slowed rate and slowed rate during flush to induce screenoutOn shutdown, WHP just hung there at 3035 psi- a good sign that we really packed it in. Should be a good well. RECEIVED ~:~s~ Oi[& 6as Oon~. Commission A~chor~., ' PUMPING SUMMARY RATE STAGE CUM COMMENTS BPM BBL BBL DATE/TIME OPERATIONS SUMMARY 11/2/94 Aborted attempt to RU. SD due to high winds (72 mph) 11/4/94 DATA FRAC 1000 MIRU frae, vac, pump. AMBIENT={-5), WIND=20 MPH. SIWHP= 0 FRAC 2000 PUMP FRAC AS PER REVISED TSO SECURE WELL. RDMO frac, vac, pump. TIME RATE IANNPI WHP ISTAGE CUM BP. i.s G I.S,el BBL BBL 11/4/94 INJECTIVITY TEST COMMENTS DISPLACEMENT = 281 BBLS 17:08 0/ 0 0 0 Start injectivity test w/10# gel 39.7 1000 5086 40/0 Stage XLgel 40 4317 60/0 Stage Flush 41.3 3900 100 39OO 150 41.2 3923 221 40# XL gel at pens 41.0 3953 25O 3884 281 20# gel at perfs 3825 3O0 3746 350 3696 401 Slow to 20 bpm 17:23 2955 441 544 Sd. Monitor WHP. ISlP = 2610 psi. Batch up to 40# gel. End monitor WHP. DATA FRAC R [ C E IV E B' 17:55 0~40 0 Est rate w/40# gel 3943 15 Start FLA 2 0 Start XL b3~$~a_ _Oil .& Cas Cons. C~rnmissi~ 40 3765 30/0 574 Stg 40# XL gel pad 40/30/6 3608 100 Slow rate to 30 BPM. Lost FLA or ran out. Redesign DF to 100 bbls. Did not restage stage counter- confused enough. Slow rate to 6 bpm to regroup. Reduce rate to 7 bpm (80bbls from pens) 18:22 845 Shut down for 2 minutes 18:24 0/20 2740 845 Increase rate to 20 bpm (10 bbls before pens). PU NG SUMMARY RATE STAGE CUM COMMENTS BPM BBL BBL !18:26 20 855 Pad atpeds. 3282 860 3245 880 3240 900 3234 920 3229 940 18:31 3220 955 SD pumps. Analyze DF. Movefluid. FRAC 20:05 0/20 0 Establish rate with 40# 2918 5 Start FLA 10 Start XL 20:06 20 2882 20/0 Stage pad 2846 38/0 58 Stage I ppg 16/20 2831 25/0 83 Stage 2 ppg 3/0 86 3 ppg. 2829 5/0 91 4 ppg 2813 7/0 98 5 ppg 2803 9/0 107 6 ppg 2765 11/0 118 7 ppg 2709 13/0 131 8 ppg 2664 14/0 145 9 ppg 2585 15/0 160 10 ppg 2357 50 20:18 2116 100 2042 141 301 Pad at Deds 1981 1 79 339 I ppg on peds 1930 204 364 2 ppg on peds 207 367 3 ppg on peds 212 372 4 ppg on peds. 1910 219 379 5 ppg on perfs 1905 228 388 6 ppg on peals 20:24 1905 391 Design TSO, 1898 239 399 7 ppg on perfs 1865 252 412 8 ppg on perfs 1903 266 426 9 ppg on pens 1849 281 441 10 ppg at perfs 1844 300 1819 320 1840 330 1830 340 PU M'J3'iNG SUMMARY RATE STAGE CUM COMMENTS BPM BBL BBL 1800 350 1820 360 1840 370 1850 380 386 Stage Flush 1974 20 2131 40 2354 6O 2580 80 2745 100 20:38 2910 120 3O37 140 319O 1 6O 20/15 3312 180 Slow rate to 15 bpm 20:42 15/12 3115 200 Slow rate to 12 BPM 3066 220 ~20:45 12/8 3135 230 Goto8 BPM 3115 240 20:47 8/5 3160 250 Go to 5 BPM 3141 255 3191 260 20:51 3270 271 825 Sd pumps. ISIP=3085 .Monitor WHP. Si well. FLUIDS PUMPED DOWNHOLE INJ TEST: and DATA FRAC: 1055 Bbls FRAC: 825 Bbls 1880 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME IINONE I 20 Diesel Recovered (not downhole) PETREDAT WINDOW GEL QUALITY CONTROL CHECK SEA H20 SEA H20 40# GEL 40# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.76 85 7.84 36 14.1 3:00 10.1 FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM RECEIVED NOV 1 Oil & 0~s Con~. Commission Anch0r,~ r" RATE BPM STAGE BBL CUM BBL with 15 PPT silica flour and 40 PPG adomite regain in pad. SUMMARY COMMENTS No ESL. MEMORANDUI " Chairma~ry~ State of ,laska Alaska Oil and Gas C~nservation Commission. DATE: November 3, 1994 THRU: FROM: Blair Wondzell, P. I. Supervisor Jerry Herring, h{~ Petroleum Inspector FILE NO: aw9kkebd.doc SUBJECT: BOPE Test - Nabors 4ES BPX Milne Point Unit MPC-13 PTD # 94-277 Thursday, November 3, 1994: I traveled to BPX's Milne Point Unit to witness a B.O.P.E. test on Nabors rig 4ES completing a workover on well MPC-13. The B.O.P.E. Test Report is attached. The test lasted for (3) hours and there was (1) failure. The choke line HCR valve leaked and was repaired, Overall, I found the rig to be in good shape, Danny Hebert has done an exceptional job on this rig. Summary: I witnessed a B.O.P.E. test on Nabors 4ES completing a workover on MPC-13, MPU. The test lasted for (3) hours and them was (1) failure. Attachment: aw9kkebd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: NABORS Rig No. Operator: BPX Well Name: MPC-13 Casing Size: 7" Set @ 8,236' Test: Initial Weekly X Other 4ES PTD # Rep.: Rig Rep.: Location: Sec. DATE: 11/3/94 94-277 Rig Ph.# 659-2234 LARRY MA YERS DANNY HEBERT fO T. f 3N R. fOE Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/~! Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer f Pipe Rams 1 Lower Pipe Rams N/A Blind Rams f Choke Ln. Valves f HCR Valves 2 Kill Line Valves f Check Valve Test Pressure 250 / 3, 000 250/5000 Not In Use 250/5000 250 / 5000 250/5000 250 / 5000 N/A Not In Use P/F P P N/A P P F/P P N/A Alarm OK OK OK OK OK MUD SYSTEM: Visual Trip Tank OK Pit Level Indicators OK Flow Indicator OK Meth Gas Detector OK H2S Gas Detector OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F N/A Not In Use N/A N/A Not in Use N/A I 250/5000 P I 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 10 250/5000 26 250 / 5000 Func§oned Functioned P/F P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 2050 Ave 3, O00 P 1,700 P minu~s 29 sec. minu~s 43 sec. OK Remote: OK Psig. Number of Failures: f ,Test Time: 3.0 Hours. Number of valves tested 16 Repair or Replacement of Failed · Equipment will be made within f days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. i. Supervisor at 279-1433 REMARKS: Choke line HCR valve failed. Kelly not in use. Rig is in good condition. Choke line HCR valve was repaired and retested 11/4/94. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~tnessed By: ~ ~ FI-021L (Rev. 7/19) AW9KKEBD.XLS 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 extension __ Stimulate x Change approved program __ Pull tubing x Variance__ Perforate __ Olher__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 954' NSL, 2169' WEL, SEC. 10, T13N, RIOE At top of productive interval 1240' SNL, 899' WEL, SEC. 15, T13N, RIOE At effective depth At total depth 1501' SNL, 698' WEL, SEC. 15, T13N, RIOE 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE -- 7. Unit or Property name Mi/ne Point Unit 8. Well number MPC-13 9. Permit number 85-67 10. APl number 50- 029-21328 11. Field/Pool Kuparuk River Field/Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8270 feet Plugs (measured) 7313 feet 8156 feet Junk (measured) 7228 feet ORIGINAL Casing Length Structural Conductor 80' Surface 4743' Intermediate Production 8202' Liner Perforation depth: Size Cemented Measured depth True vertical depth 16" To Surface 115' 115' 9-5/8" 112o sx PF "E"/250 sx "G" 4 779' 4623' 7" 310 SX Class "G" 8236' 7288' measured 7878'-7881', 7890'-7894', 7029'-7031', 7904'-7910', 8021'-8056', 7991'-8009', 7770'-7786' (isolated with dummy valves11,92) R E C E IV E [ true vertical 7019'-7022',7029'-7031', 7039'-7044',7127'-7154', 7105'-7118' 6938°-6950, (isolated with dummy valves 11/92) Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 7966' MD 3 0 1994 Gas Cons. C0m Packers and SSSV (type and measured depth) T. R. SCSSV @ 1897'; Ret. Packer@ 7598'; Perm. Pkr. @ 7943' Anch0r&~e 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 10/2/94 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify,~;t the foregoing/is true and correct to the best of 15. Status of well classification as: Oil x Gas Suspended Service my knowledge. Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. ? r~, 2 7 7 Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test__ Subsequent form required 10- Original Signed By Approved by order of the Commission ')gvid W. Johnston Commissioner Date ~'(,""~ ~/,~ y I SUBMIT IN 'IZRIPLI(k-,ATE ~issi0n Form 10-403 Rev 06/15/88 Approved Copy Returned MP C-13 RW~.,~AND FRAC SUNDRY INFORIV~,.~.:'ION Objective: The objectives of this workover are to fracture stimulate the Kuparuk "C" sand and convert well C-13 from gas lift to ESP producer. The scope for C-13 is as follows: Scope: 1. Pre- rig: Obtain a static pressure survey and bullhead to kill the well. Install BPV. Remove wellhouse and flowline. 2. MIRU Nabors 4ES workover rig. Circulate as necessary to ensure the well is killed. Pull existing 3.5" L-80 BTC tubing and straddle packers completion. 3. Perform wireline conveyed perforations at Kuparuk "A", "B", and "C" sands. 4. Perform sandback to isolate Kuparuk "A" and "B" zones and fracture stimulate Kuparuk "C" sand interval. Cleanout wellbore to PBTD. 5. Run wireline set 7" packer with 20', 20 gage screen in the tailpipe and set at 50' above the top perfs. 6. Rerun 3.5" tubing with a new ESP, GLMs, SSSV and tubing packer. 