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Home My WebLink About179-104Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:179-104 6.50-029-20422-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11029 10870 9449 9107, 9284 Unknown None 8041, 8183 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 38 - 118 38 - 118 Surface 2632 13-3/8" 37 - 2669 37 - 2669 5380 2670 Intermediate 9810 9-5/8" 35 - 9845 35 - 8642 6870 / 8150 4760 / 5080 Production Perforation Depth: Measured depth: 10026 - 10305 feet True vertical depth:8791 - 9015 feet Tubing (size, grade, measured and true vertical depth)33 - 9400 33 - 8277 9107 8041Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 1666 7" 9361 - 11027 8246 - 9573 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2.5-gallons WellLock pumped at 2500-psi. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 24816073092118379 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Oliver Sternicki Oliver.Sternicki@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4891 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9574 Sundry Number or N/A if C.O. Exempt: 4-1/2" Baker SAB Packer 9284 8183 Junk Packer Printed and Electronic Fracture Stimulation Data 5 OA Squeeze Operations shutdown Change Approved Program 5 OA at surface Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028313 PBU X-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 4-1/2" 12.6# x 4-1/2" 12.75# 13cr80 / L80 None 143 368 3692 1626 260 By Samantha Carlisle at 9:35 am, Oct 13, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.13 09:13:39 -08'00' Stan Golis (880) SFD 10/13/2021RBDMS HEW 10/13/2021 MGR15OCT2021 DSR-10/13/21 ACTIVITY DATE SUMMARY 8/29/2021 T/I/O = 230/1820/1010. Temp = 130°. Bleed OAP to 0 psi, hold open bleed (eval IAxOA). ALP = 1820 psi, AL online. OA cemented to surface. Bled OAP to 0+ psi in 1 min, gas. Held open bleed on OA for 3.5 hrs. Monitor for 30 min. During monitor OAP increased 140 psi. Bled to 0 psi prior to departure. Final WHPs = 230/1820/0+. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:30 8/31/2021 T/I/O = SSV/1680/1420. Temp = SI. Bleed IAP & OAP to 0 psi (pre wellock). ALP = 1920 psi, AL SI @ casing valve. IA FL @ 7996' (sta #2, SO). OA cemented to surface. Bled IAP to OT tank from 1680 psi to 0+ psi in 8.5 hrs, gas. Bled OAP to bucket from 1420 psi to 0+ psi in 1 min, held open bleed on OA throughout IA bleed. Removed OA gate valve & blind flange. Installed 3" integrals on both sides of OA for up coming Wellock. Final WHPs = SSV/0+250. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:15 9/1/2021 T/I/O = SSV/0+/600. Temp = SI. Wellock OA (Mitigate high OAP). ALP = 1890 psi, SI @ CV and lateral. Pumped ~2.5 gal Wellock into OA by pumping into the 3 and 9 o'clock integrals simultaneously for 6 hrs at 2500 psi. Final WHPs = SSV/0+/2430. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 9/2/2021 T/I/O = SSV/0+/1660. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater working. Sample not set up. SH temp = 70*. Installed gas accumulators on both OA ports. OAP now 1780 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 9/3/2021 T/I/O = SSV/0+/1620. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater working properly. Sample of Wellock looks like it is starting to set up. It has the consistency of syrup. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 9/3/2021 T/I/O = SSV/0+/1450. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater working properly. SH temp = 102°. Adjusted heater trunk a little further away from wellhead. Sample remains the consistency of syrup. SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:15 9/4/2021 T/I/O = SSV/0+/1320. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater working. SH temp = 90°. Adjusted heater trunk a little further from wellhead. Wellock sample is not set up. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40 9/6/2021 T/I/O = SSV/0+/1230. Temp = SI. WHPs (Post Wellock). ALP = 1920 psi, SI @ CV. Heater working. SH temp = 84°. Wellock sample is firm, but not set up. OAP = 1230 psi at the 9 o'clock side, and 980 psi at the 3 o'clock side. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:45 9/6/2021 T/I/O = SSV/0+/1200. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater is working properly. SH temp = 80°. Wellock is setting up and is now the consistency of peanut butter. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:45 9/8/2021 T/I/O = SSV/0+/1120. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater is working properly. SH temp = 75°. Wellock sample in the wellhouse is hard but tacky. Sample in the office is the consistency of peanut butter. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 Daily Report of Well Operations PBU X-05 Daily Report of Well Operations PBU X-05 9/9/2021 T/I/O = SSV/0+/1120. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater is working properly. SH temp = 76°. Wellock sample in the wellhouse is hard and no longer tacky. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 9/10/2021 T/I/O = SSV/0+/760. Temp = SI. WHPs (Post Wellock). ALP = 1930 psi, SI @ CV. Heater is working properly. SH temp = 82°. Wellock sample in the wellhouse is hard and no longer tacky. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 9/10/2021 T/I/O = SSV/0+/720. Temp = SI. RD hoses (post wellock). AL SI @ casing valve (1930 psi). Heater is working. Casing temp = 92*. Wellock sample is set up. Rigged down hoses and jewelry from wellock job. Re - installed Ops OA gauge. OA casing valve and blind flange need to be re-installed. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40 9/15/2021 RD intergal flange from Working and Companion OA, Installed gate valve to Working OA, Installed blind flange to Companion OA. Torqued all flanges to Spec. RDMO From:Roby, David S (CED) To:Carlisle, Samantha J (CED) Subject:FW: Sundry application for retroactive approval of work done on X-05 Date:Tuesday, October 12, 2021 11:21:40 AM In case you need this for the files. Dave Roby (907)793-1232 From: Roby, David S (CED) Sent: Tuesday, October 12, 2021 11:21 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Stephen F Davies <steve.davies@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov> Subject: Sundry application for retroactive approval of work done on X-05 Oliver, We’ve discussed this more internally and with the Commissioners and have decided we’re going to reject the sundry application since there’s no reason to approve something after the work has already been done (unless it’s a case where a verbal approval was granted and is being followed up by a 403 application as required by the regs, which isn’t the case here). We are going to require you to submit a Sundry Report (Form 10-404) for the work done on this well. In the Sundry Number box where you’d normally put the approved sundry number(s) or N/A if the work was authorized by the sundry waiver matrix please put “NONE”. Let me know if you have any questions. Regards, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 RBDMS HEW 10/13/2021 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:179-104 6.API Number:50-029-20422-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028313 Property Designation (Lease Number): 10. 341H 8. PBU X-05 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown OA Squeeze Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11029 Effective Depth MD: 13cr80 / L80 11. Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required? Subsequent Form Required: Approved by: COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker SAB Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9574 Effective Depth TVD:Plugs (MD): Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9107, 8041 9284, 8183 Date: Liner 1666 7"9361 - 11027 8246 - 9573 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 2669 37 - 2669 14. Estimated Date for Commencing Operations: BOP Sketch 38 - 118 Structural 6870 / 8150 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S3 Packer 10026 - 10305 8791 - 9015 4-1/2" 12.6# x 4-1/2" 12.75#33 - 9400 Production 10870 9449 None Unknown 38 - 118 13-3/8" 9-5/8" Contact Phone:907.564.4763 Date: 4760 / 5080 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2632 5380 Intermediate 9810 35 - 9845 35 - 8642 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. No SSSV Installed No SSSV Installed 9/1/21 (retroactive approval) By Meredith Guhl at 2:10 pm, Sep 15, 2021 321-474 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.15 07:06:44 -08'00' Stan Golis (880) DLB 09/15/2021 10-404X 9/1/21 (retroactive approval) MGR20SEP2021 cepption Requireed?Subsequeent Formrm RYesNNo y:y:COMMIISSIONNER njecction MIT Reqeq'd?Yes NNo Xxception Required? Subsequent Form R by: COMMISSIONER I xception Required?sequent Form R by:MISSIONER I Well Program Sundry Well: X-05 Well Name:X-05 API Number:50-029-20422-00 Current Status:Under Evaluation; Flowing PAL Rig:DHD Estimated Start Date: 2021 Estimated Duration:2 weeks Reg.Approval Req’std? Yes Date Reg. Approval Rec’vd: First Call Engineer:Aras Worthington 907-440-7692 Second Call Engineer: Wyatt Rivard 907-777-8547 Current Bottom Hole Pressure:Est. 3350 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2470 psi Max Inc:See Schematic Integrity Issues:OA re-pressurization when SI Brief Well Summary X-05 is an Ivishak gas-lifted producer that has a history of OA re-pressurization. The OA was fully cemented via RWO in 2009. Since then, the OA has been Well-Lock treated three times to mitigate OA re-pressurization. The OA behaves well when online but during shut-downs it re- pressurizes. An MIT-IA passed to 2500 psi on 07/04/2015 verifying PC, tubing, and packer integrity. A PPPOT-IC passed to 3500 psi on 05/14/2018 verifying casing-packoff integrity. Objective Squeeze OA with Well Lock (or similar) to mitigate intermittent OA re-pressurization. Procedural Steps DHD/Special projects 1. ND OA Gate Valve, NU OA Integral. 2. Well Lock (or similar) squeeze on OA to 2500 psi. 3. Monitor OA for re-pressurization. 4. Re-treat OA if necessary. 5. ND OA Integral, NU OA Gate Valve. Sept -00 DLB Well Program Sundry Well: X-05 Date: 04/30/2021 Hilcorp North Slope LLC 1 Guhl, Meredith D (CED) From:Abbie Barker <Abbie.Barker@hilcorp.com> Sent:Friday, July 23, 2021 1:10 PM To:AOGCC Permitting (CED sponsored) Cc:Stan Golis; Aras Worthington; Wyatt Rivard Subject:Cancellation: PBU X-05 (PTD #179-104) Sundry #321-226 Attachments:Sundry_321-226_051421.pdf Good Afternoon, Hilcorp North Slope will not be executing the work covered by Sundry #321‐226 (attached for reference). Please cancel this sundry. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564‐4915 Cell: (907)351‐2459 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. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:179-104 6.API Number:50-029-20422-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028313 Property Designation (Lease Number): 10. 341H 8. PBU X-05 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown OA Squeeze Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11029 Effective Depth MD: 13cr80 / L80 11. 5/17/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required? Subsequent Form Required: Approved by: COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker SAB Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9574 Effective Depth TVD:Plugs (MD): Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9107, 8041 9284, 8183 Date: Liner 1666 7"9361 - 11027 8246 - 9573 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 2669 37 - 2669 14. Estimated Date for Commencing Operations: BOP Sketch 38 - 118 Structural 6870 / 8150 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S3 Packer 10026 - 10305 8791 - 9015 4-1/2" 12.6# x 4-1/2" 12.75#33 - 9400 Production 10870 9449 None Unknown 38 - 118 13-3/8" 9-5/8" Contact Phone:907.564.4763 Date: 4760 / 5080 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2632 5380 Intermediate 9810 35 - 9845 35 - 8642 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. No SSSV Installed No SSSV Installed By Meredith Guhl at 8:33 am, May 04, 2021 321-226 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.03 16:40:16 -08'00' Stan Golis (880) DLB05/04/2021 SDR-5/4/21 X MGR14MAY21 10-404 dts 5/14/2021 JLC 5/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 10:50:43 -08'00' Withdrawn by Operator 7/23/2021 Well Program Sundry Well: X-05 Date: 04/30/2021 Well Name:X-05 API Number:50-029-20422-00 Current Status:Under Evaluation; Flowing PAL Rig:DHD Estimated Start Date: May 2021 Estimated Duration:2 weeks Reg.Approval Req’std? Yes Date Reg. Approval Rec’vd: First Call Engineer:Aras Worthington 907-440-7692 Second Call Engineer: Wyatt Rivard 907-777-8547 Current Bottom Hole Pressure:Est. 3350 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2470 psi Max Inc:See Schematic Integrity Issues:OA re-pressurization when SI Brief Well Summary X-05 is an Ivishak gas-lifted producer that has a history of OA re-pressurization. The OA was fully cemented via RWO in 2009. Since then, the OA has been Well-Lock treated three times to mitigate OA re-pressurization. The OA behaves well when online but during shut-downs it re- pressurizes. An MIT-IA passed to 2500 psi on 07/04/2015 verifying PC, tubing, and packer integrity. A PPPOT-IC passed to 3500 psi on 05/14/2018 verifying casing-packoff integrity. Objective Squeeze OA with Well Lock (or similar) to mitigate intermittent OA re-pressurization. Procedural Steps DHD/Special projects 1. ND OA Gate Valve, NU OA Integral. 2. Well Lock (or similar) squeeze on OA to 2500 psi. 3. Monitor OA for re-pressurization. 4. Re-treat OA if necessary. 5. ND OA Integral, NU OA Gate Valve. Well Program Sundry Well: X-05 Date: 04/30/2021 Hilcorp North Slope LLC STATE OF ALASKA ��, r,*77 F1, Fes' s`°e1 ALASKA OIL AND GAS CONSERVATION COMMISSION a � t . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed JA/ A QQ ;;Ip77f ��jj Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shufdogly120 ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Cham ❑ Plug for Redrill [I Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ 0thr: u eze 0 2. Operator Name: BP Exploration (Alaska), Inc 14. Well Class Before Work Development 10 Exploratory ❑ 5. Permit to Drill Number. 179-104 3. Address: P.O. Box 196612 Anchorage, AK99519-6612 Stretigraphic ❑ Service ❑ 6API Number: 50-029-20422-00-00 7 Property Designation (Lease Number): ADL 028313 S. Well Name and Number: PBU X-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 11029 feet Plugs measured None feet true vertical 9574 feet Junk measured 10297 feet Effective Depth: measured 10870 feet Packer measured 9107, 9284 feet true vertical 9449 feet Packer true vertical 8041, 8163 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2632 13-3/8" 37-2669 37-2669 5380 2670 Intermediate 9810 9-5/8" 35-9845 35-8642 6870/8150 4760 / 5080 Production Liner 1666 7" 9361 -11027 8246-9573 8160 7020 Perforation Depth: Measured depth: 10026 -10305 feet True vertical depth: 8791-9015 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# x 4-1/2" 12.75#, 13Cr80 / L-80 33-9400 33-8277 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9107 8041 true vertical depth) 4-1/2" Baker SAB Perm Packer 9284 8183 12. Stimulation or cement squeeze summary: Intervals treated (measured): Surface OA Treatment descriptions including volumes used and final pressure: Pulled integral plug valves off both sides and observed WeIlLock to top of both outlets. Possible wormhole in WeIlLock observed on 3:00 side. Rigged up Lincoln pump to pre -filled hardline and squeezed minimal amount of WeIlLock into OA @ 3:00 o'clock position while monitoring for pressure buildup or WeIlLock returns on the 9:00 side. Held squeeze pressure of 2500 psi for 4.5 hours with no loss at end of monitor (bled OAP several times due to thermal expansion). No pressure buildup or WeIlLock returns observed (a) 3:00 side. WeIlLock sample has set up and hardened. Final Pressures: OA = 0 psi, IA = 1606 psi, TBG = 221 psi 13' Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mof Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 134 376 3388 1580 228 Subsequent to operation: 172 443 3394 1606 221 14. Attachments: (re,rred per 20 nac 25.070.25 071, &25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-495 Authorized Name: Tempel, Joshua Contact Name: Tempel, Joshua Authorized Title: Well Integrity Engineer Contact Email: Joshua.Tempel(Mbp.com Authorized Signature: . � -7 Date: , &20 Contact Phone: '79'-q— bq 1 -5-'730 Form 10-404 Revised 04/2017 /,0 r%� JF-2p j1r/r�r�RnMS1AN 101010 Submit Original Only RD OA, RU Intergal and block valve w/ high temp gaskets. RD Comp OA flange and VR Plug, RU 11/15/2019 Inter al and block valve w/ high temp gaskets. RDMO. ***Job Complete*** TWO = SSV/580/30. Temp = SI. Bleed IAP & OAP to 0 psi. (pre wellock squeeze). ALP = 1960 psi, AL SI @ casing valve. IA FL @ 7996' (Sta #2, SO, 428 bbls). Bled IAP from 580 psi to 110 psi in 3 hours to OT tank. During bled OAP decreased 20 psi and IA FL unchanged. Monitored during rig down, IAP, OAP, and IA FL unchanged. Final WHPs = SSV/110/10. 11/16/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 TWO = SSV/110/60. Temp = SI. Bleed OAP to 0 psi (pre WeIlLock). AL spool dropped. OA cemented to surface. Installed heater in WH for day shift. Bled OAP from 60 to 0 psi in <30 seconds. Monitored for 30 minutes, OAP increased 50 psi. Bled tree cap to 0 psi and left WH door open. Final WHPs = SSV/110/50. 11/18/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 00:30 TBT/PJSM. Pulled integral plug valves off both sides and observed wellocK to top of both outlets. Possible wormhole in Wellock observed on 3:00 side. Rigged up Lincoln pump to pre-filled hardline and squeezed minimal amount of WeIlLock into OA @ 3:00 o'clock position while monitoring for pressure buildup or Wellock returns on the 9:00 side. Held squeeze pressure of 2500 psi for 4.5 hours with no loss at end of monitor (bled OAP several times due to thermal expantion). No pressure buildup or Welllock returns observed @ 3:00 side. Rig up CNG hose accumulator with AL gas. Monitor for 24 hrs. 11/18/2019 ***Job continued on 11/19/19*** ***WSR Continued from 11/18/19.*** Continue monitoring temperature and OAP as WeIlLock sets up. Monitored for an additional 15 hrs. No bleeds or squeeze pressure increases were necessary. Directed to leave full squeeze pressure applied to OA on departure. Temp = 80°. FWHP's = SSV/120/1800. 11/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00. TWO = SSV/130/1850. Temp = SI. WHPs (post WeIlLock). ALP = 1940 psi, SI @ CV. OA cemented to surface. WH temp = 850. OAP increased 50 psi in 12 hrs. Tree cap bled to 0 psi. Heater working properly. WeIlLock sample has consistency of warm honey. 