7. Freeze protect the tubing and annulus down to 2000'TVD before setting the tubing packer. RDMO Nabors 4ES. 8. Put well on production. Timing- Nabors 4ES will be making a well to well move from C-09 to ..C.~13 on approximately 10/3/94. Th~'work0~"~;'~-d~ld'T'ake ~pp'r-0xi~[~iy-.~g'd-Ey~,*-ri~i~.- , ~,~aaka ~l & Cas Gon~! Gommi~sion Anchor~.¢ DH, September 29, 1994, 11:32 AM NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB - SL = 52' KDB - GL = 55' 2. MAX. ANGLE = 42.75' @ 6000' 3. K.O.P. = 3000' 4. SLANT HOLE: YES 5. MIN. ANGLE = NA 6. TREE TYPE: FMC 3 1/8" APl 5000# WITH 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE 7966' (2.75" ID) 8. COMPLETION FLUID: 10.2 PPG NoCI-NoBr 9. FRACTURE STIMULATION: 8-28-85 LOWER KUP (2) 7.3,500 LBS. 16-20 ISP PERFORATIONS: 12 SPF, 120' PHASING, 5" GUNS (ALL DEPTHS FROM DIL LOG 5-6-85) MIDDLE KUP 7770'-7786' MD [ ISOLATED ~TH 6938'-6950' TVD~ DUMMY VALVES 11-27-92 L-8 7878'-7881' MD 7019'-7022' TVD 7890'-7894' MD 7029'-7031' ]'VD l-9 7904'-7910' MD 7039'-704-4' TVD LK-2 8021'-8056' MD 7127'-7154' TVD 4 SPF, 180' PHASING, 2 5/8' GUNS (ALL DEPTHS FROM DIL LOG 5-6-85) LK-i 799i' 8009' I,'.D 7105'-7i18' TVD CONOCO INC. (CO¢'~OCO) ANCHORAGE DIVISION · WELL No. COMPLETION MILNE POINT C- 13 ,.,.~ SKETCH UNIT (P) APl No.: 50-029-21328 PERMIT No.: 85-67 COMPLETED: 5/9/85 LAST WORKOYER: N/A FMC TUBING HANGER W/ 3 1/2" 'H' BPV PROFILE ~3 1/2", 9.2# L-80 BUTTRESS TUBING (2.992" ID, 2.867" DRIFT) ~1897' CAMCO TRDP-IA-SSA-SSSV (2.812" ID) ~ 2086' GLM -- 2783' GLM -- 3414' GLM ' -- 4041' GLM --4595' GLM CAMCO 3 1/2" --5134' GLM ~ KBUG GLM / 5764'GLM -- 6366' GLM --756~' ~L~ S EP 3 0 1994 .t,,~Ka u~l & Gas Con~. Commissi~ ~BOT PBR. SEAL ASSEMBLY Anchor~e 7598' 7651' DOT 'HB' PACKER (2.89" ID) CAMCO 'W-I' SELECTIVE NIPPLE (2.812" ID) 7685'CAMCO 'MMG-2' GAS LIFT MANDREL 2.92' I.D., 1.5" DUMMY VALVES 7725"CAMCO "MMG-2' GAS LIFT MANDREL 2.92" I.D., 1.5" DUMMY VALVES 7767' BLAST JOINT (19.80' TOTAL LENGTH) 7876' BLAST JOINT (19.5£' TOTAL LENGTH) % _ . 7901' BLAST JOINT (9.68' TOTAL. LENG'i:~) 7942' DOT LOCATOR, SEAL ASSEMBLY 7943' DOT '2-B' PERMANENT PACKER (5.875" OD, i___ 4.25" ID) ~TH MILLOUT EXTENSION (5.0' OD, 4.408' ID) 7966' cAMco 'D' NIPPLE (2.750' ID) 7977' ?JBING TAIL ~--81i6' 70P OF FILL (E-LINE 6-19-91) -. 8i56' PBTD 8236' 7" 26# L-80 BTRS (6.275" ID, 6.i51" DRIFT) I APPRO\r-ED BY: HDS D/,TE: 2-25-93 DRAFTED BY: SJN CAD FILE: ,,,,"r,r.- Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 504-7600 May 29, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-13, C-14, C-15 and B-13. If you require additional information concerning this well history, please contact Don Girdler at 564-7637° Yours ver~L~ ,,~ _/:, E. D. Wilson Sr. Administrative Coordinator DRG/vv C-13, C-14, C-15, B-13 RECEIVED Alaska Oil tx Gas Cons. CornmL~.~i~n Anchora.qe "· Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.13- CONFIDENTIAL (7,313'-Kuparuk River) AFE 10-61-1110 API No. 50-029-21328. Ak. Permit No. 85-164. Elevation: 59' KB. Location: 954' FSL, 2169' FEL, Sec. 10, T13N, R10E, Umiat Meridian 4-26-85: ACCEPT RIG. Prepare to skid rig. Skid rig. NU 20" hydril & diverter lines & prepare to spud. mix spud mud & strap & caliper BHA. Make up BHA - service MWD. Change out diverter line valve - test to 100 psi; operational check. Pressure up & test MWD @ surface. Spud in & drlg to 215'. Conductor set @ 115'. 4-27: Drlg from 215' to 2321' w/survey stations. Lost pump press.; checked surface equipment & pump rates. POH from 2321' to surface; bit lost a nozzle, picked up new bit, check out MWD. RIH to 2321'. Drlg from 2321' to 3006' w/survery stations. POH for Navidrill & BHA change to build angle. 4-28: Change BHA. PU Navidrill, orient & test @ surface. TIH & orient @ 3006'. Drlg from 3006' to 3830', Navidrill. POH from 3830'. Chagne BHA - lay down Navidrill & PU building assembly & test MWD. RIH to 264' bridge @ 264', work thru bridge with Kelly. RIH to 3710' - bridge ~ 3710'. Wash & ream from 3710' to 3830'. Drilling from 3830' to 4006'. 4-29: Drlg from 4006' to 4216'. Ream from 4096' to 4216' (undercut & ream out dogleg of 4.5). Drlg from 4216' to 4493'. POH for BHA change from 4493'. Change BHA, test MWD electronics - test MWD w/fluid. RIH to 4423' & break circ. - tight spot. Ream from 4401' to 4493'. Drlg from 4493' to 4790'. Circ. hole clean for csg run. 4-30: POH from 4790'. SLM. LD BHA, service MWD, clear floor. RU csg crew. Run 9 5/8" csg = 121 its - 36# - K-55, shoe @ 4779', float collar @ 4698'. Normal returns throughout pipe run. Make up hanger & landing jnt & cmt head. Break circ. & circ inside volume. Pump 30+ bbls of Sepiolite spacer @ 12 ppg followed by 2 bbls H_O & test lines to 3500 psi. Pump 393 bbls Permafrost type "E" w/5#/~k of Gilsonite 12.3 ppg followed by 51 bbls of 15.8 ppg Class "G" cmt w/3% NaC1 & 1% CFR-2. Release top plug & displace w/5 bbls H 0 & 358 bbls 9.8 ppg mud. Bump plug w/2000 psi - floats held. Cm~ returns to surface. Drain stack - flush out lines - wash out hydril. ND diverter system & install Tankco trash ring & start FMC speedhead. Replace brake pads on draw works. Make up speed head to torque & orient & NU BOPE. Torque FMC speed head to 5000 ft/lbs - RKB to BF = 36.80. 5-1: NU 5000# BOPE. RU & test BOPE; rams, valves, HCR valves, Kelly valves. Inside BOP, kill line to 500 & 5000 -API ring failure on choke line. 9" screwdriver reported down hole, RU Otis to fish w/magnet; struck fish @ 112' w/magnet. Could not get past. POH w/Otis & RD. No fish. Run magnet on HWDP to 112' & retrieve fish & breakdown tools. Continue test on BOP's; test API ring that failed & -1- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.13- CONFIDENTIAL (7,313'-Kuparuk River) AFE 10-61-1110 API No. 50-029-21328. Ak. Permit No. 85-164. Elevation: 59' KB. Location: 954' FSL, 2169' FEL, Sec. 10, T13N, R10E, Umiat Meridian choke manifold to 500 & 5000 psi. Function test accumulator to State specifications. Test witnessed by AOGCC Rep. Doug Amos. Install wear ring & make up BHA. Testing MWD, Navidrill & orient same. RIH to 1330' & cut drlg line, fill pipe. RIH tag cmt @ 4635', drlg cmt to plugs. Test csg to 1500 psi. Test OK. Drlg cmt & plugs to 4677'. Re-test csg to 1500 psi. Test OK. Pump pill & POH to inspect & change BHA. RIH to 4677'. 5-2: RIH to 4677'. Drlg cmt & float equip, from 4677' to 4780'. Drlg formation from 4780' to 4822'. Circ. and cond. mud. Run leak-off test to 610 psi, 12.0 ppg MWE @ shoe. POOH from 4822' to surface, PU Navidrill & stab's, orient Navidrill, RIH to 4822'. Drlg from 4822' to 5278'. MWD failed (valve stuck). POOH from 5278' to surface, changed MWD valve and electronics, PU Kelly and test MWD, still not working, lay down MWD, PU new MWD, orient MWD, PU Kelly and test MWD after installing electronics and valve, test OK, RIH to 5278', now breaking circ. 5-3: Drlg, surveyed, and oriented from 5278'. 5-4: Drld, surveyed and oriented from 6600' to 7329'. Run wireline survey @ 7329' (MWD failed). Drld from 7329' to 7798'. Circ. and run wireline survey @ 7329'. 5-5: Drld from 7793' to 8270'. Circulate. Short trip to 6376'. Circ. & pump down. POOH. Retrieve survey, service MWD, lay down MWD & Navidrill. RU loggers, RIH to 6074' tool wouldn't go below 6074' POOH, install wheels and remove stand-offs, RIH to 6074', tool wouldn't go below 6074'. POOH w/logging tool. 5-6: RD loggers. RIH w/bit to 8270' (worked tight spot @ 6074'). Break circ. and clean hole. POOH from 8270'. RU Schlumberger, RIH to 6110' w/wheels (couldn't get deeper). POOH, RIH w/tool slick, still couldn't get below 6110', POOH, RD loggers. RIH, reamed 6000' to 6244', RIH to 8270'. Circ. POOH from 8270'. RU loggers, RIH w/CNL-FDC-DIL-GR to 8273'. Logging. 5-7: Run CNL-FDC-DIL-GR from 8273' to 7500' Run DIL-GR to 4777' RD loggers. Lay down 8" DC & BHA out of derrick. RIH to 1300'. Cut drlg line. RIH to 8270'. Circ. POOH, laying down DC & BHA. Pull wear bushing and change rams. RU csg crew and run 7" csg, 208 j ts, shoe @ 8236'. FC @ 8155'. ECP ~1 @ 7958', bottom. ECP ~2 7928' top. Make up cmt head, circ. and pump 40 bbls of 12 ppg Sepiolite spacer, now mixing cmt. -2- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.13- CONFIDENTIAL (7,313'-Kuparuk River) AFE 10-61-1110 API No. 50-029-21328. Ak. Permit No. 85-164. Elevation: 59' KB. Location: 954' FSL, 2169' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-8: Mixed and pumped 310 sks of 15.8 ppg Class "G" cmt w/l% CFR-2 & 0.3% Hal-24, displaced w/312 bbls of NaC1/NaBr @ 10.2 ppg w/full returns, bumped plug to 3000 psi, inflated pkrs, checked floats, OK. Transfer salt water to rig, RD cementers, backout landing it, RD csg crew. RU Dresser, RIH w/CCL-GR-Gyro to 8100', GR failed, POOH, re-run CCL-GR from 7500' to 8159' RIH and perfed 7770'-86' 7878'-81' 7890'-94', 7904'-10', 8021'-56' w/12 JSPF w/5" csg gun in 3 runs. Run #6 - junk basket GR from surf to 7990'. Run #7 - RIH w/BOT permanent pkr set @ 7948'. RD Dresser, change top rams, RU tbg tools, test 3½" rams to 5000 psi. RIH w/completion equip. 5-9: Ran 247 jts of 3½" 9.3# L-80 BTRS tbg, gas lift mandrels, blast jts and subsurface safety valve tagged bottom pkr @ 7943' tbg measurement. Stab-in bottom pkr, ran communication test, pumped 4 bbls @ ½ BPM @ 1700 psi. No communication. Dropped ball. Set top pkr @ 7620' to 2800 #, sheared out. Shear out sub @ 2800#, pull out of PBR (sheared @ 140,000#), space out tbg, make up hanger. Displaced tbg w/90 bbls of diesel (70 in tbg, 20 in annulus, land tbg, tested hanger and PBR to 1500 psi for 15 min. OK. Back out landing it, set back pressure valve. RD tbg tools, RD displacement lines. ND BOP's, install x-mas tree, test tbg spool and tree to 5000 psi. RELEASED RIG. -3- Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 5, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Production Profile Logs for Wells B-10; B-II; C-9; C-13; C-14; C-15; C-16 Included with this cover letter are the logs and related pressure data for production profile work completed at Milne Point prior to shutdown. This information is submitted to the State as per Rule 9 of the Kuparuk River Field Rules. If you should have any questions or comments, please contact Mr. Don Girdler at 564-7637. ~~Tf R. Painter Division Manager DRG/vv Oil & Gas Cram. Commissior~ Anohorcge Tom Painter /:)/vision 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 Mi!ne 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 ~ ~ ~ne Point. ACTIVE: B-3, B-4A, B-6, B-9, B-10, B-11, B-13, B-15, B-16, C-I, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-i6 STATIC: B-20, B-21, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves, if necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-Il, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by. displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of prOduc- ing. A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the. wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that fr~ezing 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 ~o carry the if you have any cuestiens on the shutdo~m procedure please contact Don Girdler at 56~-7637. Yours very truly, STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION COMMI~.__~r, ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Add~e2s(~1 C Street Ste 200, Anchorage Alaska 99503 6. Unit,gr, Prop~rty n. am,.e .. , . , ~lllne rolnE unlc 4. Location of well at surface 954' FSL, 2169' FEL, Sec. 10, T13N, R10E, U.M. 7. Well number C-13 At top of productive interval 1240' FNL, 899' FEL, Sec. At effective depth N/A At t~_t_~)~lCP~lL, 698' FET,, Sec. 15, T13N, R10E, U.M. 15, T13N, R10E, U.M. 8. Permit number 85-64 9. APl number 50-- 029-21328 10. Pool ' Kuparuk River 11. Present well condition summary Total depth: measured true vertical 8270 feet Plugs (measured) 7313 feet Effective depth: measured true vertical N/A feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 80' 16" To Surface 115' 115' 4743' 9 5/8" 1370 Sxs 4779' 4623' 8202' 7" 310 Sxs 8236' 7288' measured 8021'-56'; 7991'-09'; 7904'-10'; 7878'-81'; 7890'-94'; 7770'-86 true vertical 7127'-54'; 7105'-18'; 7039'-44'; 7019'-22'; 7029'-31'; 6938'-50 Tubing (size, grade and measured depth) 3~", L-80, 7966' Packers and SSSV (type and measured ~p~h) SCSSV @ 1897' ; Ret. Pkr. @ 7598' ; Perm. Pkr. @ 7943' 12.At t ac h ments Description summary of proposal 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Detailed operations program [] BOP sketch [] ~'.._ ~ ~ ~ ~- Name of approver 15. I here~c~tify th~he foregoing is true and correct to the best of my knowledge Signed ~ ),~n...,--~-,)'"X~.~,%O, . Title Sr_ Production Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval Date [ Z" 2. 5 ~f~'(.¢, No. Approved by [] Plug integrity [] BOP Test [] Location clearance ~:,-. ,.;. ..... , , ~1,'~,[ [~. ~1I~ Commissioner Form 10-403 Rev 12-1-85 by order of / the commission Date/ Subrrlit in triplicate ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C01~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2. Name of Operator Conoco Inc. 3. Address ' 3201C Street, Suite 200, Anchorage, Alaska 4. Location of Well 954' FSL, 2169' FEL, Sec. 10, T13N, RIOE, U.M. 99503 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. 24416 7' Perm~N=~ 8. APl Number 5o- S029-21328 9. Unit or Lease Name Milne Point Unit 10. Well Number C-13 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-1t-85, and its suspended status should be removed. 14. I hereby certify that the fcr~egoLng is true and cor_,r/ect to the best of my knowledge. Signed-' L~--~~-~ ~: -f~ _~~ ,['~_--J Title The s~ce be,!d/¢ for Commission use Date Conditions ~lt'Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (go7) 564-7600 August 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 19, 1985, we sent you the "Well Completion" forms #10-407 for Conoco's Milne Point Unit wells No. C-7, C-9, C-ii, C-12, C-13, C-14, C-15, and C-16. On these forms, the true vertical depths at TD were inadvertently left off. The following data should be added to the submitted forms: WELL NO. TD (MEASURED DEPTH) TD (TRUE VERTICAL DEPTH) C-7 9,940' 7,429' C-9 i0,881' 7,308' C-11 8,990' 7,527' C-13 8,270' 7,313' We regret any inconvenience this may have caused you. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, R. J. Francis Manager - Engineering John R. Kemp Manager of Alaskan Operations [cortoc_ Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-Ii, C-12, C-13, C-14, C-15, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R Kemp~ ~laskan Operations KJS 5/vv RECEIVED AUG 2 0 ]985 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION cO.,., IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. ~ ~-- 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-21328 4. Location of well at surface 9. Unit or Lease Name 954' FSL, 2169' FEL, Sec. 10, T13N, R10E, U.M. Milne Point unit At Top Producing Interval 10. Well Number 1240' FNL, 899' FEL, Sec. 15, T13N, R10E, U.M. C No. 13 At Total Depth 11. Field and Pool 1501' FNL, 698' FEL, Sec. 15, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. muparuk River 52' KB ADL 25516 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 4-26-85 5-6-85 5-8-85 N/A feet MSL 1 17. Total Depth (M D+TV O)8 2 70 ' rT~l~J, ) 815 6 ' 18. Plug Back Depth (MD+TVD)(7 2 2 8 ' TVD) YESI~19' Di rectiona. Su rveYNO[_l I20' Depth where sssv set 1897' feet M D I21' Thickness °f Permafr°st 1800+ 22. Type Electric or O~her Logs Run CNL-FDC-DIL-GR-CCL-Gyr o 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 0' 4779' 12~" 1120 sx Permafrost 250 sx Class G 7' 26# L-80 0 ' 8236 ' 8~" ~ 310 sx 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) 7770'-7786' (Middle Kup) 12spf,120°phasing 3~".9.2#.L-8() 7966' 7598' 7943' 7878'-7881 ' (L-8) 12spf, 120°phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7 890' -7894 ' (L-8) 12spf, 120°phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED . 7904'-7910' (L-9) 12spf,120°phasing 8021 '-8056 ' (LK-2) 12spf, 120°phasing 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I ,. Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD ,, . Flow Tubing Casing Pressure CALC. ULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE i~ '28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . Mask~ 0it & Gas C0~s. A_nchora.