11/20/2019 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 T/I/O = SSV/130/1860. Temp = SI. WHPs (post WeIlLock). ALP = 1970 psi, SI @ CV. WH temp = 880. OAP increased 20 psi in 9 hrs Heater working properly. WeIlLock sample is unchanged. 11/21/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:00. TWO = SSV/14011880. WHPs (Post Wellock). AL SI @ casing valve (1890 psi). WH temp = 90*. The IA remained unchanged and the OAP increased 10 psi overnight. Heater is working properly. Wellock sample is the consistency of molasses. 11/22/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 11:20 TWO = SSV/110/1840. Temp = SI. WHPs (Past Wellock). ALP SI @ casing valve (1860 psi. WH temp = 89*. The IAP remained unchanged and the OAP decreased 40 psi since 0300 hrs. Wellock sample is the consistency of cold molasses. 11/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:35 TWO = SSV/110/1770. Temp = SI. WHPs (Post Wellock). ALP = 1890 psi, SI @ CV. WH temp = 66°. IAP unchanged and the OAP decreased 30 psi since 04:00. Heater is working properly. WeIlLock sample has hardened but retains some plasticity. 11/24/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:30 T/1/0 = SSV/110/1760. Temp = SI. WHPs (Post Wellock). ALP = 1900 psi, SI @ CV. WH temp = 82*. IAP unchanged and the OAP decreased 40 psi overnight. Heater is working properly. Wellock sample has set up and hardened. 11/25/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 cemented to surface. WH temp = 50°. IAP increased 20 psi, OAP decreased 60 psi in 8 hrs. Heater working properly, vent partially closed and heater trunk repositioned. WeIlLock sample is set up and hardened. 11/26/2019 SV, SSV, WV = C. MV = O. IA, OA = OTG. 20:15 Daily Report of Well Operations PBU X-05 TWO = SSV/110/1720. Temp = SI. WHPs (Post Wellock). ALP = 1900 psi, SI @ CV. WH temp = 68°. IAP unchanged, OAP increased 160 psi in 12 hrs. Re -positioned heater trunk and monitored for 2 hrs. WH temp = 88° upon departure. Heater is working properly. Wellock sample has set up and hardened. 11/27/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 T/I/O = SSV/110/1660. Temp = SI. WHPs (Post Wellock). ALP = 1840 psi, SI @ CV. WH temp = 60°. IAP unchanged, OAP increased 470 psi in 14 hrs. Heater is working properly. WeIlLock sample has set up and hardened. 11/28/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 T/f/O = SSV/110/1510. Temp = SI. WHPs (Post WeIlLock). ALP = 1840 psi, SI @ CV. WH Temp = 70F. IAP unchanged, OAP decreased 150 psi overnight. Heater is working properly. Repositioned heater trunk slightly closer to WH. WeIlLock sample is hard. 11/29/2019 SV = C. WV, SSV, MV = OTG. 16:45 TWO = SSV/110/1510. Temp = SI. WHPs (Post WeIlLock). ALP = 1840 psi, SI @ CV. WH Temp = 70°. IAP & OAP unchanged overnight. Heater is working properly. No heater trunk adjustment needed at this time to WH. 11/30/2019 SV = C. WV, SSV, MV = OTG. 15:30 TWO = SSV/110/1530. Temp = SI. WHPs (Post WeIlLock). ALP = 1840 psi, SI @ CV. WH Temp = 82°. IAP unchanged, OAP increased 20 psi overnight. Heater is working properly. No heater trunk adjustment needed at this time to WH. 12/1/2019 SV = C. WV, SSV, MV = OTG. 15:30 TWO = SSV/110/1530. Temp = SI. WHPs (Post Wellock). ALP = 1840 psi, SI @ CV. WH temp = 80°. IAP and OAP unchanged overnight. Heater working properly, no adjustments needed. 12/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 T/I/O = SSV/110/1460. Temp = SI. WHPs & remove CNG hose. ALP = 1900 psi, SI @ CV. Removed CNG hose from OA & bleed gas head on OA to 0 psi. Final WHPs = SSV/110/0. 12/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 T/I/O=SSV/100/0. Post well lock. RD 3" integral and hard line on working side O/A. RU 3" Gray valve on working side O/A. Torqued to API spec.RD 3" integral and hard line on companion side O/A. RU 3" 5000 blind flange to companion side O/A. Torqued to API spec. Job Complete. See log. Final WHP's 12/3/2019 SSV/100/0. I/A, O/A=OTG. T/I/O = 1680/240/160. Temp = SI. Assist Ops with PoP (Post WeIlLock). PoP in progress on arrival. ALP = —2000 psi, open @ CV. Monitored WHPs during PoP. OA pressure increased quickly from 160 to 210 psi, then gradually decreased to 4 psi over the course of 3.5 hours in line with temperature stabilization. Final WHPs 240/1820/0. 12/7/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:15 TWO = 200/1580/0+. Temp = 1300. WHPs (Post Wellock). ALP = 1580 psi and is online. TP decreased 40 psi, IAP decreased 240 psi overnight. 12/8/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00. T/I/O = 210/1530/0+, Temp = 121 °. WHPs (post wellock). AL online. Removed heater. IAP decreased 50 psi, OAP unchanged from 12/8/19. 12/10/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:00 T/I/O = 260/1590/0+. Temp = 1260. WHPs (post Wellock). AL online. IAP increased 60 psi, OAP unchanged from 12/10/19. 12/12/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 TWO = 200/1570/0+. Temp = 156°. WHPs (post Wellock). ALP = 1570 pai and is online. TP decreased 60 psi, IAP decreased 20 psi, OAP unchanged overnight.. 12/13/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:40. TWO = 210/1560/0+. Temp = 1170. WHPs (post Wellock). ALP = 1570 psi, open @ CV. TP increased 10 psi, IAP decreased 10 psi, & OAP unchanged overnight. 12/14/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 T/I/O = 180/1520/0+. Temp = 129". WHPs (Post Wellock). AL open @ casing valve. The TP decreased 30 psi, IAP decreased 40 psi and the OAP remained unchanged since 12-14-19. 12/16/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 Daily Report of Well Operations PBU X-05 TWO = 180/1620/0+. Temp = 122°. WHPs (Post Wellock). ALP = 1620 psi, open @ CV. IAP increased 100 psi, OAP unchanged since 12/16/19. 12/19/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:45 TWO = 240/1610/0. Temp = 1240. WHPs (Post Wellock). ALP = 1610 psi, open @ CV. TP increased 60 psi, IAP decreased 10 psi, OAP unchanged overnight. 12/20/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 00:50 ■11:::�ii1 w31-HFAD= MC:E1/0Y ACTUATOR= AXfLSON OKB. BP/ = 74.19 BF. E EV = 40.28' KOP= Max Angles = 3100 -40-@ 7055 Datum RU= 1017T Datura ND = 8800 SS 5518- Bowan CSG F L-80 BTC, D=8.835" 13-=' CSG. 72#. L-80, CSG, 47#, W D 563 XO 80 BTC Minimum ID = 3.726" @) 9366' 4-112" OTIS XN NIPPLE 4-1/2' TBG, 12.6#, 1301480 VAM TOP, .0152 bpf, D=3.958' 1512" TBG, 17#, L-80, .0232 bpf, D=4.892' I TBG TP, 12.750, CS HYDRL. ID = 3.958' V8' GSG, 47#. SOO-95, BTC. ID = 8.681' PERFORATON SLMkRY REF LOG: SM - BHCS ON 02/15180 ANGLEATTOPFBiF 35' @ 10026' Note: Refer to Production DB for historical perf data SIZE SPF IVIEiVAL OprJSgz SHOT SLY 3-118' 4 10026 - 10050 O 04/08/88 RK 2-718" 4 10146-10148 S 03120/88 36 3-1/8' 4 10148-10175 O 04/08/88 2 3- V8' 4 10185-10217 O 04/08/88 RK 31/8' 4 10227 -10305 O 04/08/88 36 2-71r 4 10317 - 10336 S 0320/88 7- LNP 29#, L-80, .0371 bpf, D = X-05 SAFETYNOTES'CHROMETBG8 MPPLES'** X r DV PKR r -ac I Fr MnnrlRcl c ST MD ND OLi/ TYPE VLV LATCH SIZE 4 3490 3477 17 MMG DOME RK 16 3 6203 5744 36 MMG DOME RC 16 2 7996 7148 38 MdG SO RK 28 :,IATE 1 8990 7946 36 M�1G DMY w 0 DATE REV BY COWANM DATE REV BY OO?AMRM 0224180 ORIGINALCOMPLETON 07/29115 W-ra(AC GLV CfO(07104115) 04113/09 N2ES RWO 09106117 MOM GLV p0(09101/17) 07YJ0/09 JR/M) DRLG DRAFT COWECT10NS 1125M SV P11LL BP/SLOGGOS (0427/09) 03/20/14 WID'1JMD SEr 4-12' PX PLUG (03117114) 0729N5 M--,c4j D P LLID Px FLOG (075Wi-5) C l9-518' x 4-12' BIIRS-3 PKR, D=3.875' 4110HESXNP, D=3.813" X 5112' XO, D = 3.958' PBR SEAL ASSY x 4-1/2" BKR SAB FIG OTIS X NIP, ID = 3.813' 412' OTIS )N 4-12' WLEG,1 ELMD Tr LOG1 FISH: WRPRISBM ELEWNr(0126f09) 7' MARKa2JOM PRIJC DE BAY UPfr WELL' X-05 PBiMr No: 1791040 AS No: 50-029-20422-00 SM 6, T10K R14E, 36T PPL 8 59 FWL BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Joshua Tempel Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X-05 Permit to Drill Number: 179-104 Sundry Number: 319-495 Dear Mr. Tempel: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jere ce Chair DATED this 1 day of November, 2019. IBDMS±� Nov 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED &V H/ 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChangAr g 1 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 11 After Casing ❑ Other OA WeIILock qX%e 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0. 5. Permit to Drill Number: 179-104 3, Address: P.O. Box 196612 Anchorage, AK 6 API Number: 50-029-20422-00-00 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU X-05 - 9, Property Designation (Lease Number): 10. Field/Pools: ADL 028313 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ftp Total Depth TVD(f ): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11029 9574 10870 9449 None 10297 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2632 13-3/8" 37-2669 37-2669 5380 2670 Intermediate 9810 9-5/8" 35-9845 35-8642 6870 / 8150 4760 ! 5080 Production Liner 1 1666 7" 9361 - 11027 8246-9573 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10026 - 10305 1 8791 -9015 4-1/2" 12.6# x 4-1/2" 12.75# 13Cr80 / L-80 33-9400 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 9107 / 8041 4-1/2" Baker SAB Perm Packer 9284/8183 12. Attachments: Proposal Summary El Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Cl Exploratory ❑ Straligraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: November 13, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Tempel, Joshua be deviated from without prior written approval. Contact Email: Joishua.Tempeldbp.com Authorized Name: Tempel, Joshua Contact Phone: Authorized Title: Well Integrity Engineer Authorized Signature: / Date: / 0 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Num e Plug Integnty ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: IMS NOV 052019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑No Subsequent Form Required: APPROED BYTHE V Approved by COMMISSIONER COMMISSION Date: 1 NEV lr/111ORIGINAL 1d��5 A6A3/0C. "�j ubmitFormand Attachments in Duplicate Form 10-403 Revised 0412017 Approved application is valid for 12 months from the date of approval - I Well: X -OS X-05 OA Well -Lock Squeeze Sundry Expected Start Date: November 13, 2019 Well Interventions/Pad Engineer: Josh Tempel (907)891-5930 History X-05 has a history of IAxOA communication. Due to OA re -pressurization while on gas lift, in 2009 a RWO cut & pulled the PC and cemented the OA. Post RWO the OA re -pressurized and in 2015 the OA was treated with Well -Lock. The treatment was effective until 2018 when re -pressurization was seen and it was retreated with Well Lock. On 10/26/2019, the OA pressure was reported over NOL and attempts to bleed the OA resulted in rapid repressurization. Current Status As of 10/27/2019, the well is currently under evaluation and will be soon shut-in and classified as "Not -Operable' by BP. Objective Squeeze the cemented OA with Well Lock to re -mediate OA re -pressurization. Procedure 1. ND OA Gate Valve, NU OA Integral 2. Bleed Annuli, Prep OA. 3. Welllock OA. Squeeze to 2500 psi. 4. Monitor for a minimum of 7 days. 5. ND OA Integrals, NU OA gate valves by o1woo 3- LIMMY REF LO(? SM- BF65 ON 07715/80 R= A?B ---_.— 741V SIZE -4026' - -.. - 31 W S -W CSG 47N, SNDT SOZ L-BOWD563XO TO L-81 SM 10177' = sow SS 07AMM 9-518' 801094 CSG PATCµ 47#, L-80 BTG 0 -SA 5' Mtrtinum ID = 3.72b- @ 9366' 4-112" OTIS XN NIPPLE 1260, 1=4-80 VAMTOP, Ka L1218G'R, 12.751, GS IrvDRL, ID = 3.956'- 9400- PERFOPATe)N SL*AFAR7 REF LO(? SM- BF65 ON 07715/80 ANGLEATTOPPSF: 35-61002W NI : Fbfa b Roduckon OB fa hitrf data SIZE MF3NAL fpn/5� SNDT SOZ &1/8'0026- 10050 O 07AMM 2-718'0148-10148 Gf.0 S 032488 3-1/8'0148-10175 9NTE6 O 04A8188 31/r 4110185-10217 0 0410&88 3-Iff0127-109D5 O 04100188 2-718'0317- 10336 5 0371Fk88 mim X-05 Well: X-05 SAIFEFYIgT�:"'(]ftOGlE TffGd fJpPLB••• Heel cr uevno< OATE REV BY OON RM I DATE jF?,FVBYj CONAROS 02lANW V TYPE F&YO OAgNiT MOST GI.V 60109101717) 0700049 JRAGC Ofd_G CRAFTOON3S:M MiE7 07119115 N:SIJ RLLFDP7i 0.W 14Tl04H5) Gf.0 9NTE6 NSM?CW NAG ffFa( 9A1H78 LVM W1117 MAG 910 1117 OATE REV BY OON RM I DATE jF?,FVBYj CONAROS 02lANW ORGINIL GOMPLGTION 07r2gms lw"AOGLV OO (0710045) OIfl9109 MMS F&YO OAgNiT MOST GI.V 60109101717) 0700049 JRAGC Ofd_G CRAFTOON3S:M 11/25049 SV FILL MSLLOUFF" (OY27109) 0920/14 VX W SET 412 PX FLM (03!77/14) - 07119115 N:SIJ RLLFDP7i 0.W 14Tl04H5) x 4-12 PL1R PFAIDFIOE BAY LM AaL xAs PE35f46: 5791040 AN No: 5DM9-20422-00 TIOµ RI4E 36T Rt 8 50 PAL BP &plmalloa (ANaka) STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMI REPORT OF SUNDRY WELL OPERA 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations,�i ❑ Suspend ❑ Perforate 11Other Stimulate 11Alter Casing 11Change ApAp—r43v P rlp ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ® Re-enter Susp Well ❑ Other: OA WeIlLock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 179-104 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. API Number: 50-029-20422-00-00 7. Property Designation (Lease Number): ADL 028313 8. Well Name and Number: PBU X-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: None feet measured Total Depth: measured 11029 feet Plugs true vertical 9574 feet Junk Effective Depth: measured 10870 feet Packer true vertical 9449 feet Packer Casing: Length: Size: MD measured None feet measured 10297 feet measured 9107, 9284 feet true vertical 8041. 8183 feet TVD: Burst Structural Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Conductor 80 20" x 30" 38-118 38-118 Surface 2632 13-3/8" 37-2669 37-2669 Intermediate 9810 9-5/8" 35-9845 35-8642 Production Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 10 Gas ❑ WDSPL ❑ Liner 1666 7" 29# L-80 9361 -11027 8246-9573 Perforation Depth: Measured depth: 10026 - 10305 feet Sundry Number or N/A if C.O. Exempt: True vertical depth: 8791 -9015 feet %E!D N O 1/ 14 flA Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# x 4-1/2" 12.75#, 13Cr80 / L-80 33-9400 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9107 true vertical depth) 4-1/2" Baker SAB Perm Packer 9284 5380 6870/8150 8160 Collapse: 2670 4670/5080 7020 33-8277 8041 8183 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treat Cemented OA with WeIlLock Treatment descriptions including volumes used and final pressure: Squeezed 0.7 gals of WeIlLock into OA @ 3:00 o'clock position. Held squeeze pressure of 2800 psi for one hour with no loss at end of process. Swap to opposite side of OA spool piece; 9:00 o'clock and squeezed WeIlLock into OA and held squeeze pressure at 2800 psi. pumped volume 0.3 gallons. Left 2000 psi on both sides and hung tags explaining process on repair. Arrange to have daily monitors for 14 days. Both sides of OA jewelry are solid with WeIlLock. Final Pressures: OA: 400 psi, IA: 300 psi, TBG: 107 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 248 1613 6261 1673 289 Subsequent to operation: No Test Available 300 107 14. Attachments: (required Per 20 AAc 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 10 Exploratory ❑ Development RI Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 10 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-209 Authorized Name: O'connor, Katherine Contact Name: O'connor, Katherine Authorized Title: Integrity & Interventions Engineer Contact Email: Katherine. O'connorCD_bp.corn IAuthorized Signature: Date: (1' 1 118 Contact Phone: +1 9075644640 Form 10-404 Revised 04/2017 01 r i VI `j l?' RBDMSg,$) NOV 0 9 2018 Submit Original Only Daily Report of Well Operations PBU X-05 ACTIVITYDATE SUMMARY T/I/O=SSV/260/0. RD O/A Working side 3" Vetco Gray valve. RU 3" intergal. with 2" hardline block valve and cap. RD Companion side 3" blind and RU 3" intergal with 2" hardline block valve and cap. No PT 10/8/2018 required. *** Job Complete *** Final WHP's = SSV/260/0. See log. T/I/O = SSV/260/0. Temp = SI. Treat cemented OA w/ WeIlLock. AL SI @ casing valve, ALP = 1930 psi. TBT/PJSM. Pulled integral plug valves off both sides of OA casing spool and reinstalled integral cap. Rigged up Lincoln pump and squeezed 0.7 gals of WeIlLock into OA @ 3:00 o'clock position. Held squeeze pressure of 2800 psi for one hour with no loss at end of process. Swap to opposite side of OA spool piece; 9:00 o'clock and squeezed WeIlLock into OA and held squeeze pressure at 2800 psi. pumped volume 0.3 gallons. Left 2000 psi on both sides and hung tags explaining process on repair. Arrange to have daily 10/10/2018 monitors for 14 days. ***Job Complete*** T/I/O = SSV/300/1050. Temp = SI. WHPs (Post OA Wellock squeeze). ALP = 2000 psi, SI @ CV. OAP = 1100 psi @ 3 o'clock valve, OAP = 1000 psi @ 9 o'clock valve. Wellhead temp taken from thermometer at the 6 o'clock position = 78*. Wellock sample in Nalgene bottle on top of wellhead has not set up. Heater in wellhouse working properly. 10/11/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 T/I/O = SSV/300/320-360. Temp = SI. WHPs (Post OA Wellock squeeze). ALP = 2000 psi, SI @ CV. OAP = 320 psi @ 3:00 valve, OAP = 360 psi @ 9:00 valve. Wellhead temp taken from thermometer at the 6 o'clock position = 58*. Wellock sample in Nalgene bottle on top of wellhead is firm but will indent. Heater is out of burner fuel and blowing cold, call non-mobile. Heater replaced and working properly on departure. 10/12/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40. T/I/O = SSV/300/330-540. Temp = SI. WHPs (post OA Wellock squeeze). ALP = 2000 psi, SI @ CV. OAP = 330 psi @ 3 o'clock valve. OAP = 540 @ 9 o'clock valve. Wellhead temp taken from thermometer @ 6 o'clock position = 74°. Wellock sampe in Nalgene bottle on top of wellhead is firm but will indent. Heater is installed and blowing hot air. 10/13/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/300/260-500. Temp = SI. WHPs (Post OA Wellock squeeze). ALP = 2000 psi, SI @ CV. OAP = 260 psi @ 3 o'clock valve and 500 psi @ 9 o'clock valve. Wellhead temp taken from thermometer @ 6 o'clock position = 88*. Wellock sample is hard. Heater in WH working properly. 10/15/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:20 T/I/O = SSV/300/0. Temp = SI. WHPs (post OA Welllock squeeze). ALP = 2000 psi, SI @ CV. Both sides of OA jewelry are solid with wellock and stuck at @250 psi. Verfied wellock was hard on OA jewelry and plastic nalgene bottle. Wellhead temp taken from thermometer @ 6 o'clock positon = 90°. Heater working preperly. 10/16/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 T/I/O = SSV/300/0. Temp = SI. WHPs (post OA Wellonck squeeze). ALP = 2000 psi, SI @ CV. Both sides of OA jewelry are solid with wellock. Wellhead temp taken from thermometer @ 6 o'clock position = 880. Heater working properly 10/17/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/300/0. Temp = SI. WHPs (Post OA Wellock squeeze). AL SI @ casing valve (2000 psi). Wellhead temp @ 95* (heater adjusted). Replaced 3 o'clock position gauge. 