~e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ...... " GEoLo(~i(~ M'~{K:ER~;:. .............. ';' ': :":FORMATION'TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time ofeach phase. . . KA 3,759' 3,740' MA 4,045' 4,002' NA 4,315' 4,238' OA 4,490 ' 4,384 ' T/Kup. Interval 7,621' 6,823' Middle Kuparuk 7, 770' · 6,938 ' Laminated Zone 7,787' 6,951' Lower Kuparuk 7,990' 7,104 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 Eastman Whipstock A PETROLANE COMPANY (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 May 31, 1985 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two copies of the Gyro Multi-Shot survey run for Conoco Inc. on Pad C, Well No: 13. This is to be considered a formal letter of transmittal. The data herein, is to considered strictly confidential. A copy of thiS letter is being sent to Conooo's represen- tatives, Mr M. Bradshaw and Mr S. Davies. Should you have any questions regarding this survey data, please refer all questions to CONOCO INC. DistriCt Technical Coordinator cc: M. BRADSHAW S. DAVIES RECEIVED JUN 1 1 ]985 Alaska Oil & Gas Cons, Commission Anchorage Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide Eastman Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY CONOCO, INC. COMPANY Pad Cf Well Number- 13 WELL NAME Milne Point, North Slope, Alaska LOCATION JOB NUMBER A0585G0256 TYPE OF SURVEY Gyro Multi-Shot DATE 06-May-85 SURVEY BY B JAHN RECEIVED'; j U N 1 1 1985 OFFICE Alaska Oil & Gas Cons. ~m~b',~i~ge, Alaska Annhnr,qg~ ( - Eastman ~ -- Whi~tock- A PETROIANE COMPANY ( (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Date: May 31, 1985 Conoeo, Inc. 3201 C. Street Suite 200 l\nchorage, Alaska 99~j03 \'1e1l Number: Pad C, Well No: 13 Loca tion: Milne Pt., North Slope, Alaska 'Type of Survey: Gyro Multi-Shot D a tC-) : 06-MAY-85 ~~e thod of Compll ta t. i on: Radius of Curvature Surveyor: B JAHN ~Job Numb(~r: A0585G0256 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosinq the or.19 l.nal and one copy of th,E,' Gyro Mul t'Ì- Shot sur\7ey run on the:' above mentj.cned wf~11. '1'0 date, t.he following di~jtri.bilt:ion has beG'n accomplished: A.. 1 copy del i V'2r ec:i \.0 dr i ll..lnq .for :i. n ...house d i r; r.!: .L b l1 t: i. 0 n . 9 cop.i{~S noted f:~)r (":) ¡ CO~11T).:¡ny reT."ìr:(-'S(~rltativef).. -;, C.. (')~) 1. (,.\ S 4,~ .., l' ';,' /. 'i' I", ..:, l' 1'" "\' ì t\ f"t. \,1 ¡::', 'J] ( '-1' 1 ~:. ,.., ..J '£:' 'i;;.. . ..L. \.... J., I ~ ., ,,, 11<.. '- I., v..' '.", 1::. ..~ . B. c. We wish to take this opporturd ty to t!iank you for: using Eantmttn vJhipstock and look forwê.l.rd to bc..i.r\<J of S0f\iice in thE~ :t:uture.. Coord i n~3 tor "''''/f'' .\ ~) c.. '.. 1. .1. ~- cc: L.A. Dinges .- Off~)hore }::{p}ornt i.on ConOGO O..G. Rie.1 - P..E..S. HesC::f'1v'o,ir Sf:ct.i..on Conoco H.E. Gill..i.12inf':'l - P.I<.D. H~::'serv().ir Sectl.on Conoco \vi.lliam Van 2\1r:.:!n - A.l.:lsk".t ():~,1 and Ci:':l!3 Con~3el:'vation CornxEission J.L. Weaver .. Chevron d.S.A., [ne. DaVE~ 'E ngG t.r.-OI1: - Chevr. () n U.. :.~: . ,q.., I nc. Concord nff ice D.)le Bossert -. Ch¿:'lmplitl Petr\').."Lt?lUil (.':':J. C.E. Seery, Jr. - Reading and Bute's Petr01e~m Co. N!:? i 1. 13 u t. t: r ~~ IT! -, C i tie::; S 1;:\ .r vie (~ 0 L 1 i.! n '::.i (; a:.:; (~o r p . Directional Drillers/SutrSurface Surveyors/Instrument & Tool Rentals/Sales/Worldwide. ~. KUPARLIK FIELD, NORTH SI_OPE, ALA'.:.;KA GMS, 0-[-:100 MTI, '.--;URVEYFIR: B ,JAHN? DATE RUN: 06-MAY-85 GYRO NO: 291, CAMERA NO: 079, ?0 DEG A/;..[ NO: 1:2,48 FORESIGHT: N53:2:4 i:::E VERTICAL SEE:'FION CALCULATED IN PLANE OF F:'ROF:'OSAL DIRECTIOI'q: :F.; 28 DEE;. 2? MIN. E R E E ri F;: E 0 F '.E; I_1R V F Y RADILIS OF' CI..IRVATLIRE METHOD Eastman r-:uNC~C:C~-., I NC. PAf] C, WELL Nr-t: 1:2.: r-4MS KUF'ARUK F'IELT].~ NF'tRTH SI_CIPE_~ ALASKA ,_10 B N CI: A c.)._,,= .... J..-, (_) ..- ._, 6 C:r'tMF'UTAT I ON T I ME DATE I:--:: 59:27 24-MAY-:--:5 ,. F'AGFF Nr-i. 1 TRUE MEA:_E;URED 'RRIFT DRIFT COURSE VERTIC:AL VERTICAL :::-;UBF:;EA R E ti: T A N G U L A R C L 0 K--; U R E Dr-,]4LE DEPTI---I ANGLE DIRECTION LENGTH DEF'TH SE(':TION TVD C 0 0 R D I N A T E S 'FiISTANC:E D!REr':TIOr,,I :--;EVERI FEET D I'1 'Fi !"1 FEET FEET FEET FEET FEET FEET Et M DG/1 (":,¢_ 0. 0 0 0 0 0. 0.00 0.0(1) -52.0c) 0.00 0.00 0.00 0 0 ' O. 0C 100. 0 0 0 0 100. 1 c)0.00 o. (i)(i,:, -1.8.00 0. C)C) 0.00 C). 00 0 tI) 0.0( 2c) 0. 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(-) =~.- c}. 1 (:: ' 5E: 0., 0.2,"_- 0.5:--: 0....._ c), ()0 .::._,'..)0, (')_ c). 0 0 100 . 2499. . . '-:'~ R. _ :3.74 24.4.'7 , ':.):::. . 1 . ._,':-'5.._ ,-,'=' =[._. :2:'7 E 2/-,_ O. (').. c) .... 1 ."5 ._,c. 61 C) E 1 (") c) . .,..._ ..'.-, Fi':':':'.,... 9. :=,,_ :2: , ':..,..._":', .,.._'::' '"l 47 · '.-7., ::3 1 , 4.5 .=,'"' 5, ....~/._, E 270c) c) 1 = ':' .., 4 C) W 10C) 269':'.-' 9::: 4:3"1- .?/,47,':'-':'": 1 :5:1 c- Pi 7~:i E ~ . · --' . n ,, · . n · .. ~ .... · _ . ._1 - n 28 tl) ti:,. (')_ c'). 0 c). 100 . 27 c.,.. ':.'.., ':.".. :::_ ":1- . ~_ .,...'.';' 2 '747 , '.-.".' 8 -'.s', 0 :-"4._ ..,e 5.74 E 2 ...... c.,, (-) C), ':":' 1 '=;_ ¢'._, 19. () W 1 t'). ¢)..2 :::_ 9.. ':'...'. . ,:-,,.. :z:_ 4 ./.:, 7 2 :.2:47.9. ::::.. ='"':". 24'='._, .=~._,/-,_ 7 E 5 .~'i:':: S 75 =~] .... 74 ::; 75 22 E 6.0:':: S 72:2:0 E /,_. t')'~)_ . .:..-,'" 70:30 E 6.09 ."F.; 68 2L=: E 0. 0. '-' '= 0.27 0.25 0.25 Eastman Whipstock l)) A ?~'TRO~,ANE C'20~PlWY C F- N 0 C r'z~, I N C. I::'AD C -, WELL Nil1: 1 :':: GM:E; KUF'ARUK FIEL'Fi, NORTH F;LOF'E.., ALASKA ,J ri B N 0: A (.) .... -.. ._, i..., (_) ...._, 6 F:OMF'!JTA'I' Z AN 1" I ME DATE 1 :'::: F;.. 'T,'.: 27 ',.'7-: 4. - I'I A Y - ...,._':' .=; PAGE NO, ]"RUE MEASURED DRIFT DRIFT COURSE VF..--R-I-ICA/. VERTICAL SUBF;EA R E C T A N G U L A R C L 0 '.:; U R E DOGL DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S FtISTANCE DIRECTION :_--;EVER FEET ri I"1 ri I'.1 FEET FEET FEET FEET FEET FI:::ET 'Fi I"1 DG/1 :'::00(':,. . (':,. 15 S .,:.._,'-' ~ 0 bi :310C,. 3 15 ::--; 1'~") 0 E :32OC). 4, 0 :--: 15 0 F :'::30o, 9 0 S 17 0 E :E: 4'r')0. t. 2 ':":' :::; 2':..')':::' E 1 C) 0. 2'.--.¢ '? '.9 · '? 7 10 C), :"-': C)'?'.9. 'F' 2 100. :31 '.-.-.":.-:. 58 1 (:)(1), :--',2'F.'::'.:, 7 :L 1 C)o, :E: :3':--" 7, 0:3 2.64 '.--; .5.50 E 5.62 '._--; 5. 11 E 1:3.4'? '-' /-, 86 E o_-~ _ · 26.04 c-._. lC.) .4.5 E 4:2: .') 1 '.--4 1 A 2:2: .F'. 6.11 S ,"S4 22 E' 0,0 7./-,'[') :::; 42 17 E :3. 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'.::;U B'._-.; F A MEA'.=_;URED VERT I CAI_ VERT I CAL 'r]EPTH DEF'TH DEPTH FEET FEE-I- FEET 7:2::--::'::. 6 !? 66 ()0.00 ,/:,54. 8.00 7.4/_-, 2.02 A 700.00 664:3.00 '759 ('). 79 6800.00 /:, 74 E:. (')0 772,r':,. 6 (") /_-.'.::,' 00. ,F:, 0 ,,:':, 84 ::2:. (':, 0 ...v ,-.~ 1:2,] ,-,! - _ . . . / ,:,._ ..,. 26 700('~ (-)0 6 c...) 48.00 7 '.;',' 84.. 67 71 (')0.0 (:) 7,[:],*.1. 8. ,:"),[::, 811 A. i 4. 7200.00 7 .1. 4'2,. C)0 ~,-~ .*--! ~- ,-.. .... ..-., ~. 1 ,-.-.'-' 7:2. 0 ,F:, . ,F:, ,0_ 724 E: . (":, ,:],.. R E C: T A N G U L. A R C 0 0 R Ti I N A T E S FEET 1646.:.:.:8 S :::71.18 E 1712:.77 S '.--.¢i/_-,.5A E 1778. v-.:,,.. :_-; ,:.vA.o,.._. 07_ E 184:3.87 '.:; 100'?).54 E t(). ,. ,. 19. O_ ::',_. ':,.....'-.' '.~:; .' '=__ ~- ? 4 E 2:304. '1,5 S 1::_::56. 65 E 2 :::':74. :'30 '.:;1 q. 10.4. 5 E: 2 4 4 = F;::: · :..._ S .1.464. 16 E F:: ri I'1F' I..I '[' A 1- I 0 I',,I T I ME DATE 14: 19: 4 .1. 24-MAY-:=:= C L 0 S U R E D I S T A 1"4 C E D I R E C: T I 0 N F E E T D I'1 :186:--:. 11 ,.E; 27 ~'.]:3 E 1 '? 42. :5'P S 2E: '? E 2022.70 S '28 2:6 E '":'1('}2 1.=; S 28 42 E .,_'---' 1:31 ,, .._,':-- 1 S.."-',:,'-' 57 E F:'AGE NO. Eastman - Whipstock l A t~'TROLANE OOICPANY C:ONC,20., I I,.IR · F'AD E:., WELL NO: 13 GMS , InB NO: A,J, .... = .... L,t.~.-._,..'--. KUPARUK FIELD, NORTH SLOF'E, ALASKA GM'.:;., 0-:-]:1,:]0 MD-, '-E;URVEYOR: B .JAHN., BATE RUN: 06-MAY-85 G Y R 0 N 0: 2'.;:' 1 -, C A M E R A N 0: 07'?., '.-.-..'(':, I] E G A / U N 0: 1 :.--'. 4'.:: FORE::;IISHT: N5:--: 34 1SE RF"CORD OF INTEI'~F'OI..ATED '.E;URVEY _ Eastman ipstock A £~" TROLANE OC~ft:"ANY ~-:0 N 0 C r3, T N E.. PAD E:, NELL N~"'l: 1:'.:: GMS I<:UPARUK F T ELD, NORTH'"'.=,Lt..qF'E , ALA.:,b..A'-' "' ,J ID B N Fi: A,o. '..., ,:,._, L., (J' ..- .:,,-':, F:Fd:-IPI_ITA ]- I ON T I ME fiATE F'AGE NO. KA KB KC KD L.A LB MA MB MC NA NB NC N D NE IxIF OA OB UI'..ICi'"tNI=. M KFI .1. 9 T / I< I MK- 1 B/MK- 1 L-8 B/L-8 B/L-9 L, K- 1 B/LK-1 LK-2 B / LK-2 MARKER ....... C 0 D E NAME MEA'SURED DEF'TH FEET 3759.00 3810.00 .]::355.00 3 ? 10.00 3945.00 3979.00 4045.00 4125. (:)0 4197.00 4:315.00 44'? 0.00 · ., / ~ . C') 0 7497.00 75 ? 0.00 7621.0(:) 7770.00 7787.00 7876.0C) 7::: 9::::. 00 7'F,'C)4.00 7910. O0 7990.00 8007. O0 8021.00 8056. O0 TRUE VERT I CAL DEF'TH FEET :.5:740. 10 :37C-:7.74 :3829.5:1 ':":'-" '--' 96 · ..' ~-1 / ..' ,m :3911.74 3942.62 4001.7 ::: 4. C':, 72, '70 4 ] :::F;. '-"-' 42:-:.', 7..=;/.-, 4261, :.5:,.'") 4. 2 :::": '.1-, '2 c:, 4. :301. ! ,'.5, 4:31 :':: ,, 7'7,' 4 :':",55,37 4 :~:: 84 ,, 4- 7 44 E'; 6.2.4 &, 72'7. :2 :':: 6'79'.:::'. 39 /_:, 8:2:::3.3 !:9 ,/-', 9:37.6:3 6'? 5 C). 5 7 C, 17,95 7 ():30,, ::.'E..: 1 7 c). ::,,_ 9.. 1 ..."" 7(')4:3.65 7104.052: 7118. :31 7127. :::0 71 -:,o '"'=' SUBL:;EA VERT I CAL DEF'TH FEET .]:688.10 · :,7..:,.:,. 74 :3777. :.5:1 :'."',',.:359 · 74 3 :--: 90. d, 2 :.5:94. 9.78 4. 02 ("). 70 4. 0 :::', :--:. 8:2 41 ::::5. '."!;6 42 (':, 9, :30 4. 2:3:2.20 4. :24'.:.:,'. 1/::. 42,'.:':, !. '7'P 4:3 0:3. ::: 7 4.:3:32.47 4.4. 04 ,, 24 6,'-,'7 :~, :;:'.: :3 6747. :39 6'7'71 "" . .,::, .6991.65 7052.0:3 7066. :31 7075.3 () 7101.51 R E c: T A N G U L A R is: ct 0 R D I N A T E :=: FEET 1.: ..... 37 ,_, 64.'70 E 1 =' ' ~":" · -,(.:'..... '._:; 74 .9 6. E 16 F,_. 12 o._, 84 . C:'_ :::: E 18:.5:. 35 '--3 'P5. :30 E 1 S.,' d,. 04 L=: 102.6'7 E 20:3.:36 .S 109.74 E 2:3:.5:. 'P:--: S 12 :':-:. 8 ::: E 26,/-,_. ...5,_,':' :E; 141 . .,...":' ,_,/- E 297.44 '.:; 156.98 E · -",.:., 1 4.5 '-' 182 =--=' E u u -- I _1 ..-, :::6,5.00 S 188.59 E :'::7:E:. 07 -S 1 '? 4.41 E 387.7,'-, :::; 1F.'8.7:2 E · :, .~ ._,. 18 S 201. ',7-.': 9 E 4.:;.21, C) 2 S 2 ]. 2. ,:") 7 E ";' 1 '--~":: /-, 0 ':' 1:27 ('-~ ,, 0 6 E: 22(':'.';; ......' :d,' 8 1276 '---' '> E -n u ,-' 2248.01 '.:;1:312. '7:!;:': E 2'7' 56.77 ::: 1:3.1. 9.6:3 F' 2262.45 c-._, 1:2:24.. 0'7 E 2265, 55 S 1:326,4.9 E 2 :'::: 0,'5,, '--'J. 1 S 1 '-'.-,-.., '=,:,''''' ,, :::,:]) E 231.,5_,,,:31 S 136/_-,,.(t-7 E 2:32 :-4,, 12 ._,':' 1:371. :':: 1. E 2 :':: 41..=; .... 2 :_--; 1 '-':,,:,'-'._,='. 4:3 E C L 0 S U R E Et I :-_-; T A N iS: E D I R E C T I 0 N FEET D M 150.12 S 25:37 E I68. 15 :E; 26 2:E: E 1:E:5.29 S 26, 59 E 2 c)./-,_. 6 :':: '.:; 27 .:. ''~',:,'''' E 221.27 '.:; 27 .]::--: E · "-:,--,. :_=; '27 4. 2 264.71 S 27 5.a E :::c:, 1 /-,'-P S 27 '"' =' _ . . _ . ,..I ,j E 3:3 d-,. :3:2 '.E; 27 4 9 E :-..:':) /-,.. .. _. 0:::_ _ ._,':' 2'7 '..-':7 E 4-10.:::4 S 27 19 E 4...'._,. :.5: ':' :.27 'l ::: E 4:35. '71. :E; 2'7 ::3 E: 44.]: 76, ':' 2'7 4 ~" 471.42 S 2,'L, 44 E 4'P,:'-) ,, '7 ¢5: t.3 ':ii:,'.":, :ii: 2 E: 5:3'F.:'. ,'5,'7f.;; 2.=.55'7 E :2: :'::/', 2./', ..../", .:," .... .2_ '::).. 2 '"':~.. 24'2:0 ,, '7 :!:",'.E; '::!:'P 4 (:) E 2.4-4.0, 2:3 S 29 4~' .... · 25:34,75 '.::; :::':':"} 4. E ,..._,4. .... 64 S :3 C) 6 E- · 7.:6 (':, ':', '-'""' -,, ..: ..... S :.5:(.]:, 17 E :2.'5,14. · 28 S :3,[:)1. 9 262:1,4.2 S :_30 20 E 26:25,:3".'? S 30 21 E 2677,35 S :3(..7.:' :_30 E 2689, 77 S 30 32 E 2.697 ,, d,d, S :.-.:0 2:':: E 27:20.69 S :3 C) :'37 E'] ( __. _Eastman F'AD F;, gIELL NO: 13 G1"1:_--; I'::]_IF:'ARUK F I E!..D, I',IFflRTH S/OF'E, AI..A'.E;I<~ MARKER-. C:ODE NAME ,J 0 B N 0: A 05:35 G 0'.-.25/_-, B / K I TI] TRUE F;I_IB :--.:;E A MEASURED VERT I CAI_ VERT I C:AI_ DEPTH DEF'TH [~EF'TH FEET FEET FEET F-: 1 '-"'-' (') f) -;' ''~ '-' .... = ...... .' 14 .8 2 / 1 ._./- 2 . ',:: 2 :--: 270.00 7:2:1 :]-:. :2:0 7261. :--: 0 C: 0 M P U T A T I 0 N T I ME DATE 14: 0:3: 01 24 - M A Y - :35 PAGE R E C T A N G I_1 L A R C 0 0 R D I N A T E ::; FEET ;2:384. :36 :E; 141:--:.41 E · .'4 .... ~-~-~ S 1471~.:2:0 E C L r-i ,.:; LI R E D I ::; T A N C E F~ I R E C T I O N F E E T B I'1 2774.'78 :_--; :30 45 E 2:E:/-.2 1.7 ':' :'::¢~ ~/-. E Eastman Whipstock A PE'rRO(ANE COMPANY CONOCO, !NC, , PAD C, WELL: NO, '13 Gl'IS KUPARUK FIELD.~___N_ORTH SLOPE, ALASKA EASTI'IAN I,/HI PSTOCKi. ' INC. . · HORIZONTAL PROJECT I,ON SCALE 1 IN..- .500 FEET' .... DEPTH INDICATOR, TVD 43~3 ,$805 5573 ................................................................... 5949' 6339 DEPTH 8270 HD;. 731~3o30 TVD - ~,.,i .......... :_;_, SOUTH '2'4'55';05"E/[$T 1.471';30 67'30 OLOSURE 28$'2,,17' S 30 56 3 E ~I .... ~ CONOCO, INC. PAD C. WELL NO, 13 GMS KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. - r i 2000- 4000 ................ 6000._ 500 500 2500 · 0 2000,, VERTICAL SECTION CLOS'URE .,2.8.6.2 ...... 1..7 .... S..30 ...... 56 :3 E · 4000 Suggested form to be inserted in each "Active" well folder to check for timely compli~.~e with our regulations. ~)¥ERATOR, WELL NAblE AND NUMBER Reports and Materials to be received by: Date ,i Required Date Received Remarks Comp~Let ion~ Report Well His tory x~~% Core Description '~~ . ., .... .-',~ .... ~ ..... .- ~.,~ '~ ,,.~,~ ~_~ , Registered Survey ~ . Inclination Survey ' Directional Survey Drill Stem Test Reports ~Z~x*, -"~ .... · LOCATION IN SECTION FRO~ S. LIN£] FROIvl E. UNE 1068' 220:5' 496' 2027' C-13 I 954' 839' 724' C · 16 I 610' 2169' 2134' 2098' 2063' 1287 ' 2273' 457' 2219' C-19 I 1468' 2329~ I STATE PLANE CO-0RDS. /~)RTHINGS EASTINGS 6 , 029,351.58 558,255.76 6, 028, 280.21 6 , 029,237.39 558~ 438.90 558,292.56 6 , 029-(12~.. 94' ' [' 55 8"~529.0 6-* 6 ,029 J, 028, 894.48 6, 029,569.69 __ 029,749.88 558,566.J4 558t 402:27 ~.81 185.84 558~ 248. 260 558, 128· 09 ' ' SI M P~'"'N LAGOON MILN[ PT. UNIT )a. qY SCALE IN MU_ES CONOCO MILN[ PO!I~T UNIT EXISTING OE.VELOPM E NT NOTES: .... !. STATE PLANE CO-ORDINATES ARE ZONE 4. Z. ALL GEODETIC POSITIONS ARE N A.D. 1927. :~. · 4. LOCATED WITHIN S~CT. I0, T 13 N, RIOEt U.M.,AK. GEODETIC LATITUDE 70e 29' 26. 894" N. 70 o 29' 21.260" N 70029' 25.768" N. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF TI~E SECTION CORNER POSITIONS. --'70°29' 24.639" N. 29' 23.5o2" ~ 7D° 29'22.387"N 70° 29'29. 044" 70° 29'20.680'' 149° 31' 25.909" W 70o 29' 30.821" 149° 31' 29. 208" POSITION LONGITUDE }DATE !CHECI<EQ 149° 31'20.280# W II -I-85 J.H. 149031'24.486'W. I 6-1,85! J.B.S. 149°31'23;438"W' I ' "~'-'"~'~:'- "' 149°31' 22' 374"W' I " 149° 31'27.550" W, II -9 -85 L.0. I 11-10-85i L.O. .,?~; O? 4 .~ ":~-~,~ I!1 CERTIFICATE OF SURVEYOR : ~L~ --'~ -- '~ ~'~ Ill - .~r~..' ,-, '~,",:-'~ iii~ ~~, I HEREBY CERTIPY 7HAT lAM P~OPERLY ~'~.n ..... ':.-"~;/ ~",-,'2~ III ~~[~il & G~s ~s. Co.mission FIELD BOOK .. 22-85 22 - 85 46 - 85 46 - 85 'C' PA D AS- BUILT WELL LDCATI01~ Sueveyed toy CONOCO i SCALE : J SHEET : I' · 400' J 2 OF* ~) COulaENTS : ~BERGER' OFF%!-iORE SERV>~E$ Division of Schlumberger Limited HOUSTON, TEXAS 77001 PAGE 2 OF 2 JULY 5th, 1985 C ~r · .O]>~OCO INC. 3201 "C" STREE".F ANCHORAGE, ALASKA 99503 A'~tention: MIKE BRADSHAW PLEASE REPLY TO $CHLU.~ERGER OFFSHORE ~t~F~Ct~S POUCH 340069 PRUDHOE BAY, AK 99734 ATTN- · HOLLY BURGAN Gentlemen: . CASED HOLE CNL/GR-& Enclosed ore prints of the2" &' 5" DIL: LDT./CNL '& C.YBE_RLOOK. ComPany CONOCO, INC. , Well MILNE POINT UNIT C-13 Field. MILNE POINT ., County NORTH SLOPE .qtote ALASKA Additional prints are being sent to: 1 BL prints & 1RF CITIES SERVICE OIL & GAS CORP.'" 'P..O. BOX 939 o . __prints BAKERSFIELD ? CA 93302 ATTN'i NEIL BUTTRAM c/o JIM QUINN ,, prints prints _~prints __prints prints The film is RETURNED TO CONOCO We appreciate the privilege of serving you. prints RECEIVED BY: R"_F -jUL Alaska Oil'& Gas Cons. Commission Very. truly yours, AnChorage SCHLUMBERGER OFFSHORE SERVICES CATHERINE GADOMSKI DISTRICT MANAGi[R CONOCO, INC. SCHL_UMBFRGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON, TEXAS 77001 PAGE 1 OF 2 JULY 5th, 1985. 3201 "C" STREET, SUITE 200 A~ICHORAGE~ ALASKA 99503 Attention: MIKE BRADSHAW PLEASE REPLY TO 5CHLU~-~BERGER OFFSFIO~E StcRVICES POUCH 3'40069 PRUDHOE 13AY, AK 99734 ATTN: HOLLY BURGAN Gentlernen' CASED HOLE CNL/GR & Enclosed are 2. B_L_prints of the. 2" & 5" DIL, LDT/CNL & CYBERLOOK company CONOCO INC. Field MILNE POINT Additional prints are being sent to: 1 BLprints & 1RF WEST COAST & ALASKA DIVISION, 290 MAPLE COURT, SUITE 284 VENTURA, CA 93003 ATTN: PHIL SALVADOR on: ., Well MILNE POINT UNIT C-13 , County NORTH SLOPE State ALASKA 1 BL prints & 2RF CHEVRON U.S.A., .INC__. . P~_0_O. BOX ~_07839 ANCHORAGE, AK 99~10 1 BLprints & 1RF CONOCO, INC. P.E.S. RESERVOIR SECTION OFFSHORE BUILDING P.O. BOX 2197 HOUSTON, TX 77252 ATTN: GERALD KIEL c/o GEORGE LAMB 1 BLprints CONOCO, INC. P.O. BOX 1267 PONCA CITY, OK 74603 ATTN- H.E. GILLILAND/6356RW 1 BLprints & 1RF ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: WILLIAM VAN ALEN 1 ]~rints & 1 RF CHEVRON U.S.A. , INC. P.O _. O z-_ 8200 CONCORD, CA 94524 ATTN: DAVE ENGSTROM c/o LOUI S__KLK~ 0NSK__Y 1 BL .prints & 1 RF CHAMPLIN PETROLEUM COMPANY P.O. BOX 1257 ENGLEWOOD, CO 80150 ATTN: DALE BOSSERT c/o BILL KIRSCHNER 1 BL prints & 1RF READING & BATES PETROLEUM CO. 3200 MID CONTINENT TOWER TULSA, OK 74103 ATTN: C.E. SEERY, JR. SOS.-15§5,A The film is RETURNED TO CONOCO We appreciate the privilege of serving you. DATE: Very truly yours, SCHLUMBERGER OFFSHORE SERVICES CATHERINE GADOMSKI DISTRICT MANAGER STATE OF ALASKA AND GAS CONSERVATION C(~...-MISSION ALASKA~_.L SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-67 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21328 4. Location of Well SURFACE: 954' FSL, 2169' FEL, Sec. 