10/18/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1330 hrs. T/I/O = SSV/300/0. Temp = SI. WHPs (Post OA Wellock squeeze). ALP = 1990 psi, & SI @ casing valve. Wellhead temp @ 78* taken from thermometer @ 5 o'clock position, heater working properly. Sample set up hard 10/19/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:00 hrs. IT/I/O = SSV/310/0. Temp = SI. WHPs (post OA Wellock squeeze). ALP - 1990 psi, SI @ CV. Wellhead temp @ 740 taken from thermometer @ 5 o'clock position. Removed and released heater. 10/20/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 08:00 Ol 0 Daily Report of Well Operations PBU X-05 T/I/O = SSV/300/500. Temp = SI. Remove 1502 Integrals (Post Wellock). AL SI @ casing valve (2000 psi). Bled the OAP to 0 psi (-1 second, gas). Loosened the 1502 integral flange bolts on both sides of the casing spool. Used a steel wedge to release the 1502 integral from the casing spool. Performed a NFT test for 1 hour (no observable flow). Removed 1502 integrals from casing spool (minor bubbling @ top of VR profile, both sides). Valve shop re -installed the OA casing valve & blind flange. FWPs = SSV/300/0. 10/27/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1200 hrs. R/D intergals and block valves on OA post Well Lock. RU 3" Gray valve on O/A. Torqued 10/27/2018 IT/I/O=SSV/360/0. to spec. RU 3" blind flange torqued to spec. Job Complete see log. Final WHP's SSV/360/0. WELLHEAD = MCEVOY ACUATOR= AXELSON OKB. BLV = 74.18' BF. BLV = 40.29 KOP = 3100' Max Angle = 40" @ 7055 Datum MD = 10171' Datum TVD = 8800' SS • 9-5/8" CSG, 47#,1319' L 80 W D 563 XO TO L-80 BTC 9-5/8 �BOVVE N CSG PATCHI, 47#, 388 1' L-80 BTC, D = 8.835" 13-3/8' CSG, 72#, L-80, D=12.34r 2669' Minimum ID = 3.726" @ 9366' 4-1/2" OTIS XN NIPPLE X-05 1347' H 9-518" H m ES cBMENfm j 1360' 13-318' —X 9 -W BKR BCP, D = 8.835' 2208' 4/1/2' HES X NP, D = 3.813' 2571' 95/8' DV PKR GAS LFf MANDRELS ST MD TVD DEV TYPEI VLV LATCH I SIZE DATE 4 3490 3477 17 MMG DOW RK16 9266' BKR_ PBR SEAF ASSY 09/01/17 3 6203 5744 36 MMG DOME RK 16 09/01/17 2 7996 7148 38 MMG SO RK 28 09/01117 1 8990 7946 36 MNG D RK 0 09/01/17 14/1/2' FES X W. D = 3.813' 9100' H 9-518' x 4-1/2" BKR S-3 PKR, D = 3.875" 9135' 411/2" HES X NP, D = 3.813' 4-1/2" TBG, 12.6#, 13CRr80 VAM TOR 9=- REF LOG: SWS - BHCS ON 02115(80 ANGL.EAT TOP FERF: 35" Q 10029 .0152 bpf, D= 3.958" SIZE 4-1/2' X 5 1l2" XO, D= 3.958' TBG STlt;3 (04/12m) 921T Opn/Sgz SHOT SOZ 3-1/8" 9MIC 9.518" X5-112' UNQUEOVBZSHOT 10026 -10050 O 9266' BKR_ PBR SEAF ASSY 5-1/2' TBG, 17#, L-80, .0232 bpf, D=4.8�' 8284' 2-7/8' 4 TOPOF 4-1/2" TBG 92$¢' S 9284' 9-5/8' x 4-112" BKR SAB � D = 3.813' 3-118' 9334' 41/2 OTIS X NIP, ID = 3.813' TOP OF r LHR 9361' O 8361' 9-5/8' X r BKR LM HGR 3.118' 9368' 4-1/2" OTIS XN NIP, D = 3.725' 4 112' TBG TP, 12.75#, CS HYDRl , ID = 3.958' ��' O 9400' 4-112" VVLLG, D = 3.958" "/8" CSG, 47#, SOO-95, BTC, ID = 8.681"FE—�, • 3.1/8' 9396" ELMD TT LOGGED 04J25M I PERFORATDN SUMMARY REF LOG: SWS - BHCS ON 02115(80 ANGL.EAT TOP FERF: 35" Q 10029 Note: Refer to Production DB for historical perf data SIZE SPF 114TE8/AL Opn/Sgz SHOT SOZ 3-1/8" 4 10026 -10050 O 04/08188 2-7/8' 4 10146-10148 S 03/20/88 3-118' 4 10148-10175 O 04/08/88 3.118' 4 10185 -10217 O 04/08/88 3.1/8' 4 10227 -10305 O 04/08/88 2-718* 4 10317 -10336 S 03/20/88 PBTD 10870' 7" LNR, 29#, L-80,.0371 bpf, D = 6.184"11027' ? H FISH: VVRP RLBBER ELB &W 10165' r MARKERJONT DATE REI/ BY COMMENTS DATE REV BY COMINM 02/24/80 ORIGINAL COMPLETION 07/29/15 MGS/JIMD GLV aO (07/04/15) 04/13/09 N2E5 RNO 09/06117 MGS/JM) GLV C/O (09/01/17) 07/30/09 JR'JWD DRLGDRAFTCOFf6CIDNS MUM SV PULL BP/SLUGGITS (04127109) 03/20/14 I ~JMDI SET 4-1/2' PX PLUG (03117/14) 07/29/15 MGSIJM) RLLEDPX RUG (07AW15) 11 1 PRIDHIDE BAY LINT WELL X-05 POUT ND: 9791040 API ND: 50-029-20422-00 SEC 6, T10N, RNE, 363' FPL. & 59 FVVL BP 6rplorabon (Alaska) ti II 44).- 1//7.11:,v, THE STA, Alaska Oil �� /iand (gas 4 �►� � of jT 1S� Conservation Commission Itri'£ �� 333 West Seventh Avenue f GOVERNOR BILL WALKER Anchorage, Alaska 99501-8572 OF *� Q. Main: 907.279.1433 ALAS Fax: 907.276.7542 WWW.aogcc.alaska{gov Katherine O'Connor Interventions& Integrity Engineer- Challenger BP Exploration(Alaska), Inc. JUN 0 7'2 P.O Box 196612 018 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X-05 Permit to Drill Number: 179-104 Sundry Number: 318-209 Dear Ms. O'Connor: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, la42 - Hollis S. French Chair -4 DATED this 5 day of June, 2018. RBDMS JUN 0 6 cos STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION PIS 5(51/5 APPLICATION FOR SUNDRY APPRWLS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 171 • Ope do s dry 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Chankfe4 ketS4❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA WellLock Squeeze El l• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 179-104 . 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20422-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No a PBU X-05• 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028313 . PRUDHOE BAY.PRUDHOE OIL ` 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: -MPSP(psi): Plugs(MD): Junk(MD): 11029 • 9574 • L 10870 9449 None 10297 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2632 13-3/8" 37-2669 37-2669 5380 2670 Intermediate 9810 9-5/8" 35-9845 35-8642 6870/8150 4760/5080 Production Liner 1666 7" 9361-11027 8246-9573 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10026-10305 8791-9015 4-1/2"12.6#x 4-1/2"12-75" 13Cr80/L-80 33-9400 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 9107/8041 4-1/2"Baker SAB Packer 9284/8183 12.Attachments: Proposal Summary El Wellbore Schematic 0 13.Well Class after proposed work: • Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q Service Q 14.Estimated Date for Commencing Operations: June 1,2018 15. Well Status after proposed work: • Oil 0` WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: O'connor,Katherine be deviated from without prior written approval. Contact Email: Katherine.O'connori bp.com Authorized Name: O'connor,Katherine Contact Phone: +1 9075644640 Authorized Title: Interventions&Integrity Engineer-Challenger Authorized Signature: Date: 05 /11 /2 b 1 8 COMMISSION USE ONLY - I Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ✓ t^ `e� Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 I�CC1 Other: �` Post Initial Injection MIT Req'd? Yes 0 No L7 Spacing Exception Required? Yes 0 No lE/ Subsequent Form Required: /) — 4 O + pp l APPROVED BYTHE e /5)1c.) ,' I A roved by: COMMISSIONER COMMISSION Date: Co VTL 5/3///5 RBDMS_ JUN 0 s 2018 , si /ir „� ORGNAL Submit Form arid Attachments in Duplicate 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. e • bp Well: X-05 X-05 OA WeIlLock Squeeze Well Interventions Engineer: Katherine O'Connor (907) 564-4640 Pad Engineer: Wade Boman (907) 564-4674 Expected Start Date: June 1, 2018 History X-05 is a gas lifted well and has had a history of IAxOA communication. Due to chronic OA re- pressurization while on gas lift, in 2009 a RWO cut & pulled the PC and cemented the OA. Lately the well has been SI for WC sorts, and while offline it has once again demonstrated OA re-pressurization, exceeding NOL on 5-13-2018, with TIO pressures of 1880/1890/1640 psi and a fast OA BUR. The well passed a PPPOT-IC so the communication is not through the wellhead. The plan forward is to trouble shoot with DHD and obtain an OA BUR. A Well lock treatment will then be squeezed into the cemented OA to mitigate the re-pressurization and pending success the well can be brought back to operable status with live GLVs. Current Status The well is currently under evaluation and will be soon shut-in and classified as "Not-Operable" by BP. Objective Squeeze the cemented OA with Well Lock to seal off the OA re-pressurization. Procedure 1. ND OA Gate Valve, NU OA Integral. 2. Bleed Annuli, Prep OA, WeIlLock OA top job squeeze to 2500 psi per RPs. 0 , , AA 'VOY X_O 5 s NOTES:""'CHROME TBGa, ''' ,00 CON 1 ACTU4`IUf2- AXI:LSUN OKB.ELEY= 14 18 ' • !;! i • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 14, 2018 2:20 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Boman,Wade; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer X-05 (PTD# 1791040) Sustained OA pressure above NOL All, Producer X-05(PTD#1791040)was reported to have sustained OA pressure above NOL on 5/13/2018. The well head pressures were confirmed to be T/I/0= 1880/1890/1640psi. The high outer annulus pressure is an indication of a failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. Wellhead—PPPOT-IC, LPE 2. DHD—Bleed IAP,and OAP 3. Wells Engineer- Evaluate for OA wellock 4. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO SCANNED KM/l 771 t? r..•-was erim w..a. 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, August 06, 2015 4:39 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX; 'chris.wallace@alaska.gov';Glasheen, Brian P Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Sternicki, Oliver R; Pettus, Whitney; Sayers,Jessica Subject: OPERABLE: Producer X-05 (PTD#1791040)Well-lock Treatment Complete Attachments: Producer X-05 (PTD #1791040)TIO Plot.docx All, Producer X-05 (PTD#1791040) outer annulus was treated with Well-lock product on June 09, 2015 to mitigate high OA pressure from an external source. The well was placed on production July 17, 2015 and monitored over the last three weeks. The outer annulus pressure has been found to be manageable by bleeds. The well is reclassified as Operable and may remain in service. A copy of the TIO plot is included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) Y1r�1cpp$ AUG 1 0 2015 BP Alaska-Well Integrity Coordinator ��` Gil WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: A , Well Integrity Coordinator Sent: Thursday, Ju ' • 2015 4:27 PM To: AK, OPS GC3&PCC OS ; • , •'S GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Danie, ' -•• AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells •• -••r; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; 'chris.wallace@alaska.gov'; Glasheen, : • P Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity .. s nator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.g• Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION: Producer X-05 (PTD #1791040) Well-lock Treatment Co to All, 1 Producer X-05(PTD#1791040) TIO Plot August 06, 2015 11-111 n. m. 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I Ul t 3 12 u 13 • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AO C3 CC Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redd! ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:Welllock Treatment RI 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 179-104 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20422-00-00 7. Property Designation(Lease Number): ADL 0028313 8. Well Name and Number: PBU X-05 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools. PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth. measured 11029 feet Plugs measured None feet true vertical 9574 feet Junk measured 10297 feet Effective Depth: measured 10870 feet Packer measured See Attachment feet true vertical 9449 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x30" 36-116 36-116 0 0 Surface 2635 13-3/8"72#L-80 36-2671 36-2671 4930 2670 Intermediate 1360 9-5/8"47#L-80 34-1394 1391 -8642 8150 7020 Intermediate 8454 9-5/8"47#S00-95 1391 -9845 8246-9573 8160 7500 Liner 1666 7"29#L-80 9361 -11027 8246-9573 8160 7020 Perforation Depth: Measured depth: See Attachment feet See Attachment True vertical depth: See Attachment feet See Attachment S'I�° Tubing(size,grade,measured and true vertical depth) See Attachment J' See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 36"-1360' Treatment descriptions including volumes used and final pressure: 12 GALS WELLOCK,MIT IA PASSED-Pumped 1.5 bbls of crude down IA to reach test pressure of 2500. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 230 7825 5406 0 266 Subsequent to operation: 337 2396 3600 1469 246 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16 Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 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: 315-183 Contact Summerhays,Nita M( -RO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays,s,N (WIPRO Technologies Title Petrotechnical Data Manager • �r1��1:�A�,, Phone +1907-564-4035 Date 07/31/2015 //,'Z//ice=�T�— - )��- Form 10-404 Revised 5/2015 V / L '/2/f If 1RBDMS° D1m1P4 2015 %M----- Daily Report of Well Operations PBU X-05 ACTIVITYDATE SUMMARY T/I/0=75/110/20. Temp=SI. Install heater in cellar (Well lock). AL SI @ casing valve. ALP=1920 psi. Cellar has— 1'of fluid. Called to have cellar vac'd out. Heater staged in front of well house. 5/30/2015 SV, WV=C. SSV, MV=O. IA&OA=OTG. NOVP. 2130. T/I/)=80/120/20. Temp= SI. Install heat in cellar(Wellock). AL SI @ CV. ALP= 1950 psi. Lined cellar. Called for de-watering in cellar. Bled tree cap to 0 psi above SV. Placed heater in wellhouse. Wellhouse door open. 5/31/2015 SV, WV= C. SSV, MV= 0. IA, OA=OTG. 1615 T/I/O= SSV/120/30. Temp= SI. Cellar prep(Wellock). ALP= 1390 psi, SI @ casing valve. OA cemented to surface. Cellar has Herculite liner w/—2"of water. Heater installed on conductor. Above SSV @ 10 psi. Door left open. 6/2/2015 SV, WV&SSV=C. MV=O. IA&OA=OTG. 0935 hrs. _ T/I/O = SSV/120/0. Temp= SI. Treat cemented OA w/WellLock. AL SI @ casing valve,ALP= 1930 psi. PJSM-discuss job with onsite challenger's. Pulled OA casing valve bull plug and ran hose to TOC. Pumped 8 gallons wellock displacing diesel until clean wellock returns. Re-installed bull plug and used another 4 gallons wellock to pressure OA to 2500 psi and squeeze wellock for 4 hours at 2500 psi. Bled OA to 0 psi and purged across with N2 to clear casing valves. Installed N2 cap @ 500 psi. Tags hung.Arrange to have OA valves serviced. See log for details. Job continues 6/9/2015 on WSR dated 6-10-15. T/I/O= 110/180/450. Temp= SI. Check heaters(Wellock). ALP = 1980 psi. AL SI @ casing valve. WH Temp= 50*. Heater not working. Swapped out heater. 6/15/2015 SV=C. WV= LOTO. SSV, MV= 0. IA, OA= OTG. 1700. ***WELL S/I UPON ARRIVAL*** (new technology project) SET WCS FROM 9,098' SLM. ONE ATTEMPT TO PULL RK-OGLV FROM ST#1 @ 8,969' SLM/8,990' MD. TAG TOP OF RK-OGLV W/ 1.5" LIB IN ST#1 @ 8,969'SLM/8,990' MD. 7/2/2015 ***CONT JOB ON 7/3/15 WSR*** ***CONT JOB FROM 7/2/15 WSR*** (new technology project) TWO ATTEMPTS TO PULL RK-OGLV FROM ST#1 @ 8,969'SLM/8,990' MD. TWO ATTEMPTS TO PULL RK-LGLV FROM ST#2 @ 7,979' SLM/7,996'MD. PULL RK-LGLV FROM ST#3 @ 6,186'SLM/6,203'MD. PULL RK-LGLV FROM ST#4 @ 3,471'SLM/3,490' MD. SET RK-DGLV IN ST#4 @ 3,471'SLM/3,490' MD. SET RK-DGLV IN ST#3 @ 6,186'SLM/6,203' MD. SET RK-DGLV IN ST#2 @ 7,979'SLM/7,996' MD. SET RK-DGLV IN ST#1 @ 8,969'SLM/8,990' MD. 7/3/2015 ***CONT JOB ON 7/4/15 WSR*** T/I/O = 104/72/397 Temp. = 50 Assist SLB SL(WELLOCK) Pumped 18 BBLs of 80*crude down IA to reach test pressure. Bleeding to TBG to maintain a Differential of less than 2000 psi. 7/3/2015 ***Job continued on 7/4/15*** ***Job continued from 7/3/15*** Assist SLB SL(WELLOCK) ****MIT IA PASSED*** Pumped 1.5 bbls of crude down IA to reach test pressure of 2500. First 15 min lost 17 psi Second 15 min lost 10 psi for a total of 27 psi lost. Blead back-6.2 bbls AFE sign hung on master valve, tags hung. Job complete. SL in control of well upon LRS departure. 7/4/2015 FWHP= 526/475/410 Daily Report of Well Operations PBU X-05 ***CONT JOB FROM 7/3/15 WSR***(new technology project) LRS PERFORM PASSING MIT-IA(see Irs log) PULL RK-DGLV FROM ST#1 @ 8,969'SLM/8,990' MD. TWO ATTEMPTS TO PULL RK-DGLV FROM ST#2 @ 7,979'SLM/7,996' MD. PULL RK-DGLV FROM ST#3 @ 6,186' SLM/6,203' MD. PULL RK-DGLV FROM ST#4 @ 3,471'SLM/3,490' MD. SET RK-LGLV IN ST#4 @ 3,471' SLM/3,490' MD. SET RK-LGLV IN ST#3 @ 6,186'SLM/6,203' MD. SET RK-LGLV IN ST#2 @ 7,979'SLM/7,996' MD. SET RK-OGLV IN ST#1 @ 8,969'SLM/8,990' MD. PULLED EMPTY WCS FROM 9,098'SLM. PULLED PRONG FROM 9,104'SLM. PULLED 4-1/2" PX PLUG BODY FROM 9,106' SLM. 7/4/2015 ***CONT JOB ON 7/5/15 WSR*** ***CONT JOB FROM 7/4/15 WSR***(new technology project) R/D ALL PCE, TRAVEL TO COIL SHOP FOR SCHEDULED MAINTENANCE. 7/5/2015 ***WELL S/I UPON DEPARTURE, PAD OP NOTIFIED*** T/I/0=250/1600/0. Temp=152° WHPS (Post Wellock). AL online. ALP=1600 psi. 7/18/2015 SV=C. WV, SSV, MV=O. IA&OA=OTG. NOVP. 0400. T/I/0=230/1600/0. Temp=154° WHPS (Post Wellock). AL online. ALP=1600 psi. IAP and OAP unchanged since last monitor 07/18/15. 7/19/2015 SV= C. WV, SSV, MV= 0. IA, OA=OTG. NOVP. 0315. T/I/O=200/1392/0. Temp= 156°. WHPs(Post wellock). AL on, ALP= 1392 psi. TP decreased 30 psi, IAP decreased 208 psi, OAP unchanged. 7/20/2015 SV= C. WV, SSV, MV= 0. IA, OA= OTG. NOVP. 0145. T/I/O =250/1430/2. Temp= 156°. WHPs(post wellock). AL online. TP decreased 40 psi, IAP increased 40 psi, OAP increased 1 psi overnight, SV= C. WV, SSV, MV=0. IA, OA=OTG. 02:15. 7/22/2015 T/I/0=240/1460/0. Temp=158°. WHPs (Post Wellock). AL online. TP decreased 10 psi, IAP increased 30 psi, OAP decreased 2 psi. 7/23/2015 SV=O. WV, SSV, MV=O. IA&OA=OTG. NOVP. 0430. T/I/O=230/1480/0. Temp= 160*. WHPs (Post Well lock). AL is on line @ 1475 psi. IAP increased 20 psi, OAP= unchanged since 0430 hrs. 7/23/2015 SV= C. SSV, WV, MV= 0. IA&OA=OTG. 1530 hrs. T/I/O=210/1500/10. Temp= 150°. WHPs (Post Well lock). AL online. TP decreased 20 psi, IAP increased 20 psi, OAP increased 10 psi overnight. SV= C. SSV, WV, MV= 0. IA&OA= OTG. 04:30. 7/24/2015 T/I/O=220/1490/16. Temp= 152*. WHPs(Post Wellock). AL on line @ 1490 psi. TP increased 10 psi. IA decreased 10 psi. OA increased 6 psi overnight. OA jewelery under IA companion valve packed with Wellock, replaced. Operator notified. 7/24/2015 SV= C. SSV, WV, MV=0. IA&OA=OTG. 1630 hrs. T/I/O=220/1520/22. Temp= 155°. WHPs(Post WellLock). AL online. TP unchanged, IAP increased 20 psi &OAP increased 2 psi overnight. 7/26/2015 SV=C. WV, SSV& MV=O. IA&OA=OTG. 1500 hrs. T/I/O=220/1510/10. Temp= 155°. WHPs(Post WellLock). AL online. TP unchanged, IAP decreased 10 psi, OAP decreased 12 psi, overnight. 7/27/2015 SV=C. WV, SSV& MV=O. IA&OA=OTG. 1230 hrs. T/I/0=220/1500/20. Temp=155°. WHP's(Post WellLock). AL online,ALP= 1500 psi. IAP decreased 10 psi &OAP increased 10 psi overnight. SV=C. WV, SSV, MV=0. IA, OA=OTG. 13:10. 7/28/2015 T/I/O =220/1500/20. Temp= 155°. WHPs(Post Wellock). AL online. ALP= 1500 psi. No changes in pressures overnight. 7/29/2015 SV=C. WV, SSV, MV=0. IA&OA= OTG. 1515 hrs. Daily Report of Well Operations PBU X-05 T/I/O=220/1500/20. Temp= 155°. WHPs(post Wellock). AL online, ALP= 1500 psi. No changes in pressures overnight. 