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB Lease Designation and Serial No. ADL 25516 9. Unit or Lease Name Milne Point Unit 10. Well Number C-13 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-13 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completion flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-13 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. RECEIVED J U N 2 o 1985 Alaska 0il & Gas Cons. C0mmiss Anchorage 14. I hereby"~Td~y that the foregoing is tj~e and correct to the best of my knowledge. (k~,, ~ ~ i~. Sr. Production Engineer Signed ~:~ _ ~ _ Title The space below for Commission use Date 6-17-85 Conditions of Approval, if any: ORI~ UAL SIGNED BY LONNIE C. Approved by Approved Copy By Order of COMMISSIONER the Commission Date [OD Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp ConOco Inc. Manager of Alaskan Operations 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 May 29, 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 Monthly Report of Drilling and Workover Operations on wells No. B-7, B-8, C-9, C-il, and C-13. If you have any questions, please call Lynn Alexander at 564-7609. Very truly yours, ~Alaskan Operations LA/vv JUN$ 0 nOrage ALASKA r'"L AND GAS CONSERVATION CC'' ~.MISSION MONTHLY REPORT-.. F DRILLING AND WOI: OVER OPERATIONS · Drilling well ~ Workover operation [] [2. Name of operator 7. Permit No. CONOCO TNC, 85-6 7 '3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21328 4. Location of Well at surface 954' FSL. 2169' FEL, Section 10, T13N, R10E, UM 5. Election in fee~ (indi'~te KS, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. C No. 13 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of April ,19 85 12. Depth at ~ of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 4790' Spud 4-25-85 13. Casing or liner run and quantities of cement, results of pressur9 tests S I ZE WT GRAD E FROM TO 9 5/8" 36'# K-55 0' 4779' CEMENT 393 bbls Permafrost Type E, 51 bbls. 15.8 ppg Class G. Full returns 14. Cor~,g resume ar~l brief description NONE 15. Logs run a~d depth where run DIL 4,777'-8,265' LDT-CNL 7,500 ' -8,239 ' GR-CNL in 3,400'-4,777' casing 1 6. DST data. pe~fofating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE Anchorage 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 :5lA I i: rOt= ALASKA ALASKA "'L AND GAS CONSERVATION CC'' 'MISSION MONTHLY REPORT F DRILMNG AND WORt(OVER OPERATIONS,r 2. Name of operator 7. Permit No. , Conoco Inc. 85-67 3. Address 3201 C Street, Suite 200,Anchorage, AK 99503 4. Location of Well at surface 954' FSL, 2169' FEL, Section 10, T13N, R1OE, U.M. 5. Elevation in feet ¢ind/cate I<B, OF, etc.) 52 'KB 6. Lease Designation and Serial No. APL 47434 For the Month of. May , 19 85 8. APl Number 50- 029-21328 9. Unit or Lease Name Milne Point Unit 10. Well No. C No. 13 11. Field and Pool Kuparuk River Field Kuparuk River 12. D~th at end of month, footage drilled, fi~ing jobs, directional drilling problems, spud date, remarks Spud Date: 4-25-85 Drlg. f/4822' to 5278' , MWD failed. POOH. Changed MWD valve and' electronics. Depth at end of month: 8270' Drilled from 4780' to 8270' during this month. 13. Casi~ ~ ~n~ mn and quandtim of c~eflt, r~ults of pressure tests Ran 208 jts. of 7" csg. shoe at 8236'. Pumped 310 sAs. of 15.8 ppg Class "O" cement w/312 bbls of NaC1-NaBr @ 10.2 ppg w/full returns. 14. Coring ~es~ne and ~rLef description None 15. Lc.~js run and Cle~th where run RECEIVED CNL-FDC-DIL-GR @ 8273' to 7500'. CCL-GR-Gyro to 8100'. GR failed. Ran Dil-GR to 7443'. Reran CCL-GR from 7500' to 81~1~.a 0ii & GaS Cons, C0r~lmJssi0ri 16. DST data. p~foratJng da~a, ~ows of H2S. miscellaneous da~ ?erred 7770 - 86' (H~dd[e ~up.), 7878 - 81' 802[ - 56' (LE2) w±th 12 JS?F. and 7890 - 94' (L-8), 7904 - 10' (L-9) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 10404 Submit in duplicate Rev. 7-1-80 ADDITIO AL TAPES TO: = * CITIES SERVICE:BAKERSFIELD, CA READI G & BATES :TULSA,OK CHA~I :E GLEWOOD,CO CHEVRO USA:A CHORAGE AI~ KA O IL&GAS :A CHORAGE CO OCO:A CHORAGE CO OCO: PO CA CITY,OK COMPANY ' LOCATION' SCHLUMBERGER OFFSHORE sERVIcES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 N-o 000650, COMPUTING CENTER PRINT CENTER WELL NAME ' _~~[~-~-/_~ WELL NAME SERVICES · / -~ ,F?/~' /~/L~ SERVICES NO. OF BOXES' ~!~' NO. OF BOXES' ~o~ NO. · ~'~:~'5~ ~0~ NO.' - A~'t ~A~gS · ~'/4~'~*~ APP'g ~AegS · WELL NAME ' WELL NAME SERVICES · SERVICES NO. OF BOXES' NO. OF BOXES' JOB NO. · JOB NO. · ADD'L TAPES · ADD'L TAPES ' WELL NAME · WELL NAME · SERVICES · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER NO. OF BOXES' JOB NO. ADD'L TAPES DATE DELIVERED MEMORANOUM TO: THRU: FROM: Lonnie C. Smith Commissioner __ Doug Am~-_. Petroleum Inspector State-'of Alaska ALASKA OIL, A~.]D GAS CONSERVATION COFR~ISSION DATE: May 2, 1985 F,LE NO: D.ADA. 13 TELEPHONE NO: SUBJECT: Witness the BOPE Test at Conoco's Milne Point C-13 Well, Sec. 10, T13N,R10E,UM, Permit No. 85-67 on AUD Rig No. 3 Tuesday, April 30, 1985: I traveled this date from ARCO's Kup 1R-5 ~ell to Milne Point ~-13 well to witness the BOPE test. The testing commenced at 9:00 am and was concluded at 12:00 noon. The API ring between the HCR valve flange and the choke line flange failed during this test. It was replaced and retested. I filled out an AOGCC BOPE Inspection Report which is attached. In summary, I witnessed the BOP test at Conoco's Milne Pt. C-13 well. Attachment : : i 02-O01A(Rev. ~0179) .' ~i .- .~ · ' '- - '; .2' ' ' ; '~> - · ' ' ;" ': "ALASKA-"OIL' & GAS-'.CONS~V~TI~i B.O.P,E Inspection Report Inspector ~9~.. ~~-~ Operator Well ~/~/~ . Location: Sec '~ ':'- Drilling Contractor. Date ~-~'~ Well ~/~ ~p~ .~-/~ Representative. ~. L~~/A~ - . {~asing Set 8 $J7~ 'ft. ~epresentativ~' ~, ~~ ~ Location, General Well Sign ' . General Housekeeping Reserv~ pit '~ Rig BOPE stack Annular Preventer Pipe Rams ~ ~&~ ~-3 Blind Rams .: Choke Line Valves~ Tee t - Pres sure / ACCUMULATOR SYSTEM Full Charge Pressure ~~) psig' Pressure After Closure ,/~ psig 200 psig Above Precharge Attained: miL ~sec Full Charge Pressure Attained: ~ miL ~ sec 1~t9 I~Z)i ~/,~7~ /~/)psig /~ N2 1'~ / 1 50~/ .._ Controls: Master ~ R~ote ~ ~linas switch cover ~S Kelly and Floor Safety Valves Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP / d~-Test' Pressure / ~_~ est Pressure / ~est Pressure _ /; ~' Test Pressure H. C, R. Val~Ve //~'~' 2.. -__ Kill Line Valves~/~. ~ Check Valve / [i Choke Manifold. / Test Pressure No. Valves No. flanges Adjustable Chokes Hydrauically operated choke Test Results: Failures / Test Time ~ hrs. ":~'"'~ Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. Remarks: .~,6/~.. /~/¢~/ _~21/t/~? (~/x/ .~"- ~n-/'/~"6 ~/_./A/~:. ~ Distribution orig. - LO&GCC' cc - Operator cc - Supervisor April 23, 1985 Dan Girdler Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point C-13 Conoco Inc. Permit No. 85-67 Sur. Loc. 954' FSL, 2169' FEL, Sec. I0, T13N, R10E, Btmhole Loc. 1590' FNL, 788' FEL, Sec. 15, T13N, R10E, IR~. Dear Mr. Girdler: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted', a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Dan Girdler Milne Point Unit C-13 -2- April 23, 1985 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. V~_~t.ru l y yo~urs, C. V. Chattert~on~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMI-iISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o enct. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery John R, Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 April. 16, 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 C-13. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Don Girdler at 564-7637. Very truly yours, hn R Ke~ ions ~ Alaskan Operat JBF/vv cc: MP C-13 Correpondence File RECEIVED APR ! 8 1985 Alaska 0il & Gas Cons. Commissi0n Anchorage STATE OF ALASKA ALASK,_._)IL AND GAS CONSERVATION L~,vIMISSlON PERMIT TO DRILL 20 AAC 25.005 RECEIVED la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] 2. Name of operator Conoco Inc. Anchorage 3. Address 3201 "C" Street, Suite 200, Anchorage, AK. 99503 9. Unit or lease name Milne Point Unit 4. Location of well at surface 954' FSL~ 2169' FEL, Sec lOp T13N~ RiOE~ U.M. At top of proposed producing interval 1200' FNL~ IO00'FEL~ Sec 157 T13N,R10E, U.M. At total depth 1590' FNL, 788' FEL, Sec 15, T13N, R10E~ U.M. 5. Elevation in feet (indicate KB, DF etc.) RF~ 52' Pad 17' I 6. Lease designation and serial no. ADL 25516 10. Well number C No. 13 11. Field and pool :Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000.00 13. Distance and direction from nearest town 33 mi NW of Deadhorse miles 16. Proposed depth (MD & TVD) '8,400 ' MI) 7438 ' TVD feet 14. Distance to nearest property or lease line 3254' @ Surf feet 17. Number of acres in lease 1,280 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3050 feet. 21 20. Anticipated pressures MAXIMUM HOLE ANGLE 39oo (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed well C-11 120 feet 18. Approximate spud date 4/23/85 3230 psig@ ;dO~'? Surface 3800 psig@ 7,372 ft. TD (TVD) SIZE Hole 17½" 12~4,, 8½" Casing 13 3/8" Weight 48 9 5/8" 36 7" 26 L-80 22. Describe proposed program: CASING AND LINER Grade I couplingI Length MD SETTING DEPTH TOP TVD 80' 35' I 35' 4715' 33' I 33' I 8368' 32' ~ 32' I MD BOTTOM TVD 115' I 115' 4748' I 4600' 8400' 7438' QUANTITY OF CEMENT (include stage data) ±100 cf ±2300 cf CMT ±250 cf CM~ Conoco Inc. proposes drilling the subject well as a water injection well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.~ ppg. Mud weight at T.D. will be 10.2 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. 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 C No. 11 which is 120' northwest of C-13 on the surface. Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing to test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. * This depth may be exceeded if formation is deeper or wellbore does not follow proposed path. A Sundry Notice will be submitted if total depth exceeds permitted depth by over 300' 23. I hereby c/erJify that the foregoing is true and correct to the best of my knowledge SIGNEDk'" ~%~ ~ ~ k)k~.~ TITLE Pr°ducti°n Engineer The space below~for Co~-mission-~u~e -- - DATE April 11, 1985 CONDITIONS OF APPROVAL , Samples required ' Mud Iogrequired I Directional Survey required I APl number [-]YES J~rN O Permit number Approval date ' ' ~- ~ 0~/2~/85~ I SEECOVER LETTER FOR OTHER REQUIREMENTS 2'/' / // ,, APP.OMEDBY / /?//////_~ ~ .COMMISSIONER DATE A..~I '3. 1985 ~ ~ *'/ :'L f ~/W'~/i¢~''~ by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL RECEIVED Conoco et al - Milne Point No. C-13 APR I 8 1 85 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, Alaska 99503 Alaska Oil & Gas Cons. Commission Anchorage I. CEMENTING PROGRAM Ae The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B~ The 9-5/8" surface casing wi].], be cemented with ±1120 sacks of Permafrost "E" cement followed by ±250 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C~ The 7" production casing will be cemented in two stages. The first stage will consist of ±310 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. Il. ANTICIPATED GEOLOGY O' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6600' subsea TVD. III. FORMATION EVALUATION Ae Wireline logs for the 8~" hole (from T.D. to ±1000'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. iV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. A /.ow solids non-dispersed ge]./water mud system will be used from 1000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 4748'-T.D. DIRECTIONAL PROGRAM The C-13 well will be drilled to a proposed KOP of 3050', then build angle in a south 28.5° east direction. The closest that the C-13 will come to another wellbore is from surface to 1350' where the proposed C-13 will be 120' southeast of the existing C-Il well. An MWD tool is to be run while drilling for surveying purposes. Proposed hole angle is 39°. RECEIVED blORIZ.ON T AL_~OJEGZiO~ SC LE 1i IN. 100 FEE i .... ' ' t -· I : 1 CONOCO. INC. , ~ , - - ~. ·., .... pAD C. gELL N0~13 REVISED PROPOSAL; . HILNE PT..;NORTH SLOPE. ALASKA i .... ~ASTMAN WHIPSTOCK. I~C;~:~:-- .... ~.. . , . ' . . ~ ' . - t. 'SURFACE :954' FSL; 2169~ FELL-: ...... SEp. I0. ,:TIaN. RIOI:'_ ~ )"6890 .... f '' ' ..... i ........ TI1D-7694 · ! .... · iL i . :AF~R:i-. 8 ZED L985 - i ON I ...... 1200' FN~. I000' FEL , '' SEC. 15. T13N. R IOE · . ;iiPAD C, WELL N., 13'.REVISED'PROPOSAL" ..... ~ILN~ PT.;' NO~T..H SLOF..~.i ALASKA ........ .............................~:,~:;,' ~'":;s.,:;,~',~.,,c::: ...... :-'I ..... :: .... - i .......... I t i. ........... Per ~ooe:.r .-i ....~--- I · . . .......... . , i, ....t-'.._ ~ "._ .L I £0C ..... TVD._--4492..._T_M..D=4609_.DEP_=.510 - t . , ' 9 5/8." CSO~P1.,!VD=4600 .9 DE~=598 i .. ~ .......... i .... ~ .... - .. :-:--:.--~---' · -i-~- ! .i . . . .... ,-~ ....... . . '" ....... ', .... ' "- -' ........ ' ....... ' ERA - . . , ......... ] .......... :.:.-.,,38 BEG 58-MI -'-' .... t :'::-- - .... i ....... i .... i .......... i ...' ~ ·--i .... i-.. ' ' '--,i.I ..... i ....... ~ ...................... .... I ..... - ....! ........ ~ ......... '.- ~ ..... ~-- ~ ...... ~ .... : .... t ...... ! ....... i .... ~' i ~'-: --- ,..!..-~---.~ .... + .....+, ...... . . ,: ~ ~ ~ ...... · , : ~ ~- t - -. ' '' '11 .......... ~ ! ~ - ~- - ! .... I-- .. I ........ ~ ..... TARGET TVD=6B90 TMD=7694 DEP.=245 I · ' ' ' ' ' _.KUPARUK)._~__~_ __ ~ __. i , · ; , ~ I - · , , -.'' ':.!''' .......... l~..,~ .... ....... ,-~ .FOP LOUER KUP, TVD=?060, TMD=791i3_:.: . . .DEP=2581~: .... .. ..-; . ~ ............ !-- ~. 'TENTATIVE' TD TVD=7459 TMD=B400 DEP=2895 ...... ~- ..... ---~-i- .... ~ ..... ~- .... i i ; ..... ''''~ ....... t ''' ~ ~ ................. ~i _. i --i ...... , ,-.:... .;i.,i...';'...'l .... -'' ''''' tt .... ~:~ '~"'-''' 'J '' ' i. ,--i ....................................... ! ..... i.- ~ ............. t .... t ................... ~ ' ,~' 2~,~"~ ..... t - ! .... : *-' ~ ..... t .... i ..... i · ~ .... , - · · i ~ / i ........ i ~ i,. ...... i ........ 1, ,i . . . { . '! . ....... . " l, .-i . , ..... , ........ t , ., .... , /.i '. .... t I- -- znn i---i---[ · ! I i. I/ ! .'-i ''! i -'! ~'~'~-~ '-: - ~ ...... ' ---- .... ~-=' -:- i ..... ~~ ' : ~ - - ~ : : : ' ' ' ~ ": : ~ - i.: :~':-::i::::~-~ .i. t-~ I:::/'"~ ~.'~ :':::~i.:::~..:i:::.~.:::i~,'_:::f' ..... ~ .... i ~ - .i-../~~ ...... , ..... r .... I ........... ~]/' ..... ~ - 0 ........... ~ ·t .' T ,,~' ~~ . :'iS_ ', ~~2 ~t ...... ~'' ' .... '' ' ' ~ ''I 30 i :..L: : :: : ....... ' ' ' ~-:'~-, ' I ...... ~ .............. I ' ' - , ........ , '' - ~ ' ' ' ' ' ~ '~ .... : ........... I ...... [ .... 200" '~ I ........ :-::: :.: ::-: ::::i.::A-.~'::: ...:~': ~ ~,-:-~ ::- . -::-: :.: :- ::.' ; - -::::-::-: ;:-:: i : ::' :-: :-:-i: i .... :-. ~ · - - i -~h~ i · - i ........ i ..... 1 ..... : ...... ~ ..... ] - ~. ::: ::. i: :~!'-::-:::'i / ~7~o - ~ ~~ ::~. ~-~. ~L-L: ~ ,,,J:-::: i::-::::-: -:::- - ..~ ....... { I . -i ~ ' 't 1 ' I ~_oo' .. :-':i:-:::-:':' :_.i_.~~~aL~:.-,~~b, .... ~~R~OS~:;:: _"__:~ '. ...... ~ .......... ~' ~ i ~' ':"~ HILNE'PT~, NORTH SLOPE, - :::-: :-;--:-. ; ' ' · ' ............... ,'- ' h' 'D: ........ ' ' :'- ~ , ........ , ...... , ..................... ,..:-,.-..,, ........ ,.. .... __, ... { .......... Lo.m%'?*~ ~ ~ :.':::: ::_'~'::.. : :'":.': ~ :~"::~:: '_~ :':~:;'':::': : :~'~:"~" ::: ~-':, ~"-:: ,,-' :",~,. -. ........ ; ........... ~.-? ....... :.~ ......... ~ ........ ; ...... i -~ ......... --~ ................. ~-~-:-:: :.;--~--'5 .................. 4 - ! .................................. ~ "~--t .......... ~ ......... ~ ..... ~'~ ........... I--:-~ .... i-~ ...... ~ ..... ~ ~ .... ~-~:'-~- _MLJ ....... t ...... ~ :. , ~1~¢~ rill :g ~. : ............. I ...................... , .... ~ .... ~ ................... .:~ - I ' ' ' ~ ' ~- : ........ ~ ....... : ......... ~ ........... : .... ,.~ ...~ - . ~_.: .... . ..i ......... ~ .... : .... ~ ............ ~ ........... '~ i ' '~ .... ~ t ..... I ....... : ..... J ...... ; ...... ~.L ...... ' .: . .~. ::': ::.::.:,.. :.:: :.. ~..:-. :'., ::- ~ .~: ~ ..-: ....... ...................... A ..... . ~ '. ~ .... ~ ......... ~ .... Ni~-~~~ -., ~ ....... ~-- - :, - ~ :.- - i- ~ ,6~ ...... ~-- ~ - i .... ~ -i.-.: .... ,. · i ' J d · · ~ i~ ' · ' I PO0 ' ~ ':.. _~.~ ' ! .%~ ' ~ ' '~ _ ~x-: L.-: ~, ' ,',' : -., -.~ -.' .-.t ..... % . ~ . .i - ~ -~'..~ ........ ~ .... ~ .... {- - ~ I ~ - - - ~ ~ . - - { · ~ ....... ~ : ~ : ~ . ~ .~ .... ~...:.:-~..~_. ~ , CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK RECEIVED APR i 8 i985 Alaska Oil & Gas Cons. Commissio. Anchorage ~ ~ Flow Line Fill-up Line ~ _ iq0'' 2000 psih ! Annular ~.~Preventer * _ ~'~ Drill~ing [ m ~ * Relief Line [ ~) Spool (2 I1~11 ~ 6" Relief Valve 12o" x 20" I 2000 p~ ! [, ~. Connect Assembly Saver Sub ~''! ~~' Assembly 1~1 ,"! j-'Starting' ''l ~ J I.',. -,! I I.-' 1. Relief lines.from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 Fill-up Line~Fl°w Line CONOCO INC. MILNE POINT UNIT BOP STACK RECEIYED Alaska (1) B.O.?. stack size ra~in~ meets A~I ~ 53 & spec 6A for class 5N ~ith clamp & hub connectors all hydraulically operated. (2) BO?~ to be operated on each trip & pressure tested ~eekly. (3) Hydraulic control system for BO?~ to include (5) station control ~nifold located remote ~ith 160 gallon accumulator a~d 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 3" - 5000 Side Outlets 2" - 5000 Side Outlets 3" - 5000 Side Outlets' RAM 13 5/8"- 5000 11"- 5000 7-°'. ALASKA. UNITED RIG NO. 3 DRILLING CHOKE MANIFOLD: LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6"x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type Choke (2) Type 10,000 psi w/ (2) Manual (1) Automatic CAPACITIES ACTIVE SYSTEM I Sand trap 6 I Degasser tank 56 bbl I Desander suction 54 bbl I Desilter suction 55 bbl I Desllter discharge 66 SUBTOTAL Mud Tank No. I I Common 2 Suction Mud Tank No. 2 Recelvlng Discharge Mud Tank NO, 3 SUBTOTAL ACTIVE SYSTEM TOTAL TRIP TANK SURFACE VOLUME GRAND TOTAL ICalculated 4." below tank topi 237 bbl 38 bbl 122 bbl 184 bbl 184 bbl 240 bbl 768 bbl 1005 bbl 150 bbl I 155 bbl (2) HCR valves ALASKA UNITED RIG NO. DRILLING 3 BUTTERFLY., VALVE CLOSED DESANDER SUCTION CLOSED I%WiV£L ~o,~ Flow path Solids removal DEGASSING FLOW PATH Flowline lin~ & pass shaker screens Shaker discharge into sand trap (ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed) Degasser discharge into ditch Overflow returns to degasser suction (underflow butterfly closed) Switch desander suction out of degasser tank Desilter suction (Normal) Cleaned mud to treatment pit Underflow from treatment to suction pit Gravity-flooded suction Company ~ Lease & Well No. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee f!~ !(-1ð-g,: 1. (2) Loc 2~~r 2. 2 thru 8) 3. 4. 5. 6. 7. 8. j/JII 1j;S/ SF (8) I (3) Admin t'^- «~I~t.' thru 12) JlJII VIi/if (10 and 1 ) f (4) Casg /lJII ~Jfl!S" '(13thru I)' W.' (5) BOl'E tfZ~hJ!f!{ (6) Add: //7/1 ~j¡~ß~ " H"~,.,.."~e,."o,...,l",',,,,,O,.",..g'"..,Y"..':',.',L,".',c,."~"~~,,i ..........,~,...~~;S~ WV ", MTM~HJH'ïlfL JAL,/' " " I rev: ' 0 3/13/ ~5 6.011 YES NO Is the permit fée attached ..........................................~~--- Is well to be located in a defined' pool. . . . . . . . . . . . . . . . . . . . . . . . . . . . .~ " f Is well located proper distance from property line................ ./4.- Is well located proper distance from other wells .................... ' Is sufficient undedicated acreage available in this pool............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party................................. Can permit be approved before ten-day wait .......................... 9. 10. 11. 12. Does operator have a bond in force ..................................¿J~ Is a conservat ion order needed......................................~ ¡¡¡[If ' Is administrative approval needed ................................... j1~ Is the lease number appropriate ..................................... flJ'/I - 1'111 ú.t-/] REMARKS 13. 14. 15. 16. 17. 18. 19. 20. 21. ( Is conductor string provided......................................... JIi!lL Is enough cement used to circulate on conductor and surface. ò . . . . . .. ¡J¡r!l Will cement tie in surface and intermediate or production strings,... 1Iffli:... Will Cement cover all known p:roductive-horizons ......".............. Ifd')/ Will surface casing protect fresh water zones ....................... 1l!1l.i. Will all casing give adequate safety in collapse J tension and burst.. Jlál! Is this well to be kicked off from an existingwellbore ............. - 1llll Is old wellbore abandónmentprocedure included on 10-403 ............ - - /11,11. Is adequate wellbore separationproposed............. ....... .... . .. . . /1¡[11 - .s~EEEL..t)f,U . t; 0 1-3 ~z HO 001-3 ~~ :>H 01-3 t%jt%j INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE f fO¡ <)/~ ~~. I WltJ] C, ð II JJ ~g oN 22. 23. 24. 25. 26. Is¿ldtverfèrsY'stemreqtîlred......o. . .. ,'.. ... .0. .......... ....¡.. "1Iil1L Are.necessary dia~rams of diverter and BOP equipment attached ....... j Does BOPEhavesufficient pressure rating -Test to ,.!t; ()7){;) . . psig .. . ',IJJ Does the choke m¡mifold. comply w{API RP-53()'~b .}8) . . . . . . . . . . . ., . . . .. flY Is the presence of H2Sgas probable. ....,.. . ..... ..... . ........ .,.. ... .... 27. Additional requirements ..... ò . " . . . . . . .. . . . . . .. ... . . . . ... . .. . . ... . . . . - ¡lff1 H Z -~ ~_._."_.....,...,",,,-,,~.,~.... ''',","''.''''''-''''~'., -~- _ÇIL~1sk.1':1I7NLE.e/-DDI/T6f(hM I S IN ßDðrYtj¡¡..rÆ. Jb¡j., ,', " " / Additional Remarks: W(LL ç- r? l{)/LL f?£ l.9-ðl FÆð/jC-!l F/?1>I1 sIlN/f.(}.E j-¿> /J0Ó /VD. r¡!£/(£ MIl-). ßJ: .M> b ,rIlER,t{)éJ.l.l?t>R.ES 'LI} //J/I¡fj~ðZ)/~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LVP 010,M02 VE~I. FI'.CATION L:I$TING PAGE I · ~ REEL HEADER ~ SERVICE MA~E :EDIT DAT~ :95/05/~0 OR~GIN : CONTINUATION ~ :01 SE;RVTC~ NA~E :EDIT' DATE: :'~5/05/~0 OR~GTN :0000 TAPE NAN~ , :0403 CONTINUATION ~ 101 PREVIOi~S TAPM : ~O~M~Nm6 : ** FIL~ HEAD~P ** FILE NAi~ :~DIT .001 SERVICE NA~E VERSION ~ : OATE : MA×IMU~ LENGTH : 1024 ?IbETYPE PR~VIOU6 F~ ** INFORMATION RECt!RD$ ** ~N~N OOMTEN'"$ CI~ : COwOCO AI,ASKA WN : ~PU C-13 · N : WUPARU~ RlVgR RANG: 10w TOWN: 13M SECT: l0 COUNt w,sbnp? STAT: AG~SWA CTPY: ~iSa ** COMMENTS ** UNIT TYPE CATE SIZE CODE 000 000 01,3 065 000 000 008 065 000 000 01.3 065 000 000 003 065 000 000 003 065 000 000 O02 065 000 000 007 0~5 000 000 OOb 065 000 000 003 065 UNIT TYP£ CAWE SiZE CODE 000 on0 001 065 LVP 010.H0?.. VEt:~iF'ICATION LISTING PAGE 2 * ALASKA COMPlj'TIMG CMNTE~"4 , ************************************************************************************** COmPaNY = C~NOCO INC. FIELD = KUPARUK .~,p,. . COIINTY '"-NORTH 8[,,[3, E, ~OROi3G, H JOB ~'U'~'BEJ~, A.'r' ~CCI~ 70403 RUN. ffONE, DATE LQG.,ED: 06 LOP: CASIM~ - 9,625 ~ .~, ~, BIT SiZE : 8,5" TU 8270' TYPE~LUID : SYN~RX/ST.AFW DENSITY = 10,4 bB/G RM = 2,260 0 69,0 DF VISCOSITY = 4~..0 S RAM = 2,030 (~ 6~,0 DF PM = 9,0 RM.C = 1,730 ~ 6~.0 DF FLUID LOSS = 4.0 C3 R,M AT BH, T : 1.122 0 1,~,,6.0 DF WATRIX S ANDSTO'~E ***** TH~8 [)AT~, HAS M[]T BEEN DEPTH. SHIFT~D - OVERLAYs..'"' 's FIELD PRINTS ***** ********************************************************************************** hVP 01,0,~:{02 VERiFICAq, ION LISTI~]G PAGE 3 ~ SCMI~UMBE~GF...R LOGS INCLUDED {~ITH THIS * DATA A~AILABLE: T~ 4777~.0' TO 8265,0' * !)AT~ .~V.~iLABBE: 7500 O' TO ~239,0' * * DATa ~VRILABbM: 3400,0' TO 4777,0' * , * , , * ~ , , $ , , $ * , * , , , , , , , * * , * , , , , ~ , ** DAT~ FO~M~T RECORD *~ ENTRY BLOCFS TYPE SIZE ~EPR CODE ENTRY 2 1 66 0 4 1 66 ~ 8 4 73 60 9 4 65 ,lin ~6 ! 66 1 0 1 66 0 OA, TU~ SPEC%F!CATION BUOCK$ ~NE~! S~RvICE SMRVICE !INIT AP1 API APl h, PI FILE SIZE SDL REPR PROCMSS I~ ORDER ~ bOG TYPE CLASS ~OD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 ~, i 68 00000000000000 SFLU DiL OH~M O0 220 Ol 0 0 4. ! 68 00000000000000 TLD DIL OH~ 00 ]20 46 0 0 ~ 1 68 00000o00000000 Ih~ DII, ~H~M O0 ~20 4.4 0 0 4 1 68 00000000000000 SP nit, ~¥ O0 010 O1 0 0 4 1 68 00000000000000 LVP OIO,H'O~ VEPIFICATIf)N LISTING PAGE GR DIL GgDI 00 GR LDT GAPI O0 CALl [,DT TN O0 RHOB LDT ~I~3 00 OR~O L[)T ~/C~ O0 NRAT LDT O0 ~P~I LDT PU O0 PEF LDT O0 NCNL LDT CPS O0 ~CNb t,t')T CPS O0 ~RAT CNL O0 NPHI CNL PU O0 ~R CNL ~API O0 10 10 80 50 56 20 O0 90 58 30 3O 20 90 10 DATA, ** DEPT SP RHOB NPHI 8,~65ioooo S~I.,[ 28 531,3 ~R 999 ,,9,, 500 DRHO -999, .?.500 DEF -099,2500 t,!PHI 2 108 -999 -990 -999 OEPT SP RHOB ~RAT 8000 0000 SFLU ~ 34 DR,HO 30, ~105 PEP' -099. 2500 1,2 58 0 -999 DEPT SP 7000 0000 SFI~U -24:~031 GR -999,P500 DRHO -999o~500 DEF -099.~500 MPHI 211 -999 -99~ SP gPHI NRfiT 95. 999. :090. -q9g. DEPT SP RHOB NPHI MRAT 5000.0000 SFLi] -60.~1~7 GR :090,2500 DRHO 099.~500 PEF -999.2500 MPHi 1 86 -999 -~99 -990 DEPT SP RHOB NPH! MR~T 4no0.o000 SFLU -990.~500 -999,7500 DRHP -990.2500 ~.~4~6 ~PHI -ago. -999. -~9~. 44. 2207 8125 2500 2500 2500 7969 8750 3 '2,,500 4,434 5000 25OO 2500 2500 7188 3750 2500 25O0 2500 49O2 31~5 2500 2500 2500 ~500 2500 2500 2500 5801 Ol 01. O1 02 O1 O1 O0 O0 O1 3i 3O O1 00 Ol GR ,~) R ,~, T NCNL nR GR NRAT NCNb ~R GR ~RAT NCNb NRAT CR ~R MRAT TLD D'RAT I~;CNL , -099, '999, -999, -999, 3362 -999 . 1, '999. '999. -099. -999. 2~ -999, -999, -999, -999, -999, -999, -999, -99~. -999, -099. -q9g. 59. 3984 2500 25OO 2500 2500 7188 '8750 8164 0000 2500 905,3 2500 2500 2500 2500 5938 2500 2500 2500 2500 4297 2500 2500 2500 2500 25O0 2500 ~500 2500 75O0 I 68 00000000000000 68 00000000000000 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1. 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 O00OO000000000 I 68 00000000000000 1 68 00000000000000 IbM CALl RNRA 3.3398 -999,2500 -,999,2500 999,2500 I,b~ CALI RNRA 17',77~69 8. 56 2,099~2 1.23, 000 Ib~ CALI RNRA FCNL 1 ~389 -999:.500 -999,2500 -999,~500 Tb~ CALl RNDA FCNL 2,6035 -099.2500 '999.2500 -999,2500 CAI, i RNRA F'CNL, 2 3945 -999:2500 -999,2500 -999.2500 CAI, I FCNb -999.2500 -099 2500 -099:25O0 -999,2500 i,,,VP OlO,H02 VE~IFICATi~)N b!$TI' :~C, PA~'~,E RHDB NPHI NRAT 3400 0000 SFLU -999 2500 ~R -qgq ~500 DRHO -999 ~500 PEF 4 5508 NPHI -99g ,2500 II, D -999 2500 GR -,~99 ~500 NEAT -999 2500 NCNL 57 3730 GR SERVICE ~A~E VERSIO~ ~ : DATE : ~AXiMUM LENGTH : 1024, NEXT FiLF ********** EOF ** TAPF TRAILER,** SERVICE NA~E :EDIT DATE :85/05/~0 ORIGIN :0000 TAPE NAM~ :0403 CONTINUATION # :01 NEXT TA, PF MA~E : CO~M~N~$ : ** REEL TR~I. bER ** SERVICE NA~E :EDIT DATE :85/05/30 OR'~GIN : REEb NAMF : CONTIN~!ATION ~ :01 NEXT CU~MFNTS : -099.2500 IbM -999.~500 CALl' -999,2500 RNRA 49,6875 -999,2500 -999,2500 -999,2500 -~99,2500