7/30/2015 SV= C. WV, SSV, MV= O. IA, OA=OTG. 1300 hrs. Fluids Summary BBLS Type 1 DIESEL 5 METH 20 CRUDE 26 Total Fluids Summary GALS Type 12 WELLOCK 12 Total m H la MO N .7 N (D N S M CD Lo M m C>DCDCDMCDI0NOI0 Ln O. O co CD In M N- Ln OO d a- N M Nr CO I- CO 0) — M O 00 65 0) O O) CA CA O) O) CA O O G 00 CIO O O CID O O Cn CIO 0) 0) O. 0 C'') O) N N N N M CD CC) t CO CO CO CO M CO Ln N O CO 000OOOLn a) CO 00 O •-• N Cr) Ln CD N- CO 0) N o 1- 0000) 0) 0) 0) 0) 0) 0) 0) O p CID O CO CO O CD OD O O O OD CA p m LU CO 0 < I- tx m O CIO Ln CD CD 1- O O O O Ln o 2 J w w w U') v N- CA O CC) N- CO O M W J Ci) Z 4-9a O N N N N N N M M w < L11 (� J (� O O O O O O O O O O o 0 p p 0 J p 0. 0. gg = zcnzol_ oO oO W Q W Z Q Z 2 0 Q J Q 2 O o O co co co Ir < X • .0▪ CDCDaOLnCDCDI- ooOol- p, N CIO 0) O N Ln 1- CIO O m M O N- •- •- •- N N N N N N M • (3 0 0 0 0 0 0 0 0 0 0 0 0 ( 10 L a) Y O cc .e •e2 O u) c i vai c i ca d a O U O U) U) U) U) U) U) U) U) Ci) U) U) U) maaaaaaaaaaaa tCOMMCOMMMCOMMCOM O. O t m a a>' I- O v v v v v v v v v v v v p O= c 0 0 0 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N N N N Zow W N- N- N- N- N- N- N- N- N- N- N- N o w IX p J ow O M M CV) CV) CV) CV) CV) CY) M M M M Qm p p W J J Q 0W W J J Q Q 0_ co LL LL. LL. (A 0_ a) E co z 101010101010101010101010 0 0 0 0 0 0 0 0 0 0 0 0 m d d 0 Cl)Jd N0 w a X X X X X X X X X X >< X Q Q m m LL E Cn CI) 0_ tY a) Q, 00000000 co rCO fp.. a9OON � If)aov cc If) N N- CO 11) CO U 0 0 0 O M O O O • O CO N N. N O N M O co I� :: I� � CO O I CO M CO if) e N N x— CO 0) CO CO CO CO 0 HI — O cor- CO CO Nr O) Tr M Co) CO 0) M M CO M N M x— CO CO CO CO it I- NO M CO O O CO co CO N N N r- C) 0) 0) O) 0) V CO Q COMA CO CO O CO M N CO O COX M M M M a) a) a) _JD M= a a0 CO° cD J C� OJlCoclItCo # d M .-J N X I- # * CD h- 4 N C13N N a0 N N co U � Cn �nLO co � ln � � r i 0) 4 .c +-' L.0O Nr CO CO 0)CD CO CO to co a) COI- 0) C co CO co CO — M M 0) JN a-- CO r O W W of 0 Q Q .(7)• 0 „ W W U• O `,7(1 0 Z Z Z Z Z ceW W W m m m m O � ~ ~ Z » » 0 c H Packers and SSV's Attachment PBU X-05 SW Name Type MD TVD Depscription X-05 PACKER 1365.95 1365.88 9-5/8" BOT External CSG PKR X-05 PACKER 9106.15 8040.24 4-1/2" Baker S-3 Perm Packer X-05 PACKER 9284.31 8183.7 7" Baker SAB Packer TMJ a`" X_05 SA�YNOT�-�' ETBG&NIPPLES*** WB_LFEAD= MCP1/OY •ACRIATOR= AXEt.SON 0103.REV= 74.18' 114 t 0; I 134T J H 8`5!8'ms BS CEMNTER BF.ELEV= 31 A, r• BOP= — ar 9-5/8"CSG,47*, H 1319' ;v Mix Angle= 40' 7055 L-00 HY D 563 XO 1360' �- 13 3/8'X 9-5/8"BKR BCP D=8.835' Datum MD= 10177' TO L-80 BTC e Datum ND= 8800'SS I ' 2208' H4/1/2*HES X NP 0=3.813' 9-5/8'BOWEN CSG PATCH,47*, tH 1388' _ �—I 2571' —fie'DV PKR Iml L-80 BTC,D=8.835 11 GAS LFT IYNNDR 3_S 13-3/8'CSG,72*,L-80,D=12.347' H 2669• ST MD ND DEV TYPE VLV LATOI SEE DATE L 4 .3490 3477 17 MNG DOLE RK 1 16 ' 07/04/15 3 6203 5744 36 MMG DOME R( 16 07/04115 2 7996 7148 38 1W DOME RK 16 1 07/04/15 1 8990 7946 36 MNG SO Ia( 26 07/04/15 Minimum ID =3.726" @ 9366' i 9069' H4/1/2"FES XIV,D=3.813' 4412" OTIS XN NIPPLE 9100' 1-19-5/8-x 4-1/T BKR S-3 R0R,13=3.875' I r - 9135' H4/1/2'FES X NP,D=3.813' 4-1/2'TBG,12.61/,13CR-80 VAM TOP, --I 9208' .0152 bpf,ID=3.958' `------1 9208' H4-1/2'X 5-1/2'XO,D=3.958' 5-1/2'TBG STUB(04/12/09) H 921T 9224' H9-5/8'X 5-12'UNDUE OVERSHOT 92g5. —BKR.PBR SEAL ASSY 5-1/2'TBG,17*,L-80,.0232 bpf,D=4.892' H 9284' IR - 9284' H9-5/8'x 4-12'BKR SAB PKR,D=3.813' TC4'OF4-1/2'TBG —I 9284' ►�4 I 9334' —4-1/2'OTIS X NIP,ID=3.813' TOP OF T Lt'R H 9361' 9361' H9-5/8"x r BKR LNR HGR I 9366' 1-4-1/2 OTIS)N NIP,D=3.725' 4-1/T TBG TP,12.75*,CS HYDRL.ID=3.958' —I 9400' 1 - 9400' H4-12'1MLEG,D=3.958' 9-5/8'CSG,47*,SOO-95,BTC, ID=8.681' —{ 9846. 9396' ELMD TT LOGGED 04/25190 PERFORATION SUMMARY REF LOG:SINS-BRCS ON 02/15/80 ' ANGLE AT TOP FT32F:35'0 10026' Note:Refer to Roduction DB for historical pert data I SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-1/8' 4 10026-10050 0 04/08/88 2-7/8' 4 10146-10148 S 0320/88 , ? H FISFt WRP RUBBER ELEMENT(0126/09) 3-1/8- 4 10148-10175 0 04/08/88 10169' Hr MARKERJONT 3-1/8' 4 10185-10217 0 04/08/88 ' 3-1/8' 4 10227-10305 0 04/08/88 2-7/8' 4 10317-10336 S 03/20/88 PBTD —I 10670'J • x'•01 r UR 29*,L-60,.0371 bpf,D=6.184' -- 1102T i,•6••••••• • DATE REV BY OOLOANTS DATE REV BY COMFITS LJO IOE BAY mar 02124/80 ORIGINAL COMPLETION 07/29/15 MOWN)GLV CIO(07/04/15) WELL X-05 04/13109 IQES MO FERMI ND:'1791040 07/30/09 JR/JM) DRUG DRAFT CORRECTIONS AR No: 50-029-20422-00 1125/09 SV RLL BPRSLUGGITS(0427/09) SEC 6,T1ON,R14E,363'RA_&59'FV& 03/20/14 W G JMD SET 4-1/2"PX PLUG(03/17/14) 07/29/15 MGS/JMD PULLED PX RUG(07/04/15) II BP Bcploratlon(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, July 16, 2015 4:27 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Wallace, Chris D (DOA); Glasheen, Brian P Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION: Producer X-05 (PTD #1791040) Well-lock Treatment Complete Attachments: image004.png; image001 jpg; image002.png All, Producer X-05 (PTD#1791040) was treated with Well-lock product on June 09, 2015 to repair outer annulus repressurization that was previously found to be unmanageable by bleeds. Prior to being unsecured,the well passed a MIT-IA to 2500 psi on July 04, 2015 confirming two competent barriers to formation. At this time,the well has been reclassified as Under Evaluation to determine if the treatment was successful. The outer annulus pressure may exceed MOASP (1,000 psi) while determining the stabilization trend. Should the outer annulus pressure approach 2,000 psi, it will be bled off and a new approach developed. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Slickline: Pull downhole plug—COMPLETED 07/04/15 2. Operations: Bring well online 3. Downhole Diagnostics: Monitor outer annulus for stabilization pressure Please call with any questions or concerns. Thank you, Whitney Pettus scow JUL 2 12015 (A/i'mutt': Kevin 1'mr%,) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@JBP.com From: AK, D&C Well Integ • sordinator Sent: Thursday, January 16, 2014 1 . _AM To: AK, OPS GC3 Facility & Field OTL; AK, OPS—GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services ations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS Well Pad CX; Wermager, Chad R; 'jim.regg@alaska.gov' 1 ��,_ • • OF TfJ� • is! ��\I�j7 THE STATE Alaska Oil and Gas -,—.��i� of Conservation Commission -� __ . ALASI�:A iii} 2333 West Seventh Avenue -� •11.41.; * , GOVERNOR BILL WALKER Anchorage,e, Alaska 99501-3572 Main: 907.279.1433 ALASFax: 907.276.7542 www.aogcc.alaska.gov Jessica Sayers Engineering Team Leader SCANNED . 'r, ,i 2l `; 110- IC# BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-05 Sundry Number: 315-183 Dear Ms. Sayers: 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, P44.4(/(------ Cathy P. Foerster / Chair DATED this 2 d of April, 2015 Encl. , RECEIVED STATE OF ALASKA Allah 3 1 2.015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request Abandon Plug for Rednll❑ Perforate New Pool❑ Repair Welly Change Approved Program El Suspend Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension & A- vl'tltre44/7v /lz' - Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Well Lock Tee#nelegy • 2.Operator Name: 4 Current Well Class: 5 Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 • 179-104-0 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20422-00-00. 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU X-05 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): -10.Field/Pool(s): ADL0028313 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11029 • 9574 • 9135 8064 9135 10297 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 36 2-116.2 36.2-116.2 Surface 2635 13-3/8"72#L-80 35 7-2671.15 35.7-2670.95 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1666 7"29#L-80 9360.94-11027 8245 53-9572.9 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/7/15 Commencing Operations: Oil D • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Email Jessica.Sayers@BP.Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature cc)c/v/zZe 564-4 81 Date 3/3O// Prepared by Garry Catron 564-4424 /l/•J/` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 6-1S-3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No ' Subsequent Form Required. /I Lr —4 G zi f APPROVED BY Approved b . 14,... _ COMMISSIONER THE COMMISSION Date: ¢ "2 -/S yT 3/31//5- 0 " y- .-/5 O b fa '1 tl H frdfm th la Attachments'3/• i"s Form 10-403 Revised 10/2012 Approved application is veli r 2 o t s to of royal. Submit Form and in Duplicate RBDMS- APR - 6 2015 /,lei ,40f Ln O o °) oOcoo co0coco coop L J Q J J J J (i) a_(i) O O O O O O O • CO co N co N- O O CO U) V N IT) LO N- N N- LO CO U O O O O O O O L- N- Ln CO CO CO V .4- D CO r r O N N m CO CO co V co I- h- a) (n N CO r O f,- N- 021• O V I— A V O CO CO CO (fl CO r r r jr r CO O N CO CO CO I- Q 0 r CO N- CO ~ CO "Zr V CO M CO co co co co N CO M r Op co CO (3 CY) a) E • !n Mr CO (I) LO� � O r C m - 0 CO O CO C COr 00 (O N CO N N Q rn N rn rn rn () O O cm Q Cl) Q H CO V O) Co Co co Co N t13M co co co co CO NN U r 0) O) O) In O (, O O CO Cp O O U O 0i bJ0co —I COJ N CO *k J N J *k xN- C) - (Ni U O = N E0 r N N L() Eo I� () (V M O In r r ([) O CO Ln CO C3) O (O LC) CO CO 6) N O co co Nr CO CO r CO co J r co r N (T W W C • H a 0 U W I-0 U Z W W W m m m Z_ Z__ cn1- 1— Perforation Attachment ADL0028313 Well Date Perf Code MD Top MD Base TVD Top TVD Base X-05 3/17/14 BPS 10026 10050 8791 8810 X-05 3/17/14 BPS 10146 10148 8888 8890 X-05 r 3/17/14 BPS 10148 10175 8890 8912 X-05 3/17/14 BPS 10185 10196 8920 8929 X-05 3/17/14 BPS 10196 10206 8929 8937 X-05 3/17/14 BPS 10206 10217 8937 8945 X-05 3/17/14 BPS 10227 10240 8953 8964 X-05 3/17/14 BPS 10240 10250 8964 8972 X-05 3/17/14 BPS 10250 10270 8972 8987 X-05 3/17/14 BPS 10270 10280 8987 8995 X-05 3/17/14 BPS 10280 10305 8995 9015 X-05 3/17/14 BPS 10317 10336 9024 9039 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028313 Well Facility Type MD Top Description TVD Top X-05 PACKER 1366 9-5/8" BOT External CSG PKR 1366 X-05 PACKER 9106 4-1/2" Baker S-3 Perm Packer 8040 X-05 PACKER 9284 7" Baker SAB Packer 8184 X-05 PACKER 9284 7" 26# L-80 8184 pp ' To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: X-05 WeIlLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 03-17-14 CMIT-IA passed to 2500psi Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1425 psi; Last H2S Reading: 007-14-2013 108 ppm Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 04/13/09: RWO completed cement OA to surface > 08/31/05: FO call-in frequent OA bleeds Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WeIlLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. - 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 11i£= crw 'Y1E1IILAD= 40(3-VC)Y _O5 SAFETTNOTES"•.CHROME TBG&IWPLFS" ACTT A TOR= AXELSON OKH H k V- /4 18' 114� I 134T —9-616"FES ES CEMENTER 1 BF v= 28 99-576•CSG 47#, — 1319` Iry .f Mu Am*= 40'@7055 L-80 I W0 583 ao — - +3160• H13-338"x 9- BKR SCR ID=30'35' Daum Re= 10177 TO L-6O BTC Doom WO- 88610'SS ' II I 2700' Han rr I Fs X NIP,0;3359 9-516'6W994 CSC PATCH.478, --I 1388' _ Lap I 2571"_ 19-54e'OV PAN 1 L-80 BTC,13=8.83' . GAS LFT 1.4148.85 113-318•(SG,728,L-40.D-12.34r f— 2606• ST MU 1v[) DEV TYPE VLV LATCH SeE DATE J 4 3490 3477 17 MAO 0(71E 18( 16 06f065 3 6203 5744 36 1.94G 0061E R( 16 06/06/09 2 7996 7148 38 MAO 0011.E 11< 16 06106109 1 8990 7946 36 .M3 SO 61( 24 06106109 Minimum ID=3.725"01 9366' 1 Sow• 4112 MS x IIP 1)=3.e13- 4-12"OTIS XN NIPPLE o.:4 E. I 9100` H 9-'5AT x 4-1/T 1310111-3 ROL D=3 875' I 9135 via*rEsxPr,D=3813'I 4-112'MG,1160,13CR40 VAM TOP, 9206• s1_3!52.... f l4I112 r x tL r 9Cs 1 f i a .0152 bpi.1)-3-956' .„,__�_-.—•-1 9206' H4-112'X 5-112'NO.ID=3.j 6-112"TBG S U3(04/12409) -I 9217 f `., 1 924' H 9-5Nf X 5-11?MOUE OVERSHOT { 9 AKR PAR SEA'ASSY S-lIT TUG„118.L-80,.025260.V.4.892' 9264' 11+ I 9284' --I%518'a 41/7 BIOL SAS PCR,D=lair J 113POF4-VT1UG H ow -4 iii;_IL 9334 - 14 yr OTS X IIP,D-3.813' TOP OF r Laft H 9361' I 93 —9-5+8-X r atm LP HGR 9366' 1. .74-11' ons 79'3 NY' D=3.725•-.. (4.112'MG TP,12.164.CS HYORL.D=3.508' H mar { 61•9400' -f4-1t1'VAEC,,D-3.956'] `_- 9396 —ELA4o TT LOOOEA 04123'!03 9616`450,471.50093.BTC. D=8-681' — guy PRIFT RA11DN 51MA4.RY ' REF LOG:SW8-811CS ON 02'15180 . ANGLE AT TOP PEW 35"ag 1007€ Nota:Rotor to FFoduc6cal 738 for historical pert data 512E SFF I'BU8IAL OpMSgz 51-0T SOZ 3-118' 4 10026-10050 0 04/08/88 2-7/6' 4 10146,10148 S 03/2048 Z H RSIt WRP I8 BER PiaENT(ov2s/o9) I 3-14' 4 10148-10175 0 04/08188 10169' -;:r r aF „raw 3-1/8' 4 10185-10217 0 04106188 3-1/8' 4 10227 10306 0 .0410648 2-7/8' 4 10317.10336 S `0320168 C P610 1 10470' 41fif/fif1r1F f 4447431 {t r lie,298 L-80,.0371 Opt,D 6.184' Bar ,-f f 11.-ff 1'�-1 444�Atre DATE REV BY OOMEN S DIE REV BY 40!/.43674 PE8DH[)E BAY(.NT 01124160 O81113IN10L COMPLETION 1 41ELL. X.03 04113106 14203 MVO FERF4TP4) 1791040 07(3(009 JRJh4 CALL CRAFT CHOPS API No. 50-029-20422-00 1/625109 SV RLL B1'SLL83Gf5(04/27109) SEC 6.T1011 R14E.363'FM.&59'FWl 03/20/14 INI R M)SET 4-1f2"PX AJJ3(03117414) _ firn BP BmloratloR(Alsskap 3 of 3 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, January 17, 2014 7:24 AM To: AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Wallace, Chris D (DOA); AK, OPS Well Pad CX; Wermager, Chad R; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, D&C Well Integrity Coordinator Subject: RE: NOT OPERABLE: Producer X-05 (PTD #1791040) OAP Not Manageable by Bleeds All, Producer X-05 (PTD #1791040) will remain online temporarily until inclement weather allows for shutting in and freeze protecting. As soon as possible please shut in the well and notify the Well Integrity Team. Thank you, Laurie Climer (111crnatc .- Jack hi,ehrr»r BP Alaska - Well Integrity Coordinator f± Gk: WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, January 16, 2014 11:31 AM To: AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS Well Pad CX; Wermager, Chad R; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer X-05 (PTD #1791040) OAP Not Manageable by Bleeds All, Producer X-05 (PTD #1791040) was found to have a rapid OA repressurization not manageable by bleeds . At this time the well has been reclassified as Not Operable and shall be shut in and freeze protected. Please call with any questions. Thank you, Laurie Climer 'Alternate.*Jac TVs row.; BP'Alaska - Well Integrity Coordinator GkxW Wells tOrganaa on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, December 26, 2013 8:40 AM To: AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS Well Pad CX; Wermager, Chad R Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer X-14 (PTD #1791040) Sustained Outer Annulus Casing Pressure Above MOASP All, Producer X-05 (PTD #1791040) was confirmed to have sustained outer annulus casing pressure above MOASP on 12/22/2013. The pressures were tubing/inner annulus/outer annulus of 1400/1700/1080 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform outer annulus repressurization test Copies of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP AI Well Integrity Coordinator GlobalWells GW COrganizailor Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@bp.com Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator(AKDCWellintegrityCoordinator@bp.com) Sent: Thursday, December 26, 2013 8:40 AM To: AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Wallace, Chris D (DOA); AK, OPS Well Pad CX; Wermager, Chad R Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer 31�--U,(PTD #1791040) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: Producer X-05 (PTD #1791040) TIO Plot.docx; Producer X-05 (PTD #1791040) Wellbore Schematic.pdf All, Producer X-05 (PTD #1791040) was confirmed to have sustained outer annulus casing pressure above MOASP on 12/22/2013. The pressures were tubing/inner annulus/outer annulus of 1400/1700/1080 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation. Plan forward: 1. DHD: Perform outer annulus repressurization test Copies of the TIO plot and wellbore schematic are included for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator Globak lls Organization rganza on XANNED C�rganizai�t�n Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinatorPbp.com a DW 000 2.LW I Ow Producer X-05 (PTD #1791040) TIO Plot WWI:X- s + Tbg —F w �— OA OOA t OOOA On TREE = CM/ WELLHEAD= MCEVOY ACTUATOR = AXELSON KB. ELEV = 74.18' BF. ELEV = 40.28' KOP = 3100' Max Angle = 40° @ 7055' Datum MD = 10177' Datum TVD = 8800' SS 9-5/8" CSG, 47#, —j 1319' L-80 HYD 563 XO TO L-80 BTC 9-5/8" BO WEN CSG PATCH, 47#, L-80 BTC, ID = 8.835" 13-3/8" CSG, 72#, L-80. ID = 12.347" 1 1388' 1 1 2669' 1 Minimum ID = 3.725" @ 9366' 4-112" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, I 9208' .0152 bpf, ID = 3.958" 5-1/2" TBG STUB (04/12/09) -9217- 5-1/2" TBG, 17#, L-80-0232 bpf, ID = 4.892" 9284' TOP OF 4-1/2" TBG 14 9284' TOP OF 7" LNR 1-1 9361' 1/2" TBG TP, 12.75#, CS HYDRIL, ID = 3.958" I 9400' 9-5/8" CSG, 47#, SOO-95, BTC, ID = 8.681" 9845' PERFORATION SUMMARY REF LOG: SWS - BHCS ON 02/15/80 ANGLE AT TOP PERF: 35° @ 10026' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10026- 10050 O 04/08/88 2-7/8" 4 10146- 10148 S 03/20/88 3-1/8" 4 10148- 10175 O 04/08/88 3-1/8" 4 10185- 10217 O 04/08/88 3-1/8" 4 10227- 10305 O 04/08/88 2-7/8" 4 10317 - 10336 S 03/20/88 PBTD 10870' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1102T X-05 SAFETY NOTES:"'CHROME TBG & NIPPLES*** 1347' 9-5/8" HES ES CEMENTER 1360' 13-3/8" X 9-5/8" BKR ECP, ID = 8.835" 2208' 4/1/2" HES X NIP, 1D = 3.813- 2571' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 4 3490 3475 19 MMG DOME RK 16 06/06/09 3 6203 57011 38 MMG DOME RK 16 06/06/09 2 7996 71061 38 MMG DOME RK 16 06/06/09 _L 8990 79051 35 MMG SO RK 24 06/06/09 4/1/2" HES X NIP, ID = 3.813" 9100' N 9-5/8" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 9135' H4/1/2" HES X NIP, ID = 3.813" 9208' 4-1/2" X 5-1/2" XO, ID = 3.958" 9224' 9-5/8" X 5-1/2" UNIQUE OVERSHOT 9265' BKR. PBR SEAL ASSY 9284' N 9-5/8" x 4-1/2" BKR SAB PKR, ID = 3.813" 9334' 4-1/2" OTIS X NIP, ID = 3.813" 9361' 9-5/8" X 7" BKR LNR HGR 9366' 4-1/2" OTIS XN NIP, ID = 3.725" 9400'4-1/2" WLEG, ID = 3.958" 9396' ELMD TT LOGGED 04/25/90 �I FISH: WRP RUBBER ELEMENT (01/26/09) 10169' 7" MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 02/24/80 ORIGINAL COMPLETION 04/13/09 N2ES RWO 07/30/09 JR/JMD DRLG DRAFT CORRECTIONS 11/25/09 SV PULL IBP/SLUGGITS (04/27/09) PRUDHOE BAY UNIT WELL: X-05 PERMIT No: 1791040 API No: 50-029-20422-00 SEC 6, T1 ON, R1 4E, 363' FNL & 59' FWL BP Exploration (Alaska) 17M Schlumber 9 er NO. 5436 Alaska Data & Consulting Services r °.. Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPC -04 AXBD -00061 MEMORY ,, GLS - 11/17/09 1 t NK -38A AWJI -00057 MEM PROD PROFILE L - 11/04/09 1 1 14 -12 B3S0 -00033 PRODUCTION PROFILE 11/13/09 1 1 13 -35 B14B -00084 INJECTION PROFILE V -Q 11/10/08 1 1 06 -08A B14B -00082 PLUGBACK SET W/X-FI OW CHECK - 11/08/09 1 1 H -30 AV1H -00031 PRODUCTIONPROFILE 11/14/09 1 1 18-11A B2NJ -00038 MEM CNL & SCMT I n 111/06/09 1 1 Y -23B AYKP -00055 GLS - - G [S 11/22/09 1 1 N -24 AY54 -00109 PRODUCTION PROFILE - 11/08/09 1 1 02 -31A AYKP -00053 PRODUCTION PROFILE 11/15/09 1 i 03 -01 BBK5 -00014 PRODUCTION PROFILE 11/24/08 1 1 L -213 B581 -00017 INJ PROFILE W/WFL 11/19/09 1 1 W -209 AYKP -00054 INJ PROFILE W/WFL - 11/17/09 1 1 X -05 AP311-00072 PRODUCTION PROFILE 11/29/09 1 1 X -07 AYS4 -00111 PRODUCTION PROFILE Q o 13 11/27/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BI' Exploration (Alaska) Inc. Alaska Data & Consulting Services Petiotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 I STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP RT OF SUNDRY WELL OPE~TIONS ~IAY 0 4 ~r. w 1 erformed: ~ias ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re Er~~~~nded 1Netl' ~'' ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Driil Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 179-104 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20422-00-00 7. KS Elevation (ft): 74 2' 9. Well Name and Number: PBU X-05' 8. Property Designation: 10. Field /Pool(s): ADL 028313 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11029' • feet true vertical 9543' feet Plugs (measured) None Effective depth: measured 10980' feet Junk (measured) None true vertical 9504' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2669' 13-3/8" 2669' 2669' 4930 2670 Intermediate 9845' 9-5/8" 9845' 8603' 8150 5080 Production Liner 1666' 7" 9361' - 11027' 8207' - 9541' 8160 7020 h +,Y~~iuXjJ lWb~~~ ' 1 I~! t'~I ~~ ~ (~ ~tkJ Perforation Depth MD (ft): 10026' -10305' Perforation Depth TVD (ft): 8752' - 8976' 4-1/2", 12.6# x 5-1/2", 17# 1 3Cr80 / L-80 9400' Tubing Size (size, grade, and measured depth): Y 4-1 /2" 1275# Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 9100'; 9-5/8" x 4-1/2" Baker'SAB`packer 9284' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut, pull and dress tubing to -9212'. Cut, pull and dress 9-5/8" casing to 1384'. Run 9-5/8" tieback (surface to 1389'). Cement w/ 100 Bbls Class 'G' field 1.1 .Run new Chrome tubin w/ overshot to 9224'. 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: Subsequent to operation: 754 11,311 4,472 1,700 380 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 NIA if C.O. Exempt: Contact Jovy Roach, 564-4352 309-022 Printed Name Terrie Hubble Title Drilling Technologist w ~(f Prepared ey Name/Number Signature Phone 564-4628 Date v ' Terris Hubble 564-4628 Form 10-404 Revised 04/ ®("~ ~ ~ ~ n f /1, ~ / Submit Original Only os • • X-05, Well History (Pre Rig Workover) Date Summary 01/26/09 WELL SHUT IN ON ARRIVAL. DRIFTED W/ 3.80" SWAGE TO WRP AT 9,288' SLM. PULLED 4-1/2" WRP FROM 9288' SLM. (missing part of one rubber sealing element.) DRIFTED W/ 3.64" CENT, 2.63" VyIRE GRAB TO 9600' SLM (nothing recovered). 01/27/09 T/I/0=450/560/40 Assist Slickline, Brush & Flush. Pumped into Tbg with 5 bbls meth and 100 bbls 190°F crude while Slickline brushed Tbg. FWHP's=100/560/340. Casing valves open to gauges. 01/27/09 BRUSH & FLUSH 5-1/2" TBG, 4-1/2" TBG & 7" LINER TO 9600' SLM. RAN 3.65" CENT /TEL /SAMPLE BAILER. LOCATE TBG TAIL @ 9372' SLM (+24' correction to elmd). TAG TD @ 10273' SLM (+24' correction= 10297' elm btm open pert @ 10227-10305' and 8' of covered perfsl• SAMPLE BAILER FULIs OF WHAT APPEARS TO BE FRAC SAND & FORMATION SAND. LEFT WELL S/I, TURNED WELL OVER TO PAD-OP. 01/27/09 WELL SI ON ARRIVAL. INITIAL T/I/O = 220/560/80. STANDBY UNIT TO RU ELINE. W/O HEATER. 01/29/09 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 200/500/0 PSI. PERFORMED CROSSFLOW DETERMINATION AT IBP SETTING DEPTH. NO CROSSFLOW OBSERVED,__ SET BAKER 3 3/8" IBP MID-ELEMENT AT 9493' IN THE MIDDLE OF THE THIRD FULL JOINT BELOW THE TBG TAIL. SURFACE AND VISUAL CONFIRMATION OF IBP SETTING. WELL Si ON DEPARTURE. FINAL T/I/O = 50/500/0 PSI. JOB COMPLETE. 02/03/09 WELLS/I ON ARRIVAL. LRS MIT T x IA, (PASSED) 0 PSI LOSS, T & IA 30 MIN TOTAL. SAT DOWN W/ 3.0" DUMP BAILER & 3.65" CENT @ 1' SLM (TBG HANGER AREA). MADE 2 RUNS W/ 4.0" GAUGE RING THEN 3.75" SWAGE, ABLE TO WORK THROUGH VERY TIGHT. 02/03/09 T/I/0= 300/720/0. Assist SL. CMIT TxIA "`PASS" to 2100 psi. Pumped 2 bbls neat spear followed by 12 bbls of 80° crude into IA to reach test pressure. TP pressure was 2100 psi. IA pressure 2500 psi. No loss on TxIA in 30 mins. Test was a pass as per SLPE. Bleed pressures back to normal. Bled back 12 bbls. Valve positions are as follows: SV, WV =closed. SSV, master, IA, and OA =open. FWHP = 280/700/0 02/04/09 RAN 3.61" SWAGE WORK TIGHT SPOT @ 20' SLM. RAN 3.50" CENT S/D 3' SLM. DRIFT W/ 3.75" SWAGE, BOBBLE THROUGH 17' SLM, TO SSSV @ 2207' MD, 02/05/09 MADE 3 RUNS W/ 3.00" DUMP BAILER, 3.6" SWAGE TO 9464' SLM, DUMP 6' SLUGGETS ON TOP OF IBP. SET 3.78" JUNK CATCHER @ 9366' MD (9344' SLM). SWAGE TUBING W/ 3.80" & 4.34" SWAGE @ 17' SLM. DRIFT TO 9249' SLM W/ 4.25" CENT, SAMPLE BAILER, (EMPTY ). WELL LEFT S/I ON DEPT. 02/13/09 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 350/750/0 SSV CLOSED ON ARRIVAL DUE TO A SLIGHT LEAK IN THE WING VALVE. HAD TO CLEAN AND REBUILD TOOL STRING ON LOCATION. CCL STOP DEPTH: 9218'. CCL TO CU: 12'. CUT DEPTH: 9230'. CUT 8' BELOW TOP OF FIRST FULL JOINT BELOW SLIDING SLEEVE PACKER. SSV CLOSED ON DEPARTURE. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 250/700/0 JOB COMPLETE. 02/24/09 T/I/0=350/700/40 Circ-Out Well CMIT TxIA PASSED to 3500 psi, MITOA PASSED to 2000 psi. Pumped 5 bbls meth, 970 bbls 115°F seawater, 3 bbls meth, 147 bbls 100°F diesel down Tbg, through cut, up IA, into X-07's flowline. U-Tubed TxIA for freeze protect. Freeze protected hardline with 10 bbls diesel. Pressured up TxIA with 9.5 bbls diesel for CMIT TxIA. T/IA lost 200/200 psi in the 1st 15 mins and 80/80 psi in the 2nd 15 mins for a total pressure loss of 280/280 psi in 30 min test. Bled TxIA to 0 psi. Pumped into OA with 1.1 bbls diesel to reach test pressure for MITOA. OA lost 120 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 160 psi in 30 min test. Bled WHP's to 0 psi. FWHP's = 0/0/0. Swab, Wing, Lateral, SSV =Shut. Master, IA, OA =open. Page 1 of 2 C~ • X-05, Well History (Pre Rig Workover) Date Summary 02/25/09 T/I/O=SSV/6/Vac. Temp=Sl. Monitor WHP's (secure). AL blinded C«3 casing valve. ALP=O+. IA has integral installed on IA companion valve. IAP increased 6 psi. OAP on a vac overnight. Called grease crew to open SSV, unable to open at this time. SV, WV, SSV =closed. MV =Open. IA, OA = OTG. NOVP. 02/26/09 T/I/O=Vac/6Nac. Temp=Sl. Assist Cameron w/ LDS drill out. Bled IAP from 6 psi to 0 psi in 10 min (all gas). Maintain open bleed on IA during LDS drill out. Final T/I/0=0/0/0. SV, WV =Closed. SV, MV = Open. IA, OA = OTG. NOVP. 02/26/09 T/I/O = 0+/6/vac. Monitor TBG pressure pre PPPOT. AL blinded C~ casing. ALP=O+. Integral installed on IA. Heater on location. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 03/05/09 T/IA/OA= 0/0/0 Temp=Sl LDS DRILL OUT. RU 1 HP BT onto IC test void 0 psi. Removed (3) broke pins, RU Drill onto wellhead, drilled out (1) LDS. RD drill installed blank, in all (3) broke pins holes. 03/05/09 T/I/O = 0/VAC/0. Temp = SI. Assist Cameron with LDS drill out. IA has integral installed. AL tine is SI & blinded C~3 casing valve. ALP = 0+ psi. Assisted Cameron w/LDS drill out. WV, SV =closed. SSV, MV = open. IA, OA = OTG. 03/06/09 T/IA/OA= 0/0/0 Temp=warm Second LDS drilled out, Cameron tree group assisted with removing OA annulis valve, for rigging up WACH drill. Drilled (3) LDS out. 03/06/09 T/I/0= VAC/0/0. Temp= SI. Assist Cameron w/ LDS drill-out. AL connected, blinded & shut-in C~ casing valve. ALP= 0 psi. Assist Cameron drilling -out and replacing LDS. SV, WV, ALC = C. SSV, MV = O. IA, OA = OTG. 03/06/09 T/I/O = 0/0/0 Removed O/A valve for drill out of lock down screw. Pput O/A valve back on PT pass. 03/07/09 T/IA/OA= 0/0/0 Temp=warm PPPOT-T (PASS) PPPOT-IC (PASS) PPPOT-T Pressure bled through slotted bleed screw verified 0 psi. Removed 1 " NPT plug, removed internal check, installed 1"Alemite. Cycle all LDS "Standard" all moved and were in good condition. RU HP BT onto THA flushed void until clean returns achieved. Pressured void to 5000 psi for 30 min, 5000/ 15 mins, 5000/ 30 mins. Bleed THA void to 0 psi, RD test equipment, re-installed Alemite cap. PPPOT-IC RU 1 HP BT onto IC test void 0 psi, drilled out (2) remaining broke pins. Total (3) pins removed (1) LDS C~ 12:00 position could not tap threads blank installed. Cycle all LDS "Standards" all moved and were in good condition. Flushed void until clean returns achieved, attempted to pressure to 3500 psi, would not build pressure above 1000 psi. RU elephant gun onto packing port, injecting plastic into packing port until air free ribbon of plastic achieved, pressured to 6200 psi, on packing port. (2nd test) Pressured to 3500 psi for 30 minutes, 3500/ 15 minutes, 3500/ 30 minutes. Bled off test pressure to 0 psi, RD all test equipment, re-installed Alemite cap. Job Complete. 03/07/09 T/I/0= VAC/0/0. Temp= SI. Assist Cameron w/ LDS drill-out. AL connected, blinded & shut-in Q casing valve, ALP = 0 psi. Assist Cameron drilling, out and replacing LDS. SV, WV, ALC = C. SSV, MV = O. IA, OA = OTG. 03/10/09 T/I/O = 0/0/0 Set 6 3/8" CIW J BPV Pre Rig. Page 2 of 2 BP EXPLORATION Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Start: 3/29/2009 Rig Release: 4/13/2009 Rig Number: Date From- To 'Hours Task Code NPT Phase 3/29/2009 04:00 - 00:00 20.00 MOB P 3/30/2009 00:00 - 09:30 9.50 RIGU P 09:30 - 10:30 1.00 WHSUR P 10:30 - 11:00 0.50 WHSUR P 11:00 - 12:00 1.00 WHSUR P 12:00 - 15:00 3.00 WHSUR P 15:00 - 19:00 4.00 WHSUR P 19:00 - 19:30 19:30 - 21:00 21:00 - 23:30 23:30 - 00:00 3/31 /2009 00:00 - 03:30 03:30 - 04:00 Page 1 of 10 ~ Spud Date: 1 /29/1980 End: 4/13/2009 Description of Operations PRE Move rig over to X-05, center the rig over the well, raise the derrick, and spot the pits. Prepare to start on X-05. PRE Accepted the rig x_00:00. Laid herculite and bermed the pits. Winds in excess of 20mph during this time. Install berms and walkways around all of the buildings and rig. Hook up all communication and electrical lines. DECOMP Pull BPV with DSM DECOMP Hold pre-spud meeting with Raymond Nix's crew DECOMP Install secondary annulus valve and hook up circulating lines to circulate out the freeze protect and to test the OA. DECOMP Spot LRS and riq up to pressure test the 13 3/8" x 9 5/8" DECOMP Install the TWC trouble J-ing into the hanger with the TWC. Pressure test the TWC from below, LRS pumped 15 bbls wi no pressure. Rig up the test pump to the tubing annulus any um 2 more bbls. Still no ressure. Line u the kill line to tubina annulus and pressure up to 300 psi on the TWC...not 0.50 WHSUR P DECOMP Rig up to reverse circulate out the crude from the tubing. 1.50 WHSUR P DECOMP Ria up DSM and test the lubricator to 1500 psi. Good Test. Pull the TWC and riq down DSM, 2.50 WHSUR P DECOMP Rig up to the top of the tree and reverse circulate out the crude from the tubing at 205 gpm @ 350 psi. Shut down and switch lines and pump diesel out of the backside at 245 gpm C~ 170 psi. 0.50 WHSUR P DECOMP Rig up DSM lubricator and test to 1500 psi. Good Test. Install the TWC. 3.50 WHSUR P DECOMP Attempt to test TWC from below to 1000 psi 2 times with loss of 180 psi each time. FIII up tree and test TWC from below a ain and monitor for a leak into the tree b o enin the need) valve on top, Not leaking past the TWO. Rig down DSM and attempt to test TWC from the top. Bad Test. 0.50 WHSUR N SFAL DECOMP Found valve on test um was leakin b , so we re laced it and aot a good test on the TWC from above to 3500 psi for 10 04:00 - 08:00 4.00 WHSUR P DECOMP Nipple down the tree and adaptor flange and prepare to nipple up the BOPE. 08:00 - 11:30 3.50 BOPSU P DECOMP Nipple up the BOP stack, install the riser, and mousehole. Adjust the turnbuckles and take RKB measurements. 11:30 - 12:00 0.50 BOPSU P DECOMP Pick up the BOP test joints, fill the stack, and hook up the test equipment. 12:00 - 16:30 4.50 BOPSU N SFAL DECOMP Perform a body test on the BOP stack. Test failed. Trouble shoot by testing the ROPE and HCR valves. Test failed. Body test the choke manifold. Test failed. Change out the chart recorder and then bod test BOPE. Good test 16:30 - 22:00 5.50 BOPSU P DECOMP All BOP tests were against the TWC. Test upper rams to 250 psi low/ 3500 psi high with 4" and 5 1/2" test jts. Good Tests. Test the Hydril to 250 psi low/ 2500 psi high with 4" and 5 1/2" test jts. Good Tests. Test the choke manifold and all other BOPE equipment to 250 psi low / 3500 psi high. Good tests. Hydraulic IBOP failed ok'd by AOGCC rep. Chuck Schieve to change out and test once tubing is out of the hole. Test witnessed by NAD Tool Pusher's Chris Page and Jon Castle Panted: 4/"LU/"LOOy 11:11:35 F'M ~ i BP EXPLORATION Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date ~ From - To Hours Task Code NPT - _ __ 3/31/2009 16:30 - 22:00 5.50 BOPSU P 22:00 - 23:00 I 1.001 BOPSURP 23:00 - 00:00 1.00 BOPSU P 4/1/2009 00:00 - 01:30 1.50 BOPSU P 01:30 - 02:30 1.00 PULL P 02:30 - 04:00 1.50 PULL P 04:00 - 05:30 1.50 PULL P 05:30 - 11:30 6.00 PULL P 11:30 - 20:30 9.00 PULL P I 20:30 - 22:00 1.50 PULL P ', 22:00 - 22:30 0.50 CLEAN P ', 22:30 - 00:00 1.50 BOPSU N SFAL 14/2/2009 00:00 - 00:30 0.50 BOPSU N SFAL 00:30 - 01:30 1.00 BOPSU P 01:30 - 04:30 3.00 BOPSU P 04:30 - 05:30 1.00 CLEAN P 05:30 - 08:00 2.50 CLEAN P Start: 3/29/2009 Rig Release: 4/13/2009 Rig Number: Page 2 of 10 ~ Spud Date: 1 /29/1980 End: 4/13/2009 Phase Description of Operations DECOMP and BP WSL's Matt Martyn and Chris Kobuck; also, by AOGCC rep. Chuck Scheve. DECOMP Rig down testing equipment and clean and clear the floor to pull tubing. DECOMP Ri u DSM lubricator and extension. DECOMP Test lubricator to 500 psi. Good test. Pull the TWC and rig down DSM. DECOMP Once TWC was pulled the well went on a vac. Pumped 35 bbls to fill u the hole and it stabilized: Monitor well. Static. DECOMP Make up the landing jt. and screw in the crossover to the hanger 6 turns. Loosen the lockdown screws and pull the hanger to the floor with 10k overpull. -Up Wt. 170k DECOMP Dis lace the well at 490 gpm @ 150 psi. Saw a small amount of diesel then cleaned up and began getting back rubber from the dual encapsulated control lines. Cleaned up once we pumped surface to surface. DECOMP Pull and la down 5 1/2" com letion from 9223' to 7001'. Recovered 23 clamps, 23 pins and 7 stainless steel bands. Rig down the control line spooler. Up wt. 170k /Down wt. 120k DECOMP Continue pulling 5 1/2" completion from 7001' to surface. Recovered 216 jts. with 1 SSSV, 5 Gas Lift Mandrels and 1 sliding sleeve. Cut joint was 8.19'. Most of the pipe was overed with black muck, which was the consistanc of tar. DECOMP Rig down the casing equipment and clean and clean the floor. DECOMP Pick up the baker tools to the rig floor for the 9 5/8" clean out assembly. DECOMP Change out the hydraulic IBOP. DECOMP Change out the hydraulic IBOP. DECOMP Service the top drive DECOMP Rig up and test the lower VBR and hydraulic IBOP to 250 psi low/ 3500 psi high for 10 minutes. Test failed, isolated all of the valves and still the pressure was still bleeding off. Filled the annulus back up and re-tested. Good test. Test witnessed by NAD tool pusher Ken Helf and BP WSL Chris Kobuck. Witness waived by AOGCC rep. Chuck Scheve. DECOMP Pull the test plug and run in the wear ring. DECOMP Pick up BHA and prepare to go in the hole with_ the 9 5/8" clean 08:00 - 12:00 4.00 CLEAN P DECOMP Run in hole from 330' to 3771' pumping a surface to surface every 1000'. Brought back significant amounts of black tar like substance. 12:00 - 14:00 2.00 CLEAN P DECOMP Run in hole from 3771' to 5973'. 14:00 - 14:30 0.50 CLEAN P DECOMP Pump a Hi-Vis sweep at 540 gpm C~ 1780 psi. Brought back more of the same black tar like substance that we saw earlier. 14:30 - 17:00 2.50 CLEAN P DECOMP Continue in the hole from 5973' to 9164'. 17:00 - 18:00 1.00 CLEAN P DECOMP Wash down from 9164' to the tubin stub at 9212'. Due to taggin debris ~ 9164' -Up Wt. 165k /Down Wt. 145k /Rot Wt. 160k -GPM 450 C 1820 psi -RPM 30 / TO 4k -Tagged the stub at 9212' 18:00 - 19:30 1.50 CLEAN P DECOMP Pump a Hi-Vis sweep at 500 gpm Q 2000 psi: Brought back Printed: 4/20/2009 12:11:39 PM BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Spud Date: 1/29/1980 Event Name: WORKOVER Start: 3/29/2009 End: 4/13/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/13/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 4/2/2009 18:00 - 19:30 1.50 CLEAN P DECOMP more of the same black tar substance from earlier. Monitor well. Static. Pump dry job and prepare to POH. 19:30 - 22:00 2.50 CLEAN P DECOMP Pull out of the hole from 9212' to 330'. 22:00 - 23:30 1.50 CLEAN P DECOMP Lay down the BHA and stand back the drill collars. The boot baskets were full of the black tar substance. 23:30 - 00:00 0.50 CLEAN P DECOMP Begin to make up the 9 5/8" Scraper BHA. 4/3/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Continue making up the 9 5/8" casing scraper to 347'. 01:00 - 02:30 1.50 CLEAN P DECOMP Run in the hole from 347' to 4589'. 02:30 - 03:00 0.50 CLEAN P DECOMP Circulated a bottoms up at 500 gpm C~ 720 psi. Saw a small amount of black tar substance. 03:00 - 04:30 1.50 CLEAN P DECOMP Run in the hole from 4589' to 8057'. Ciculate a Hi-Vis sweep C~? 500 gpm C~3 1200 psi. Saw an increase amount of the black tar substance. 04:30 - 06:00 1.50 CLEAN P DECOMP Ta ed stub C~ 9213', break circulation, and pumped a Hi-Vis sweep. 06:00 - 08:00 2.00 CLEAN P DECOMP Milled over stum down to 9,229' md. Stum at 9,214' md. 08:00 - 09:00 I 1.001 CLEAN I P 09:00 - 12:30 3.50 CLEAN P 12:30 - 13:30 1.00 CLEAN P 13:30 - 15:00 1.50 CLEAN P 15:00 - 17:00 2.00 EVAL P 17:00 - 00:00 7.00 EVAL P 4/4/2009 100:00 - 02:00 I 2.001 EVAL I P 02:00 - 04:30 I 2.501 EVAL I P 04:30 - 06:00 1.50 CLEAN P 06:00 - 06:30 0.50 CLEAN N 06:30 - 07:30 I 1.001 CLEAN I P 07:30 - 08:00 I 0.501 CLEAN I P 08:00 - 10:30 2.50 CLEAN P 10:30 - 13:00 2.50 CLEAN P -up wt 165k, Dn wt 145k, Rot 160k, RPM 80 -TO 5k, GPM 350 @ 1,700 psi DECOMP Circulate and condition. Pump Hi-Vis sweep C~1 540 GPM, 1,700 psi. Circulating sweep out of hole. DECOMP Pull out of hole from 9,214' and to 347' md. Change out elevators. DECOMP Lay down BHA, Standing back Drill Collars. Laying down Jars, Bumper sub, Scraper and wash pipe. DECOMP Laying down Baker tools down Beaver slide. Clean and clear rig floor. DECOMP Rig up for Logging Picking up SWS tools up Beaver slide. DECOMP Run in hole with SWS USIT/GR/CCL to 9,150' and to out of well. DECOMP Finish logging out of well with USIT/GR/CCL. RD SWS. Top Of Cement ~ 2,645 md. Top of Cement DECOMP Rig Up and Pressure test casing to 1,500 psi for 5 min. Good Test. Pressure u casin to 3 500 si for 30 minutes. Lost 120 si in for 15 minutes and 60 si in second 15 minutes. Good Test DECOMP RIH with RBP to 1,641 md'. Make Up top drive and circulate to warm up fluids. WAIT DECOMP Wait on decision on weather to set RBP at - 1,600' and or to run in below permafrost and set because of freezing issues. Circulating at 399 gpm with 270 psi. Decision made to set RBP below ermafrost. DECOMP Run in hole from 1,641' and to 2,491' md. Set RBP. To of RBP C~ 2,485' md. Rate 477 gpm with 430 psi. Up wt 62k, Down wt 65k. DECOMP Test RBP to 1,000 psi for 10 min. Good Test. Blow down Top Drive. DECOMP Pick up 1 stand and dumped 2,200 Ibs of sand on RBP. DECOMP Slip and cut 98' of Drilling Line. Service Draw works and Brakes. Service Top Drive. Printed: 4/20/2009 12:11:39 PM • BP EXPLORATION Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date II From - To ~' Nours I' Task Code NPT _ _ __ 4/4/2009 13:00 - 14:00 1.00 CLEAN P 14:00 - 15:30 ~ 1.50 ~ CLEAN ~ P 15:30 - 16:00 0.50 BOPSU P 16:00 - 17:30 1.50 BOPSU P 17:30 - 18:30 1.00 BOPSU P 18:30 - 20:00 1.50 BOPSU P 20:00 - 22:00 2.00 BOPSUF( P 22:00 - 23:00 1.00 BOPSU P 23:00 - 00:00 I 1.001 PULL I P 14/5/2009 100:00 - 02:30 I 2.501 PULL I P 02:30 - 03:30 I 1.001 PULL I P Start: 3129!2009 Rig Release: 4/13/2009 Rig Number: Page 4 of 10 Spud Date: 1/29/1980 End: 4/13/2009 Phase ', Description of Operations DECOMP Letting sand settle out on RBP. DECOMP Break Circulation and Displace 8.5 ppg Seawater to 9.8 ppg NaCI Brine. 250 gpm ~ 160 psi. DECOMP Pick Up 1 stand and tag top of sand ~ 2,432' md. Verify 53' of sand on top of RBP. Pull out of hole from 2,432' and and lay down RBP running tool. DECOMP Rig up and Pull Wear Bushing and Lay down. DECOMP Nipple down BOPE. DECOMP Remove Tubing Spool and remove from cellar. DECOMP NYipple Up Spacer Spool. Inspect well head. Replace 2 LDS with Blanks. Secure 9 5/8" Pack off. DECOMP Nipple Up BOPE. Install Riser, Turnbuckles and Mouse hole. DECOMP Test BOPE. Test Breaks with 250 psi low and 3,500 psi for 5 min each. -good tests. DECOMP Make Up BHA with Baker 8 1/4" Multi String cutter. Run in hole to 482' md. DECOMP Run In Hole with Baker 8 1/4" Multi String cutter from 482' and to 1,419' md. Pick up to 1,360' and Establish circulation at 240 gpm, 580 psi and open knives. Slack off to 1,404' and locating casing collar. Circulated down Hot 9.8 ppg NaCI brine. Picked up 20' to 1,384' md. Lay down single. Rig up to cuttings box. Up weight 45k, Down weight 45K 60 RPMS with 1 k free torque. DECOMP Engage 8 114" Multi-string cutter and cut 9 518" casing at 1,384' 189 gpm at 412 psi. RPM 58 with torque of 1500. Close Baq and establish circulation through 9 5/8" and 13 3/8" 03:30 - 06:30 I 3.001 PULL I P 06:30 - 08:00 ~ 1.50 ~ PULL ~ P 08:00 - 09:30 ~ 1.501 PULL ~ P 09:30 - 11:30 ~ 2.00 ~ PULL ~ P 11:30 - 13:00 1.50 ~ PULL P 13:00 - 21:00 8.00 ~ PULL ~ P 21:00 - 23:00 ~ 2.00 ~ PULL ~ P ~ 1100 psi 200 gpm DECOMP Rig up Little Red Services and Pressure test lines to 3,500 psi. Pumped 15 bbls of diesel. Closed Bag. Chased with 50 bbls of diesel. Wait for 30 min. Chase with 25 bbls of diesel and 30 bbls of Safe-Surf-O mixed in 9.8 ppg NaCI Brine. Circulate to clean 9.8 ppg NaCI Brine (HOT) DECOMP Pull out of hole with Baker 8 1/4" Multi String cutting BHA and Lay down. DECOMP Pick Up 9 5/8" Pack Off and Spear BHA. Engage Spear and Pull Free with 105K. Remove Emer en I' DECOMP Pull and Laydown Landing Joint and Spear assy. Install Head Pin and cross over. DECOMP Break circulation. Close Bag and circulate hole clean at 372 gpm with 1,005 psi. Take returns to cuttings box. Blowdown Top Drive. Rig down Head Pins and Lines. DECOMP Pull out of hole with 9 5/8" 47# L-80 casing from 1.384' md. Up weight 80k, Down Weight 80k. Average torq to break joints noted to be 25k. Lay down the following. -(1) 19' pup. -(34) Full Joints. -(1) Cut Joint at 20.19' DECOMP Clean and Clear rig floor. Cleaning Arctic Pac from floor. Printed: 4/20/2009 12:11:39 PM • BP EXPLORATION Operations Summary Report Page 5 of 10 ~ Legal Well Common W Event Nam Contractor Rig Name: Date ~, Name: ell Name: e: Name: From - To ~ X-05 X-05 WORKO NABOR NABORS Hours ~ VER S ALASK 2ES Task DRI Code Start LLING I Rig Rig NPT ~ Phase Spud Date: 1/29/1980 : 3/29/2009 End: 4/13/2009 Release: 4/13/2009 Number: Description of Operations 4/5/2009 23:00 - 00:00 1.00 CLEAN P DECOMP Pick up and Make up 13 3/8" Casing scraper with Dress off Mill BHA and Run in hole to 31' md. 4/6/2009 00:00 - 02:30 2.50 CLEAN P DECOMP Run in Hole with 13 3/8" Casin Scra er with Dr o BHA from 31' and to 1,384' md. Tag up on Stub at 1,384' md. 02:30 - 04:00 1.50 CLEAN P DECOMP Establish parameters and Dress off stub from 1,384' and down to 1,385' md'. -Up wt 67k, Down wt 67k, Rot wt 70k -Rate 200 gpm @ 110 psi. -Torq of 1.5k off bottom and 4-6k on @ 60 RPM 04:00 - 05:00 1.00 CLEAN P DECOMP Circulate a 30 bbl Safe-surf-o sweep and follow with 9.8 ppg NaCI Brine to clean up remaining arctic pack in the well. -460 gpm @ 400 psi. 05:00 - 08:00 3.00 CLEAN P DECOMP Pull out of hole with 13 3/8" Casing Scraper and Dress off Mill BHA. 08:00 - 09:30 1.50 CASE P TIE61 Rig up to run 9 5/8" 47# Hydril 563 casing. 09:30 - 12:30 3.00 CASE P TIEB1 Run in hole with 9 5/8" 47# Hydril 563 to 1384'. Baker-Lok all connections E ementer and below. orque turn all hydril connections to optimum make up torque of 15,800 ft/Ibs. MU butress connection to mark. Use BOL 2000 thread compound on BTC connection and Jet Lube Seal Guard on Hydril 563 connections. Consists of: -Bowen Casing Patch -Baker Type II Landing Collar -Baker ECP Packer -HES ES Cementer -35 Jts. of casing 12:30 - 14:00 1.50 CASE P TIEB1 Slack off and to 9 5/8" stub no rotation @ 1385'. Slack off 50k string weight and ull 10k over after workin atch over s u u test to 250k. Good Test. 14:00 - 15:00 1.00 CASE P TIEB1 Install the cement lines and Halliburton cement head. 15:00 - 16:00 1.00 CASE P TIEB1 Pressure test the casing patch to 1000 psi. Good Test. Increase the pressure to 1600 psi in 200 psi increments to Pressure back up to 1600 with 1/4 bbl brine. Continued the 16:00 - 17:30 1.50 CASE P TIE61 Brinkpump online at 2 bpm and shear open ES Cementer at 2850 si. Circulate well with hot 9.8 ppg brine at 6 bpm @ 250 psi. Initial temp 105 degF in, 70 degF out. Final temp out 83 DegF. PJSM with Dowell cementer while circulating. 17:30 - 19:30 2.00 CEMT P TIE61 Cement 9 5/8" Casin -Shut down circulation and drop ball to seat in landing collar and load HES cement plug into head. -Pump 5 bbls of fresh water to pressure test lines to 4000 psi. -Pump 100 bbls (518sks) of 15.8 ppg Tail cement with GasBlok -Shut down and drop closing plug -good indication on tattle tail of plug leaving. -Kick out Top plug with 5 bbls of fresh water from Schlumberger -Switch to rig pumps and displace cement with 94 bbls of 9.8 Printed: 4/20/2009 12:11:39 PM • • BP EXPLORATION Operations Summary Report Page 6 of 10 ~ Legal Well Name: X-05 Common Well Name: X-05 Spud Date: 1/29/1980 Event Name: WORKOVER Start: 3/29/2009 End: 4/13/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/13/2009 Rig Name: NABOBS 2ES Rig Number: Date ;From - To ~ Hours ~I Task 'Code N'PT Phase ~ Description of Operations 4/6/2009 17:30 - 19:30 2.00 CEMT P TIEB1 ppg Brine First 81 bbls at 5bpm ICP- 160 psi, FCP - 900 psi Slowed rate to 3 bpm for next 5 bbls then to 1 BPM for bump Final pressure prior to bump 450 psi. -Bump closing pluo at 1610 stks with 1600 psi. Saw indicato 19:30 - 21:00 I 1.501 CEMT I P 21:00 - 00:00 I 3.001 WHSUR I P 4/7/2009 100:00 - 02:00 I 2.001 WHSUR I P 02:00 - 04:30 I 2,501 BOPSUR P 04:30 - 08:30 I 4.001 BOPSUR P 09:30 -100:30 1.00 CLOEAN ~P 10:30 - 11:30 1.00 CLEAN P 11:30 - 17:30 6.00 CLEAN P - Pressured up to 1800 psi and held pressure for 2 minutes and then bleed off -Checked for flow back. No flow -20 bbls of cement to surface. TIEB1 Blow down all the cementing lines and rig down cementing equipment. TIEB1 Nipple down the BOPE, Break out the spacer spool, slack off 100k to set the emergency slips. Cut the 9 5/8" with a Wachs Cutter. -Cut Jt. (#35) had 24.24' cut off making 13.49' left in the hole. TIEB1 Remove the spacer spool from the cellar and replace with a new tubing spool and then nipple it up. DECOMP Nipple up the BOPE and test the breaks to 250 si / 3500 si. 0o est. repare to test the BOPE. DECOMP Install test plug and test the Upper and lower rams with the 4" and 4.5" test joints to 250 psi / 3500 psi for 5 minutes and chart. Test the Annular to 250 psi / 2500 psi for 5 minutes and chart, with the 4" test joint. Test all other BOPE to 250 psi / 3500 psi. All tests passed and charted. Witnessed by BP WSL Chris Kobuck and NAD Tool Pusher Ken Helf. Witness waived by AOGCC reps. Lou Grimaldi and Bob Noble. DECOMP ND BOPE testing equipment. DECOMP PU BNA #6 cement cleanout 8-1/2" bit, boot baskets, float, jar, DC's) to 320'. DECOMP RIH from 320' to 1259'. DECOMP RIH to TOC at 1343'. Establish drilling parameters. ROT - 70 RPM, TO - 1 k off / 2 to 4k on btm. Circulate 311 gpm ~ 350 psi. Drill cement shoe tract from 1343' to baffle at 1379'. 17:30 - 18:00 0.50 CLEAN P DECOMP RIH from 1379' to 2437', and tag sand. PU - 80k, SO - 80k. 18:00 - 19:00 1.00 CLEAN P DECOMP Dry drill junk on top of sand. RPM - 70, TO - 1 to 4k on / 1 k off btm. 19:00 - 20:00 1.00 CLEAN P DECOMP Displace well to 8.5 ppg seawater at 500 gpm, 850 psi. 20:00 - 20:30 0.50 CLEAN P DECOMP POH from 2437' to 320'. 20:30 - 21:30 1.00 CLEAN P DECOMP LD BHA #6 from 320'. 21:30 - 22:30 1.00 CASE P DECOMP Close blind rams and test 9-5/8" casin to 3500 i for 30 minutes - ood test. Lost 0 psi in 30 minutes. Bleed down casing. 22:30 - 23:30 1.00 CLEAN P DECOMP MU BHA #7 (Casing scraper and boot basket; 7-7/8" RCJB, 9-5/8" casing scraper, boot baskets, jar, DC's, circ sub) to 332'. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH from 332' to 1271'. X4/8/2009 00:00 - 01:00 01:00 - 01:30 1.00 0.50 CLEAN CLEAN P P DECOMP DECOMP RIH from 1271' to 2437. Mill junk on top of sand at 2437'. Mill down to 2443'. Printed: 4/20/2009 12:11:39 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Spud Date: 1/29/1980 Event Name: WORKOVER Start: 3/29/2009 End: 4/13/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/13/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ Hours ', Task Code NPT Phase Description of Operations 4/8/2009 101:30 - 02:00 I 0.501 CLEAN I P 02:00 - 02:30 I 0.501 CLEAN I P 02:30 - 03:30 1.00 CLEAN P 03:30 - 05:30 2.00 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30- 07:00 0.50 CLEAN P 07:00 - 10:00 3.00 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 12:00 1.50 CLEAN P 12:00 - 14:00 2.00 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 17:30 ~ 2.50 ~ CLEAN ~ P 17:30 - 21:00 3.50 CLEAN P 21:00 - 23:30 2.50 CLEAN P 23:30 - 00:00 ~ 0.50 ~ CLEAN P DECOMP CBU at 300 gpm, 1600 psi. Get sand returns and small bits of aluminum. DECOMP Dry drill junk on top of sand to 2447'. CBU at 300 gpm, 1600 psi. Get sand returns and small bits of aluminum. DECOMP POH from 2447' to 332'. DECOMP LD BHA #7 (RCJB, casing scraper) from 332'. Clean out RCJB. No junk present in RCJB. DECOMP MU RBP retrieval BHA to 80'. DECOMP RIH from 80' to 2451'. DECOMP Wash down to 2484' at 550 gpm, 660 psi. PU - 65k, SO - 65k. CBU. Latch onto RBP and release. DECOMP POH from 2484' to 80'. Pulled slow due to overpulls every 42'. DECOMP LD RBP retrieval tool and RBP from 80'. DECOMP LD 3 stands of drill collars. DECOMP PU BHA tools up slide. Clean rig floor. DECOMP Safety Standown with BP Drilling Management (Forman and Schultz). DECOMP PU BHA #8 (Junk Basket cleanout; saw tooth shoe, cut lip guide, pac pipe, jar, circ sub) to 212'. DECOMP RIH fro~to 9183'. DECOMP RIH from 9183' to 9200'. Close annular preventer and strip in to 9212', good indication of shear at tubing stub. Continue to strip in and reverse circulate to 9337'. Scale junk returns coming across shakers. Circulate at 300 gpm, 1850 psi. PU - 155k, SO - 135k. DECOMP H2S high level alarm - 25 ppm registered in pits. Rig rig w/air monitors -all clear. '..4/9/2009 00:00 - 00:30 0.50 ~ CLEAN ~ P 00:30 - 01:30 1.001 CLEAN ~ P 01:30 - 02:30 1.001 CLEAN ~ P 02:30 - 03:30 I 1.001 CLEAN I P 03:30 - 07:00 3.50 CLEAN P 07:00 - 09:30 2.50 CLEAN P check Line up to take returns thru the gas buster and begin circulating out at 3 bpm, 450 psi. DECOMP Continue to circulate at 3bpm, 450 psi thru gas buster. No further indications of H2S. DECOMP Continue to reverse circulate and RIH from 9337' to 9344'. PU to 9338' -stuck. Cannot move up or down. DECOMP Overpull 50k to 75k, 35 , an far unti rillstring is loose. Overpull 100k after 75k jar to pull ree. RIH to 9344', PU to 9336'. No further indication of obstruction. DECOMP Reverse circulate down to 9398'. No indication of junk basket in tubing tail. DECOMP POH from 9398' to 212'. DECOMP Lay down BHA #8 (junk basket cleanout) from 212'. Clean and clear ng noor. 09:30 - 10:00 0.50 CLEAN P DECOMP Wait on SWS E-line unit. 10:00 - 11:00 1.00 CLEAN P DECOMP RU E-line unit. 11:00 - 13:30 2.50 CLEAN P DECOMP RIH with a-line, evaluate hole, and tag on junk catcher at 9476' ELMD. POH. 13:30 - 14:30 1.00 CLEAN P DECOMP RD E-line unit. 14:30 - 18:00 3.50 CLEAN P DECOMP Wait for SWS slickline unit. 18:00 - 20:30 2.50 CLEAN P DECOMP PJSM. Spot and RU SWS unit. 20:30 - 22:30 2.00 CLEAN P DECOMP RIH with GS retrieval tool and attempt to latch with junk catcher - unsuccess u , posse a sunk in fishing neck. POH. Printed: 4/20/2009 12:11:39 PM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Spud Date: 1/29/1980 Event Name: WORKOVER Start: 3/29/2009 End: 4/13/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/13/2009 Rig Name: NABORS 2ES Rig Number: Date. From - To Hours Task Code NPT Phase Description of Operations 4/9/2009 20:30 - 22:30 2.00 CLEAN P DECOMP 22:30 - 00:00 1.50 CLEAN P 4/10/2009 00:00 - 01:30 1.50 FISH P 01:30 - 03:00 1.50 FISH P 03:00 - 05:00 2.00 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 07:30 f 1.501 FISH I P 07:30 - 10:30 3.00 FISH P 10:30 - 13:00 2.50 FISH P 13:00 - 15:00 2.00 FISH P 15:00 - 17:00 2.00 FISH P 17:00 - 18:30 1.50 FISH P 18:30 - 22:00 3.50 FISH P 22:00 - 00:00 2.00 FISH P 4/11/2009 00:00 - 01:00 1.00 FISH P 01:00 - 02:00 1.00 FISH P 02:00 - 02:30 0.50 FISH P 2 small pieces of aluminum trapped in spangs, - 1" x 1"x 1116". DECOMP RIH with 2-1/4" slickline bailer to 5-1/2" tubin stub -unable to stab in. POH. DECOMP RIH SWS with 3-1/2" bailer to top of junk catcher at 9780' SLMD. Bail junk and POH. Bailer -98% full of asphaltenes with some small pieces of cement and aluminum mix d in. DECOMP RIH SWS with 3-1/2" bailer to top of junk catcher at 9780' SLMD. Bail junk and POH. Small pieces of control line, -1" x 1" x 1/4" aluminum chunks (2), cement chunks, and a 3" section of a 6" BJ -USA tong die recovered along with asphaltenes. This die type is not used on the rig, extensive pitting present. DECOMP RIH SWS with 3-1/2" bailer to top of 4-1/2" tubing stub. Would not stab in. POH. DECOMP RIH SWS with GR (shear's up) retrieval tool and attempt to latch. POH, hang up at XN nipple. Jar, unable to come free. Shear GR tool and POH. RU to RIH with GS (shear's down) retrieval tool DECOMP RIH SWS with GS retrieval tool, an~ull fish from XN nipple. DECOMP with Lead Impression Block (LIB). POH. Body of junk catcher still on top of sluggits at 9462'. DECOMP S with 3.03" grapple. Attempt to engage fish - unsuccessful. POH. DECOMP RIH SWS with 2.928" grapple #2. Attempt to engage fish - unsuccessful. POH. DECOMP RIH SWS grapple #2 with knuckle joints removed. Attempt to engage fish -unsuccessful. POH. DECOMP RD SWS. DECOMP MU BHA #9 (Junk catcher fishing assembly; spear, cutlip guide, 2-7/8" PAC pipe, 4-3/4" DC's, jar, bumper sub, circ sub) to 489'. DECOMP RIH from 489' to 6626'. DECOMP RIH from 6626' to 9148'. DECOMP RIH to 9213'. Good indication of guide lip shearing on 5-1/2" tubing stub. Establish parameters. PU - 155k, SO - 135k, 120 gpm @ 675 psi. RIH to 9463' and to RIH 2' more (9465') and SO 10k. Pressure increased to 850 psi. SO weight dropped to 0. RIH 2' more (9467'), SO weight 10k. Pressure slowly dropped back to 675 psi. PU - 155k, SO - 135k. Turn to the left and SO multiple times. Tag at 9467' each time. DECOMP POH to 9340'. Over ull 25k on bottom of XN lu .Jar up 2x at 30k and come free. POH to 9330'. RIH to 9337' and tag XN plug. Printed: 4/20/2009 12:11:39 PM • BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Name: X-05 Common W ell Name: X-05 Spud Date: 1/29/1980 Event Nam e:. WORKOVER Start : 3/29/2009 End: 4/13/2009 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 4/13/2009 Rig Name: NABOBS 2ES Rig Number: I C ~ ti ti f O D i Date From - To Hours Task ode NPT Phase ons on o pera escr p I 4/11/2009 02:30 - 06:00 3.50 FISH P DECOMP POH from 9337' to 489'. 06:00 - 09:00 3.00 FISH P DECOMP LD BHA #9 from 489'. Recover'unk basket fish and LD. 09:00 - 10:30 1.50 FISH P DECOMP lean and clear rig floor. 10:30 - 14:00 3.50 FISH P DECOMP RIH with DP to 9131'. 14:00 - 15:00 1.00 FISH P DECOMP CBU at 464 gpm, 1500 psi. 15:00 - 17:00 2.00 FISH P DECOMP Slip and cut drilling line. Service top drive, drawworks and crown. Adjust brakes. 17:00 - 00:00 7.00 FISH P DECOMP LD drillpipe from 9131' to surface. 4/12/2009 00:00 - 03:30 3.50 BUNCO P RUNCMP RU to run 4-1/2" completion. PJSM. 03:30 - 19:30 16.00 BUNCO RUNCMP RIH with 4-1/2" completion to 9231'. Connections torque turne to 44 - s. et u e eal Guard used on all connections. Baker-Lok used on all connections below packer and the connection above. PU - 125k, SO - 115k. Swallow stub at 9217' tubing MD (9213' drillpipe MD). Shear #1 on overshot at 9221' with 12k weight. Shear #2 on overshot at 9229' with 12k weight. Stack out on stub at 9231' with 20k weight. PU and space-out with three pup joints. Tubin stub 7 stun feet inside 14 feet overall swallow of overshot. 19:30 - 20:00 0.50 BUNCO P RUNCMP RD tubing running equipment. 20:00 - 21:00 1.00 BUNCO P RUNCMP MU landing joint and XO to tubing hanger. Land tubing hanger and RILDS. LD landing joint. 21:00 - 00:00 3.001 RUN 4/13/2009 100:00 - 01:00 l 1.00 01:00 - 02:30 I 1.501 RUN Overshot at 9224' MD. RUNCMP Reverse circulate 140 bbls seawater, 307 bbls seawater with corrosion inhibitor, 186 bbls seawater. Rate - 3 bpm @ 650 psi. RUNCMP Finish reverse circulating 140 bbls seawater, 307 bbls seawater with corrosion inhibitor, 186 bbls seawater. Rate - 3 bpm @ 650 psi. RUNCMP Drop ball and rod. Pressure up tubino to 3500 Dsi and hold for 30 minutes. Packer set during pressure up. 1st 15 min -lost 50 psi, 2nd 15 min -lost 40 psi. Bleed off tubing pressure to 1700 Dsi. Pressure up 9-5/8" x 4-1/2" annulus to 3500 psi minutes. 1st 15 min -lost 25 Dsi. 2nd 15 min - 02:30 - 03:00 I 0.50 03:00 - 05:00 2.00 BOPSUF~P 05:00 - 08:30 3.50 WHSUR P 08:30 - 09:30 1.00 ~ WHSUR P Bleed annulus then tubing down to 0 psi. RUNCMP Pressure up annulus to 2600 psi to shear DCR valve, good indication of shear. Pump thru annulus into tubing - 3 bpm @ 360 psi. Pump thru tubing into annulus - 3 bpm ~ 330 psi. RUNCMP Install TWC. Pressure test from below to 1000 psi. ND BOP RUNCMP NU Tree. Pressure test adapter flange to 5000 psi for 30 minutes -good test. Pressure test tree to 5000 psi for 10 minutes -good test. RUNCMP RU DSM, remove TWC. RD DSM. Printed: 4/20/2009 12:11:39 PM • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: X-05 Common Well Name: X-05 Spud Date: 1/29/1980 Event Name: WORKOVER Start: 3/29/2009 End: 4/13/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/13/2009 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task I Code ~~ NPT Phase ~ Description of Operations 4/13/2009 09:30 - 15:30 6.00 WHSUR P RUNCMP RU LRS. Pump 151 bbls diesel freeze protect at 2 bpm, 300 psi. Allow diesel to U-tube. 15:30 - 18:00 2.50 WHSUR P RUNCMP RU DSM. Install BPV and test from below to 1000 si for 10 minutes - oood test. RD DSM and LRS. Secure well. released at 18:00. Printed: 4/20/2009 12:11:39 PM X-05, Well History (Post Rig Workover) Date Summary 04/23/09 WELL SI ON ARRIVAL. PULL B&R FROM 9,115' SLM. PULLED RK-DGLV STA3 @ 6,195' SLM, RK- DCR FROM STA4 Q 3,475' SLM. SET RK-LGLV STA4 ~ 3475' SLM (PORT 16/64" TRO 1500#), RK- OGLV IN STA3 C«3 6195' SLM (PORT 20/64"). PULLED 4 1/2" RHC FROM 9117' SLM. 04/24/09 MULTIPLE BAILER RUNS, 1.5 GAL. SLUGGITS /FILL RECOVERED. RAN TEL, 3.25" LIB, LOCATE TT C~3 9,373' SLM (9,396' ELMD,= 23' CORRECTION), NO IMPRESSION. 04/25/09 RAN TEL, 3.50 LIB, TAG TT C~ 9,373' SLM (23' correction 9,396' ELMD), TAG FILL C 9,481' ELMD. MADE SEVERAL RUNS W/ 3.50" x 10' P. BAILER, REC. -8-1/2 GALL. OF SLUGGITS /FILL. 04/26/09 RAN 3.50 MAGNET TO 9,463' SLM (NO RECOVERY). LOC. TT Q 9,377' SLM, 23' CORRECTION FROM 9,400' ELMD, TAG FILL ~ 9467' SLM. MADE MULTIPLE RUNS W/ 3.00" x 10' P.BAILR, REC. -3-1/2 GALLONS OF FILL /SLUGGITS. 04/27/09 RAN MULTIPLE BAILER RUNS,- 3 CUPS OF SAND / SLUGGITS RECOVERED. EO. & PULL BAKER 3-3/8" IBP. RECOVER 2 x 6" SEALING ELEMENTS & 1"STIFFENER RING. DRIFTED TO 10,276' SLM W/ 4-1/2" BRUSH & 3.70" WIRE GRAB NO PROBLEMS. 04/28/09 RIG DOWN SWCP #2, AFTER COMPLETING POST RWO. WELL S/I ON DEP., PAD OP NOTIFIED. Page 1 of 1 TREE= ~ 4-1/16" CM! WEL EAD= M~C.EVOY ACT TOItA R = BAKER KB. ELEV - 71.26' BF ELEV = 40.28' KOP = 3100' Max Angle = 40 @ 6900' Datum MD = 10180' Datum TVD = 8800' SS 4 ~ ' a ®.. 9-5/8" TIEBACK CSG, 47#, L-80, ID = 8.835" ~1 1388' fi Est TOC behind 9-5/8" csg _ 2173 13-3/8" CSG, 72#, L-80, ID = 12.347" 2669' Minimum ID = 3.725" @ 9366' 4-1 /2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13CR80, ID = 3.958" 9208' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9284' TOP OF 4-1/2" TBG ~$4' TOP OF 7" LNR I~ 9361' TBG TP, 12.75#, CS HYDRIL, ID = 3.958" ~-{ 9400' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9845' PERFORATION SUMMARY REF LOG: SWS - BHCS ON 02/15/80 ANGLE AT TOP PERF: 34 @ 10026' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10026 - 10050 Q 04/08/88 2-7/8" 4 10146 - 10148 S 03/20/88 3-1/8" 4 10148 - 10175 ~ 04/08/88 3-1/8" 4 10185 - 10217 ® 04/08/88 3-1/8" 4 10227 - 10305 © 04/08/88 2-7/8" 4 10317 - 10336 S 03/20/88 PBTD 10980' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11027' SA~NOTES: 3.750 O junk catcher was pus rou and retrieved through N-lF~ at X ~O ~ g9'a3p{~~6°p6'~'rydufryig~ jR1(NJ~~D(aoperations - Apr0 SO t~A l.elY1 S'V TV VRI-~Hi.tE 1319' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1347' HES 9-5/8" ES Cementer 1385' Baker 9-5/8" x 13-3/8" ECP Packer 1385' Bowen Casing Patch connection 2208' 4-1/2" HES X-NIP, ID = 3.813" 2571' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 4 3490 3475 19 MMG DCK RKP 0 04/12/09 3 6203 5701 38 MMG DMY RK 0 04/12/09 2 7996 7106 38 MMG DMY RK 0 04/12/09 1 8990 7905 35 MMG DMY RK 0 04/12/09 9069' HES X-NIP, ID = 3.813" 9100' 9-5/8x4-1/2 Baker S-3 PKR 9135' HES X-NIP, ID = 3.813" 9208' 5-1/2" x 4-1/2" XO, ID = 3.958" 9209' Top of Unique Overshot Assy 9217' 5.5" 17# TUBING STUB 9265' BKR. PBR SEAL ASSY 9284' 9-5/8" x 4-1/2" BKR SAB PKR, ID = 3.813" 9334' 4-1/2" OTIS X NIP, ID = 3.813" 9366' 4-1/2" OTIS XN NIP, ID = 3.725" See Safety Note Above 9400' 4-1/2" TBG TAIL ID = 3.958" 9396' ELMD TT LOGGED 04/25/90 10158' H MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 02/24/80 ORIGINAL COMPLETION 04/13/09 N2 ES RWO 04/20/09 TLH CORRECTIONS PRUDHOE BAY UNIT WELL: X-05 PERMff No: 1791040 API No: 50-029-20422-00 SEC 6, T11 N, R14E, 5220' FWEL & 363' FSNL BP Exploration (Alaska) H2S Alarm on 2ES Page 1 of 1 Maunder, Thomas E (DOA) From: Roach, Jovy [Jovy.Roach@bp.com] Sent: Thursday, April 09, 2009 3:00 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 2es Subject: H2S Alarm on 2ES Tom, I just wanted to let you know that we had an H2S alarm on 2ES last night. It was at 1140pm, and it was the high level alarm in the pits, at 25 ppm. The rig was evacuated, and the area was checked with air monitors before re- entering. The rig is currently doing a workover on X-05. Lou Grimaldi has been notified. Let me know if you need any further information. Thanks, Jovy 6/5/2009 04/27/09 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh s NO. Company: State of Alaska - i~;~; ~ Rv ,-, Alaska Oil & Gas Cons Comm =-~ 't- ~~ 0~ =~ ~-'-' ~ ~ ~~~ ~ ~ R' ~ ~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... n,. ...:.. F-45A AP3O-00033 ---- - - RST GRAVEL PACK LOG 04/17/09 1 V~v1 VU 1 P2-07 AVYO-00023 PRODUCTION PROFILE a ~ 04/05/09 1 1 11-12 AYQO-00019 USIT L - 5 ~ 04/19/09 1 1 X-05 AYTO-00010 USIT Aj ~ 04/03/09 f 1 X-01 A24D-00012 PRODUCTION PROFILE - (' 03/18/09 1 1 Z-21A AP3O-00022 RST ~" 02/24/09 1 1 E-34L1 AYTU-00010 OH LDWG EDIT (IFLEX) 02/08/09 1 1 L-106 22026 OH LDWG EDIT (REDO) 01/10/02 1 MPF-96 09AKA0039 OH MWD/LWD EDIT ~ 02/23/09 2 1 F-19A 40018664 OH MWD/LWD EDIT 02/14/09 2 1 F-i8A 09AKA0034 OH MWD/LWD EDIT 03/16/09 2 1 06-23C 12066550 MCNL ~ 09/14/08 1 1 03-146 BIJJ-00005 MCNL - 03/30/09 1 1 11-18 BOCV-00006 RST --ll 1 03/02/09 1 1 07-206 AWJB-00028 MCNL ~ 02/27/09 1 1 MPB-22A AXBD-00005 CH EDIT PDC-GR (CBL) 12/23/08 1 07-29D AXBD-00016 MCNL '~ ~ Ly 03/17/09 1 1 09-33A AWJI-00019 MCNL - 04/01/09 1 1 of C111+C A/-Vwln\1111 Cn/+C n BP Exploration (Alaska) Inc. _ ~ ^ v.'.-...M v,.~ vv.. ~^v„ 'v. Petrotechnical Data Center LR2-1 ",` 900 E. Benson Blvd. ' Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: s r1' -,~ 04/14/09 ~chl~mher~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~,~~ ~ti~et=:- N0.5188 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wall i..h ~ ~._._ i. i ;r*1 ,r~«'c W-18 11968978 RST _~ uare 12/22/08 CL 1 GOIOr CD 1 07-026 AXED-00013 MCNL - 02/12/09 1 1 K-05C AWJB-00016 MCNL ~ ~l 12/30/08 1 1 F-18A AYLF-00020 CEMENT IMAGE LOG ~ ~- 03/19/09 1 1 J-09A AP3O-00024 STP CROSS FLOW CHECK L ~ ~ ~ 03/25/09 1 1 X-05 AYTO-00014 PFCS CALIPER LOG f _ C 04/09/09 1 1 O-04A AYTU-00023 LDL & PLUG SET j95 - ~~ 04/02/09 1 1 04-40 AYTU-00025 USIT g ~ ~- 04/10/09 1 1 06-14B AVYO-00021 SCMT _ 04/01/09 1 1 Z-01 B AVYO-00025 INJECTION PROFILE -- /O ~ 04/11/09 1 1 L3-15 AYTU-00023 _ _" _ PRODUCTION PROFILE ~ ` 04/06/09 1 1 11-30 AXED-00021 MEM PROD PROFILE ( c~ _ °~-~ 04/14/09 1 1 3-03/J-33 AZ40-OOOf3 RST W/INJ PROFILE ~' - ~a 04/05/09 1 1 3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE - ( ~) 04/03/09 1 1 3-49A/M-40 AXBD-00019 MEM INJECTION PROFILE: 04/07/09 1 f V-114A Fes- U ~`- AVY500032 INJECTION PROFILE ~ j~~L~ 04/02/09 1 1 L -- 1° U I THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 518, E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) j _~'.~- ~-~9 01/14/09 1 f MPS-43 AXML-00020 OH LDWG EDIT 12/29/08 2 1 PLEASE ACKNOWLEDGE RE CEIPT av clrw nlr_ earn ~cTUODUUU± nr.~~ ~,~.. ~...,, ..,._ ~. ~ t:..b n,.r .__ _ _ BP Exploration (Alaska) Inc. ---,""" Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 838 ATTN: Beth Received by:__ • From: Maunder, Thomas E (DOA) Sent: Wednesday, February 25, 2009 2:30 PM To: 'Roach, Jovy' Cc: Hobbs, Greg S (ANC) Subject: RE: X-05 (179-104) RWO sundry addendum request Jovy, This should not be an issue. One adjective tha# should be included with the barrier description is "tested". I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Roach, Jovy [mailto:Jovy.Roach@bp.com] Sent: Wednesday, February 25, 2009 11:58 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: X-05 RWO sundry addendum request Tom, On our upcoming X-05 RWO, I would like to request that we will not swap pipe rams to accommodate 9-5/8" casing, as we will have 2 barriers while we do the 9-5/8 prod casing cut and pull. The barriers will be the IBP in the 7" liner tail and an RBP at ~ 2200' in the 9-5/8" casing. I apologize for not requesting this in the sundry. I have attached a current schematic for reference. «X-05 current Z-9-09.pdf» Thanks, Jovy ~ ~ K~~~~, r, ~~~ F~ Z~G~f .'~., 1. p.4,k- r 2/25/2009 TREE = 6" CIW VVELLHEAD= „,~ MCEVOY mm ACTUAT_GR= KtJ. ELEV = OTIS 74.18' BF. ELEV - ~~ 40.28' KUP = 3100' Max Angle = 40 @ 6900' Datum MD = 10180' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2669' Itl11YtUC11 Od = 3,~ZJa: ~ ~~~~' 4°7lLee TIS XN ~~PP~E 0 5-1f2" TBG; 17#; L-80, .0232 bpf, iD = 4.892" I--{ X2$4' 7OP OF 7" LNR ~-{ 9361' 1r2" TBG TP, 12.7Ei#, CS HYDRIL; ID = 3.958" ~-~ 9400' 9-518" CSG, 47#, SOO-95, BTC, ID = 8.681" (-{ x$45' PERFORATION SUME~IARY REF LOG: SWS - BHCS ON 02?15180 ANGLE AT TOP PERF: 34 @ 10026` Note: Refer to Production DB far historicaf perf data SIZE SPF INTERVAL Opn(Sgz DATE 3-118" 4 10026 - 10050 C 04!08!88 2-7!8" 4 10146 - 10148 S 03t20188 3-1'8" 4 10148 - 10175 (~ 04108!88 3-1 `8" 4 10185 - 10217 t:, 04/08188 3-1 8° 4 10227-10305 C 04/08188 2-7r8" 4 10317 - 10336 S 03120188 PBTD 10$70' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11027' SA NOTES: f_~ ~ .2207' ~-~5-1/2'° CAMCO SSSV LAND. NIP, ID = 4.562„ '~/ 2571' 9-58" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 5 2994 2993 8 CAM DMY RK fl 11124105 4** 3 5314 7812 4996 6961 37 38 CAM CARA DOME DMY **NONE RK 20 0 11/24/05 2 1 8866 9102 7803 7996 36 35 CAM CAM DMY DMY RK RK 0 0 11/24/05 ", I ~F4 HAS t3Kt?KtIV LA 1 L:t1 {UtSJUFS!`J3) 9213' 5-112" CAM SLIDING SLEEVE DB-1, ID = 4.437" I I 9230' JET CUT (02t13f09} 9265' BKR. PBR SEAL ASSY 9284' 9-518" x 4-112" BKR SAB PKR, ID = 3.813" 9334' 4-112" OT1S X NIP, ID = 3.813" 9356° JUNK CATCHER (02!05!09} ~ 9361' 9-518" BKR LNR HGR 9366° 4-112" OT15 XN NIP, ID = 3.725" 9399' BKR SHEAR SUB 9400' 4-112" TBG TAIL ID = 3.958„ ' ELMD TT LOGGED 04/2590 9396 94$7' TOP OF SLUGGITS (02f05.'09}~ 9493' 3-318'° BKR IBP (01129!09) }-~FISN: WRP RUBBER ELEMENT(01126,j09} 1015$' MARKER JOINT DATE REV BY COMI49ENTS DATE REV BY COMMENTS 02/24!$0 ORIGINAL COMPLETION 02?15!09 RRD/SV JET CUT (02l13t09) 07113102 JCIKAK PERF CORRECTIONS 12102105 KSB?TLH GLV C1O (11124/05} 06117106 DAV/TLH GORREGTIONS 02i05f09 JKDiSV SET BKR IBP @9493' (01129!09} 02i09f09 KDGISV SLUGGITSr`SET JNK CTCHR (02105;09} PRUDHOE BAY UNET 4NELL: Xt?5 PERMIT No: 1791040 API No: 50-029-20422-00 SEC 6, T11N, R14E, 5220' FWEL 8 363' FSNL BP Exploration (Alaska} • ALASSA OIL A1~TD GAS COI~TSERQATIOI~T CO1~II~IISSIOI~T • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. ~ ,,~ ~`~~~~~,, ~~ ~~ ~ 4 P.O. Box 196612 ~~~` Anchorage, Alaska 99519-6612 `- 1~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, X-05 Sundry Number: 309-022 Dear Mr. Hobbs 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90?) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~- .. %' i ~~ / ~ `~ ~, f Daniel T. Seamount, Jr. _ , i Chair ~~ ~, ~ -1~ DATED this'-~ day of January, 2009 Encl. ,fl°~ ,~ ~~ (~ b STATE OF ALASKA ~' ,~-~-'emu;,,; ~~'';~~ ~ °~3 ~ ` ~ A~ OIL AND GAS CONSERVATION CO~SION JAN 2 2 20x9 APPLICATION FOR SUNDRY APPROVAL /~~ 20 AAC 25.280 A(a~lra ~~r ~ r,.- ,. 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time 1~~~ i?lISS10R ®Alter Casing - - ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program - ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ' ^ Exploratory 179-104' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20422-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU X-05 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028313 ~ 74.2' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 11029' 9543' 10980' 9504' 9315' None si n h i TV I tructu al 1 " I 1 rf 1 /8" 9' 4 67 r i 4' /" 4' 1 5 in r 166 ' 7" 1' - 11 7' 7' - 41' 1 7 Perforation Depth MD (ft): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (ft): 10026' - 10305' 8752' - 8976' 5-1/2", 17# x 4-1/2", 12.75# L-80 9400' Packers and SSSV Type: 9-5/8" x4-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 9284' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 16, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jovy Roach, 564-4352 Printed Name Gre obbs Title Senior Drilling Engineer Prepared By Name/Number Signature Phone 564-4191 Date~jt~~y Terris Hubble, 564-4628 Commission Use Onl Sundry Number: ~0 Conditions of approval: Notify Commission so that a representative may witness ~~ ~ 1 ~~ ~ ^ Plug Integrity [BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~~ r i Other: '3 ~5<~ '~' cj.+t-~:~~: y~.. \ c).~~ ®©S l +~`Z v~`i v~v r''~ C~J\t\~ `C~i.C..._ "~'~ S~ ~~~c~.~~~ ~s~`~ ~S ~ ~- l_i l~ ~~~~~b~ r~ t~t~as~p~'~C~r`~C~~ Subsequent Form Required: ~.,~ '~ APPROVED BY ~ ~ - COMMISSIONER THE COMMISSION Date A roved B . Form 10-403 Revised 06/2006 Submit In Duplicate • by c~~ X-05 Rig Workover Well Type: Producer Current Status: This well is completed with 5-1/2" L-80 tubing and is currently shut-in with a retrievable plug in the tubing tail. Request: Pull tubing, alter casing. ~r,,,/~ Other Requests: ~ ~-~- `' t ~'~ a Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: - Cut and pull existing 4-1/2" completion between the production packer and the sliding sleeve. - Run USIT log on 9-5/8" casing. - Cut and pull 9-5/8" casing. Run new 9-5/8" casing with casing patch and cement to surface. Replace 9-5/8" packoff. - Run new 4-1/2" 13-CR80 tubing with stacker packer completion. MASP: 2420 psi Estimated Start Date: March 16, 2009 Pre-Riq Work: 1. S Pull 3.69" special clearance WFD WRP at 9315' MD. 2. S Brush and flush tubing and liner with diesel to ~ 9600' MD in preparation for IBP set. Set 7" inflatable bride lu in the 7" liner in the middle of a full ~ in .with sluggits 3. E and junk catcher. Test to 2500 psi. Note: Two IBP-setting attempts failed in 2006. Contact ODE and APE if IBP fails. 4 E Jet cut the 5-1/2", 17#, L-80 tubing ~ 1-10 ft from the top of the first FULL joint below the sliding . sleeve at 9213 cut tubin at ~ 9223' MD .Reference tubin tall 2-19-1980. 5. F Circulate the well to seawater through the tubing cut. Freeze protect the IA and tubing with diesel to 2,200'. 6 W If not already done, Bleed OA, IA & TBG to zero psi. PPPOT - IC (9-5/8") 3500 psi, PPPOT-T 4-1/2" 5,000 si. Drill out broken lockdown screws. 7 O Pressure test the OA (9-5/8"x13-3/8" annulus) to 2000 psi for 30 minutes. OMIT T x IA to 3,500 si for 30 minutes. 8. O Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 9 O Remove the well house. Level the pad. Please provide total well preparation cost on the handoverform. • • Proposed Procedure Summary: 1. MIRU Nabors 2ES. 2. MIT-OA 2000 psi. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC and test from below to 1000 psi (also tests TxIA). 3. Nipple down tree and adapter. Nipple up BOP and test. Pull TWC. 4. RU and pull the 5-1/2" tubing from the pre-rig jet cut. 5. PU 9-5/8" casing scraper. RIH to tubing stub, ensure casing is clean. POOH. 6. RU E-line. Run USIT/GR/CCL from cut stub to surface to confirm the TOC on the back-side of the casing. (TOC on 9-5/8" casing estimated to be ~ 2173'.) 7. Run 9-5/8" RBP and set 100' below TOC behind 9-5/8" casing, but no deeper than 2800'. PT RBP to 3500 psi to prove barrier. Stack 50' of sand on RBP. 8. Swap fluid to 9.8 ppg NaCI brine. 9. Cut and pull the existing 9-5/8" casing at ~ 2100', or at best location pending USIT results. Displace with diesel and heated seawater to remove Arctic Pack. 10. RIH with 13-3/8" casing scraper and washover shoe. Wash over 9-5/8" casing stub. 11. Run new 9-5/8" L-80 HYD 563 casing with ES Cementer and casing patch. 12. PT casing (tests casing threads) to 2500 psi for 10 min. 13. Open ES Cementer. Before cementing, ensure fluid returns are above 80°F (to ensure cement achieves compressive strength). Pump cement to surface. 14. Split the BOP stack. Rough cut and LD excess 9-5/8" casing, remove BOP stack. 15. Set slips. Install 9-5/8" packoff and replacement tubing spool. 16. NU BOP and test. 17. RIH with clean-out BHA and drill out ES Cementer and remaining cement in 9-5/8" casing. 18. PT casing to 3500 psi for 10 min (tests casing, ES cementer, and patch). 19. RIH with RCJB. Swap fluid to seawater. Remove sand and any junk on top of RBP. Re-run RCJB as necessary. 20. RIH and retrieve RBP. 21. PT casing to 3500 psi for 30 min charted. 22. Run 4-~/z", 12.6#, 13Cr-80, VamTop conventional stacker-packer completion. MU and land tubing hanger. RILDS. 23. Reverse circulate inhibited seawater to packer depth. Drop ball & rod and set the packer. 24. Test tubing and IA to 3500 psi for 30 min charted. Shear DCK valve, pump both ways to confirm shear. 25. Set and test TWC to 1000 psi. ND BOPE. NU and test tree. Pull TWC with lubricator. 26. RU LRS, freeze protect to ~ 2200'. 27. Install BPV and secure the well. RDMO. Post-Riq Work: 1. O Install wellhouse, instrumentation and flowlines. (NOTE: An S-riser modification will be re uired. 2. O Pull BPV. 3. S Pull the ball and rod / RHC plug from `XN' nipple. 4. S Install gas lift valves. Drilling Engineer: Jovy Roach (907)564-4352 Production Engineer: Alecia Wood (907)564-5492 Geologist: Cole Abel (907)564-5576 ATTACH: Current Schematic Proposed Schematic TREE _ 6" CM/ Wt3LHEAD = MCEV OY ACTUATOR = OTIS KB. ELEV = 74.18' BF. E1EV - 40.28' KOP = 3100' Angle = 40 @ 6900' ~_.um MO = 10180' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2669' X-05 S NOTES: 2207' H5-1/2" CAMCO SSSV LAND. NIP, ID = 4.562" 2571' 9-5/8" DV PKR GAS LIFT MANDRELS Minimum ID = 3.725" @ 9366' 4-1/2" OTIS XN NIPPLE ( 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9284' TOP OF 4-1/2" TBG 9284 ST MD TVD DEV TYPE VLV LATCH SQE DATE 5 2994 2919 7 CAM DMY RK 0 11/24/05 4*'t 5314 4950 37 CAM DOME "`"NONE 20 3 7812 6928 38 CAM DMY RK 0 11/24/05 2 8866 7771 36 CAM DMY RK 0 1 9102 7962 35 CAM DMY RK 0 11/24/05 ""ST iF4 F1A5 BROKEN LATGN (06106/93) 9213' S-1/2" CAM SLIDING SL~/E DB-1, ID = 4.437" 9265 N BKR. PBR SEAL ASSY 9284' N 9-5/8" x 4-1/2" BKR SAB PKR, ID = 3.813" ~ 9315' H3.69 WFO WRP(12/03/O8) 9334' 4-1/2" OT1S X NIP, ID = 3.813" TOP OF 7" LNR 9361' 9366' 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2" BOTTOM OF TBG 9400' 9400' 4-1/2" TBG TAIL ~ = 3:958" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ PERFORATION SUMMARY REF LOG: SWS - BHCS ON 02/15/80 ANGLE AT TOP PB~F: 34 @ 10026' Note: Refer to Production DB for historical pert data SIZE SPF INT6~VAL Opn/Sqz DATE 3-1/8" 4 10026 - 10050 C 04/08/88 2-718" 4 10146 - 10148 S 03/20/88 3-1/8" 4 10148 - 10175 C 04/08/88 3-1/8" 4 10185 - 10217 C 04/08/88 3-1/8" 4 10227 - 10305 C 04/08/88 2-7/8" 4 10317 - 10336 S 03/20!88 PBTD 10980' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 11027' 9396' ~MD TT LOGGED 04/25/90 10158' H MARKER JOINT f7ATE REV BY COMMENTS DATE REV BY COMMBVTS 02/24/80 ORIGINAL COMPLETION 07/18/06 CJN/PJC PULL IBP @ 9570' 07/13/02 JGKAK PERF CORRECTIONS 10/25/06 JMF/PAG SET BKR IBP @ 9445' 12/02/05 KSB/TLH GLV GO (11/24/05) 12/24/06 JCANPAG BKRIBPPULLED(11/28/06) 05/28/06 TWS/PJC PXN PLUG PULL® 12/09/08 TFA/SV SET WRP (12/03/08) 06/17/06 DAV/TLH CORRECTIONS 07/17!06 DFR/PJC SET IBP @ 9570 PRUDHOE BAY UNff WELL: X-05 PERMff No: 1791040 API No: 50-029-20422-00 SEC 6, 711 N, R14E, 5220' FWEL & 363' FSNL BP 6cploration (Alaska) TREE _ . 6" CNV WEL4HEAD = MCEVOY ACTUATOR= OTIS KB. ELEV = 74.18' BF. ELEV = 40.28' KOP = 3100' Max Angle = 40 @ 6900' Datum MD = 10180' Datum TV D = 8800' SS I~alVO P~posed X-05 ~ $~"°T~ ~~ 2000' 4-1/2" HES X-NIP, fD = 3.813" n - 2100 9-5/8" CSG 47# L-80 HYD563 2100 ES Cementer w /csg patch & xo to HYD563 2571' 9-518" DV PKR Est TOC behind 9-5/8"csg ~ _ 2173 13-3/8" CSG, 72#, L-80, ID = 12.347" 2669' Minimum ID = 3.725" @ 9366' 9135' HES X-NIP, ID = 3.813" 4-1/2" OTIS XN NIPPLE 9166' 9-5/8x4-1/2 Baker S-3 PKR 9200' HES X-NIP, ID = 3.813" 9230' Unique Overshot 9240 Jet cut 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9284' TOP OF 4-1/2" TBG1 9284' 9265' {-I BKR. PBR SEAL ASSY 9284' N 9-5/8" x 4-1/2" BKR SAB PKR, ID = 3.813" 9315' H 3.69 WFD WRP (12/03/08) I 9334' 4-1/2" OTIS X NIP, ID = 3.813" TOP OF 7" LNR 9361' 9366' 4-1/2" OTIS XN NIP,. ID = 3.725" 4-1/2" BOTTOM OF TBG 9400' 9400' 4-1/2" TBG TAIL ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9845' PERFORATION SUMMARY REF LOG: SWS -BRCS ON 02/15/80 ANGLE AT TOP PERF: 34 @ 10026' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10026 - 10050 C 04/08/88 2-7/8" 4 10146 - 10148 S 03/20/88 3-1/8" 4 10148 - 10175 C 04/08/88 3-1/8" 4 10185- 10217 C 04/08/88 3-1/8" 4 10227 - 10305 C 04/08/88 2-7/8" 4 10317 - 10336 S 03/20/88 I PBTD I ~ 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" ~ 1~~~ 11~ 027' ~ 9396' ELMD TT LOGGED 04/25/90 58' H MARKER Jo~vT GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE DATE REV SY COMMENTS DATE REV BY COMMENTS 02124/80 ORIGINAL COMPLETION 07!18/06 CJNIPJC PULL IBP@ 9570' 07/13/02 JGKAK PERF CORRECTIONS 10/25/06 JMF/PAG SET BKR IBP @ 9445' 12/02/05 KSB/TLH GLV GO (11/24/05) 12/24/06 JCIWPA BKR IBP PALLED (11/28/06) 05/28/06 TWS/PJC PXN PLUG PULLED 12/09/08 TFA/SV SET WRP (12/03108) 06/17/06 DAV/TLH CORRECTIONS 12/22/08 JER RWO Proposed 07/17/06 DFR/PJC SET IBP @ 9570 PRUDHOE BAY UNff WELL: X-05 PERMff No: 1791040 API No: 50-029-20422-00 SEC 6, T11 N, R14E, 5220' FWEL 8 363' FSNL BP 6cploration (Alaska) MEMORANDUM TO: THRU' State of AlaSka Alaska Oil and Gas Conservation Commission Julie Heusser, ~ Commissioner Tom Maunder, ~-~~ P. I. Supervisor FROM: Jeff Jones, SUBJECT: Petroleum Inspector DATE: December 9, 2000 Safety Valve Tests Prudhoe Bay Field BPX / X-Pad SatUrday. December 9, 2000: ! traveled to BPX's X Pad in the Prudhoe Bay Field to witness Safety Valve System tests. Merv Liddelow, BPX representative in charge of the testing, . performed the tests in a safe and proficient manner. Of the 26 wells., tested, 3 fa[lures were witnessed. Well X-14A's SSV failed to close and well X-19B's pilot was frozen and the $SV failed' to Close. Mr. Liddelow indicated to me on 12/10/00 that these items have been corrected and successfully re-tested. The AOGCC test reports are attached for reference. I conducted 26 well house inspections concurrent with the SVS tests. A slight crude oil leak was noted on a wellhead flange of Well X-19B. Mr. Liddelow indicated he would have this item addressed. No other eXcePtions were noted. SUMMARY: I witnessed SVS tests and conducted well house inspections on BPX's X Pad. 26 wells, 53 components tested, 3 failures. 26 Well houses inspected. Attachments: SVS PBU X Pad 12-9-00 JJ NON-CONFIDENTIAL SVS PBU X Pad 12-9-00 JJ.doc Alaska Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/X Pad Separator psi: LPS 174 Date: 12/9100 HPS 723 Well Permit Separ Set LfP Test Test Test 'Date Oil, WAG, GIN& Number Number PSI PSI TAp Code Code Code Passed CAS or X-01 1790540 174 125 125 P P OIL X-02 1790690 174 125 125 P P OIL X-03A 1980860 723 '550 400 P P OIL X-04 1790890 174 i25 125 P P 'OIL X-05. 1791040! 174 ' 125 '115 P P ' ' OIL X-06 18000901 ' · X-07 1800130' 174 125 110 P P OIL ,,, X-08 1800360 174 125 115 P P OIL X-09 1800280 . ' X-10 1800430 · 174 i25' 120 'P P ' ' OIL X-11A 1990780 2000 ·i950 'P P P ' WAG , X-12 1800440 174 125 110 P P 'OIL X-13A 1930650 174 125 100 P P OIL X-14A '1921430 174 125 120 P 5 '" OIL X-15 1800740 174 125 '. 125 P ' P ' OIL X-16 1811720 174 125 .125 P P. . OIL X-17 1811690 723 55.0 '520 P P ~ OIL X-18 1811620 174 125 120 ' P P' 0IL X-19B 1961300 " 174 125! 0 2 5. , . OIL X-20 1940670 X-21A ~1991080 '174 125! I10 P P OIL X-22 1931300 174 125! 1.10 · p p '1 OIL X-23 1840610 · !' . X-24A ' 1991250 X-25 1840340 174 125' · 120' P' P 6IL · X-26 1840300 , , , ', X-27 1840690 174 125' 120 P P ~ OIL ,,, X-28 ,, , .1'9311'40 . , X-29 1931390 X-30 1950410 174 125 115 P P' OIL · X-31 1931980 174 125 120 P P OIL X-32 1931620 174 125' 125 ~ P. OIL X-34 1931720 174 125 115 P ' P OIL X-35 1931990 174 125' 90 P "' P ~IL ,! 12/13/00 Page 1 of 2 SVS PBU X Pad 12-9-00 SJ.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE X-36 1961670 Wells: 26 Components: 53 Failures: 3 Failure Rate: 5.6% E390 Day Remarks: 12/13/00 Page 2 of 2 SVS PBU X Pad 12-9-00 SJ.xls LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL X-05 # DESCRIPTION 1 PLS-GLS FINAL BL+RF 1 PLS P PROF FNL BL+RF 1FSPL FINAL BL+RF 1PLS P PROF FNL BL+RF 1PL$ P PROF FNL BL+RF ECC No. Run # 1' 1506.02 Run # 1 1506.O3 Run # i 3924.03 RUn # 1 5656.03 Run # 1 6333.00 Please sign and return to: A~. Rodney~ At l~ne Services / Anchorage, AK 99518 Received by: ~~.~ //~ )~~ate: CONSERVATION CO~IMISSION ~IIVALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS ~ PORCUP~.E DR~VE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOPY: (907) 276-7542 July 13, 1994 Steve Farris/Jerry Bixby Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification SPX PBU Wells PTD 80-086 & Dear Mr. Farris/Bixby: On July 7 & 9, 1994, our Inspector John Spaulding witnessed no-flow tests on BPX's PBU wells M-8 and X-5 respectively. The wells had been shut in on the previous day. Both wells were bled down to atmospheric tanks on-site. A gas meter showed that well M-8 was producing approximately zero SCF per hour and well X-5 approximately 61 SCF per hour. Since these rates are well below the limits for "no-flows", the Inspector concluded that wells M-8 and X-5 were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from BPX's PBU wells M-8 (PTD 80-086) and X-5 (PTD 79-104) on the condition that the low-pressure sensors and surface safety valves must be maintained in good condition and, if for any reason, the wells again become capable of unassisted flow of hydrocarbons, the subsurface safety valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. PI Supervisor c: John Spaulding bew/nlpbu 2 printed on recycled [~apcr i.'~ y (~; F) MEMORANDU TO: State o' Alaska Alaska Oil and Gas Conse~ation Commission DATE: July 9, 1994 THRU: Blair Wondzell,~~.~ ,~ ~,,~.~ FILE NO: P. I. Supervisor FROM: John Spaulding~~/J~ ~'' ~'~ SUBJECT: Petroleum Inspe(~tror li91gibd.doc "No Flow Test" BPX / PBU / Well X-5 Prudhoe Oil Pool Saturday July 9, 1994: I traveled to BPX PBU to witness the "No Flow" test on well ×-5. The well and gas lift was shut in at 2pm on July 8, 1994 and the bleed down process was started. The tubing was bled to 0 psig and the inner annulus was bled to 500 psig. The" No Flow" test was started at 12:30pm 7/9/94, the tubing was shut in for a pressure build up for 1 hour; 5psig was obtained; then the tubing was bled to an atmospheric tank and tubing bled to 0 psig in 2 min. At this time the American gas meter was hooked up to measure the gas flow and to monitor for any fluids. 2:20 pm open tubing to gas meter 0 psig 2:25 pm test # 1, 0 scl / hour and 0 psig 2:40 pm test # 2, 0 scf / hour and0 psig 2:55 pm test # 3, 0 scl / hour and 0 psig During the 30 min. gas testing a total of. 125 scf / hour was observed; no fluid flow was observed at any time during the test. I reccomend that the AOGCC consider BPX I PBU well X-5 for "No Flow" staus. Summary: I witnessed the "No Flow" test on BPX PBU well X-5. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Ancl~orage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:07/08/91 T#:82564 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below, Well Records at (907) 564-4~-!,5. If you have any questions, please contact BP A-03 INJ 06/17/91 #1 A-11 INJ 06/17/91 #1 F-09 Prod-F 06/13/91 #1 F-10 Pmd-F 06/13/91 #1 H-14 Prod-F 06/15/91 #1 M-25 Temp/FM 06/16/91 #1 R-22 GR/CL 06/16/91 # 1 ×-05 Leak Det 06/12/91 #1 X-06. CCL/Jewelry~ Log ~:,-06114/91 # 1 X-11 CCL/Jewelry Log 06/14/91 #1 X-11 INJ 06/14/91 # 1 X-27 Jewelry Log 06/16/91 #1 11500-11882 Camco 5" 9700-10050 Camco 5" 9800-10100 Camco 5" 9750-9970 Camco 5" 10400-10670 Camco 5" 10750-10906 Camco 5" 10000-10700 Camco 5" 9050-9350 Camco 5" 10250-12411 Camco 5" -8390-9570 .Camco 5" 9050-9570 Camco 5" 10400-11400 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES l~p I~'XPLORATioN DISTRIBUTioN FROM: In[orrnation Con Well ~rol SUBJECT: Records Enclosed is Your Copy o! the rnalerial lisled Well Records at (907) 564-4445. E-26 Per/ X-01 Prod. F 06/22/91 X-05 Prod-F 06/21/91 06/20/91 oenson 8o Box 196612 Ulevard Date :06/25/91 · T#:82535 be~ ifyou have anyquest~ns'Pleasec°ntactBp #1 #1 8770-9250 #1 8800-9149 Sch 9900-10250 Sch 5" Sch 5" 5" Distribution: ARCO CHEVRON _xxO~ GEOSClENcE MOBIL S PHILLIPs RESERVoiR STATE OF AL ARCHIVEs ASKA RECEIVED JUN 2 7 1991 ' Alaska 011 & Gas Cons. Commission Anchorage 1. Operations performed: Operation shutdown Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 363' SNL, 60' EWL, SEC. 08, TION, R14E, UPM At top of productive interval 2097' NSL, 2927' WEL, SEC. 06, TION, R14E, UPM At effective depth 2220' NSL, 2997' WEL, SEC. 06, TION, R14E, UPM At total depth 2678° NSL, 3145' WEL, SEC. 06, TION, R14E, UPM 12. Present well condition summary Total depth: measured 11029feet true vertical BKB 9574feet A ,~. OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIO Stimulate 3( Plugging Perforate Repair well 5. Type of Well: Development ~ Expkxatory Sffatigraphlc Service Other 6. Datum elevation (DF or KB) KBE, 74.18 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-05 (23-06-10-14) PBU 9. Permit number/approval number 79-104 / 90-239 10. APl number 50- 029-20422 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10255feet true vertical BKB 8936feet Junk (measured) fill at 10255' (01/91) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth -- BKB 110 20x30 10.6 c.y, 144 144 2635 13 3/8 3839 c.f. 2669 2669 9811 9 5/8 1550 c.f. 9845 8641 measured true vertical .. 1666 7 564 c.f. 9361.11027 10026'- 10050' (Sag R) 10148'-10175', 10185'-10217', 10227'-10305' subsea 8677'-8697' (Sag R) 8779'-8902' (three Ivishak intervals) REr,,-~zd;:L0146'-10148' ct: APR 2 Tubing (size, grade, and measured depth) A. [a$/~,a.0il& Gas Cons. Commission 5 1/2" L-80 to 9284' with 4 1/2" tailpipe to 9400' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 9284'; 5 1/2" SSSV at 2207' 13. Stimulation or cement squeeze summary 5/3/90 - hydraulic fracture treatment of the Ivishak formation Intervals treated (measured) 10148'- 10175', 10185'- 10217' Treatment description including volumes used and final pressure 2000 bbls. flush/slurry; 84,000# 16/20 Carbolite proppant 14. Reoresentative Daily Average Production or In!ection De, t~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run. Daily Report of Well Operations 1340 1474 948 3870 ~r 4796 4077 16. Status of well classification as: Oil .~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/~;/8~ .~ 1167 343 1214 289 Service Supervisor Waterflood/Miscible Flood Date SUBMIT IN DUPLICATE 9/13190 10/7/90 Rigged up Schlumberger and pedorated the following intervals using 3 3/8" carrier guns at 6 spf: Reperf: 9620'- 9628' MD BKB Add peri: 9628'- 9630' MD BKB Reperf: 9630' - 9650' MD BKB Reperf: 9665' - 9700' MD BKO Returned well to production and tested. Performed hydraulic fracture of the above intervats with 141,400# 16/20 Carbolite proppant in 2157 bblS. flush/stuffY. Cleaned out well, returned to production, and tested. jam 1/23/90 RECEIVED APR 1 2 t991 Alaska 0il & Gas t;ol~s. Commission Anchorage BP EXPLORATION RECE 1 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :05/16~90 T#:81153 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. -F-21A Gas Lift 04/28/90 #1 2000-11606 Camco 5(" ' ~ .-R-08 Prod-F 04/26/90 #1 2250-11195 Camco '5"',/~-' .~X/:)5 GR 04/25/90 #1 9100-10289 Camco 5" ,2f-09 LEAK DET 03/30/90 #1 8600-9900 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR cS'T-AT-~-O F ALASK-A~ ARCHIVES BP EXPLORATION RECEIVED_ . MAY/~ Naska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:05/08/90 T#:81105 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below, if you have any questions, please contact BP Well Records at (907) 564-~.,!.45. Tubing Puncher 05/04/90 #1 1790-2034. Sch 5" Completion 05/04/90 #1 10290-10942 Sch 5" Tubing Puncher 05/04/90 #1 9920-10325 Sch 5" TDT-P 05/04/90 #1 11450-11902 Sch 5" Completion 05/02/90 #1 111 72-11406 Sch 5" CBT 05/03/90 #1 13175-13968 Sch 5" CET 05/03/90 #1 13175-13987 Sch 5" DDL 05/04/90 #1 13385-13690 Sch 5" GR 05/03/90 #1 10185-13941 Sch 5" Data Frac 05/03/90 #1 9800-10216 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 12, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-5 (23-06-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform remedial/capacity sustainment work on the well. Yours very truly, /~/f ~ Supervisor Waterflood/Miscible Flood BJP:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECE. VED 'APR 1 1990 ,(,A. OIL AND GAS CONSERVATION COMIV~' .~'N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Alter casing ~ Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 363' SNL, 60' EWL, SEC. 08, TION, R14E, UPM At top of productive interval 2097'NS1., 2927' WEL, SEC. 06, TION, R14E, UPM At effective depth 2314' NSL, 3018' WEL, SEC. 06, TION, R14E, UPM At total depth 2678' NSL, 3145' WEL, SEC. 06, TION, R14E, UPM 12. Present well condition summary Total depth: measured 11029 feet true vertical BKB 9574 feet operation Shutdown Plugging Pull tubing Variance ~ 5. Type of Well: Develolxnent Stm~gmphi¢ Re-enter suspended well~ 'nme extension Stimulate X Perforate Other 6. Datum elevation (DF or KB) KBE. 74.18 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-05 (23-06-10-14) PBU 9. Permit number 79-104 10. APl number 50- 029-20422 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured true vertical 10421 feet Junk (measured) fill at 10421' (05/88) BKB 9103 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth - - BKB 110 20x30 10.6 c.y. 144 144 2635 13 3/8 3839 c.f. 2869 2669 9811 9 5/8 1550 c.f. 9845 8641 .. measured 1666 7 564 c.f. 10026'. 10050' (Sag R) 10148'-10175', 10185'-10217, 10227'-10305' true vertical subsea 8677'.8697'(Sag. R) 8779'-8902' (three Ivishak intervals) 9361-11027 Tubing (size, grade, and measured depth) 5 1/2" L-80 to 9284' with 4 1/2" tailpipe to 9400' 8245.9572 Sqzd: 10146'-10148' 10317.10336' 1990 Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 9284~ 5 1/2" sssv~~,'~iI & Gas C0~ c0mm 10n 13. Attachments Description summary of proposal ,4 Detailed operations program ~ 14. Estimated date for commencing operation 15. Status of well classification as: April 1990 16. If proposal was verbally approved Oil X Gas ~ Suspended Name of approver /) Date approved Service 17. I hereby ~.~b/that the fo~pj~~d correct to the best of my knowledge. Conditions of approval: Notify Commission so representative may witness J Approval No. ~.,, Plug integrity BOP Test Location clearance ~o,~e6 G.oP~ Mechanical Integrity Test Subsequent form required 10- ~ ~' Approved by order of the Commission ORIGINAL......,,,- ,,SIBNEOe,a,'ruBt' . ~ Date ~' Form 10-403 Rev 06/15/88 ~.u,,,~,.- .......... SUBMIT IN TRIPLICATE WELL X.5 (23.06.10-14~ PBU HYDRAULIC FRACTURE PROPOSAL A hydraulic fracture of the Ivishak intervals 10148'-10175' and 10185'-10217' will be performed as follows: 1. Isolate the lvishak by setting an inflatable bridge plug between 10217' and 10227' MD. 2. Perform a calibration frae. 3. Rig up fracturing equipment and pressure test. Fracture the well as follows: Volume Propp ant Rate ~ ~ PPG TYPE LBS BPM Pad 60.0 0.0 0 45 1 2.0 1.0 16/20 CL 2000 45 2 1.0 3.0 16/20 CL 3000 45 3 1,0 5,0 16/20 CL 5000 45 4 1.0 7.0 16/20 CL 7000 45 5 1.0 9.0 16/20 CL 9000 45 6 10.0 10.0 16/20 CL 55000 45 Flush 10.1 0.0 0 Total 81,000 e Leave well shut in overnight. Clean out any frac sand left in the wellbore, return well to production and test. Retrieve bridge plug. jam 4/11/90 REEEtVED ~'R 1 3 1990 ~ J~il & Gas Cons, Commission ~chorage Coiled Tubing Blow-Out-Preventers Coiled Tubing · Pack-Off Blind Rams Cutter Rams Slips ~ ~2" Chicksan (Kill Line) Pipe Rams Pump-In Sub (Circulate/Returns) W ell Head ............... RECEW--ED ~-- Swab Valve BP EXPLORATION HOUSTON ARCO BP Exploration (Alaska) Inc.. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 CHEVRON F~XON TEXA~,O MOBIL Date: 04-27-89 80013 PHILLIPS STAT~ OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: BP'CASED HOLE FINAL LOGS The following material Is being submli'i'ed herewith. Please acknowledge recelpt by signing a copy of this ie't-t'er and returning it to this office: A-11I CCL/GR 04-15-89 #1 8850-10604 C-35 TEMP 04-12-89 .#1 2950-9638 H-22 FM/TEMP 04-22-89 #1 SURF~.9600 S-18 CCL 04-16'89 #1 11100-11990 W-34 PITS 04-11-89=~ #1 10350-10786 X-O5 TEMP/GLS 04-15-89 #1 55-9500 Z-25 CCL 04-16-89 #1 10500-11600 Cmmco Camco 5" Camco 5" Camco 5" Camco , 5" Camco 2"/5" Camco 5" Rece i ved Date ~~A~ka Oil & Ga;Cons. C0mmissi0rl Anchorage Shirley R. McCurry INFORMATION CONTROL Well Records LR2-:i Standard Alaska ~ Production CompanJ 900 East Benson Boull~ ~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION July 27, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well X-5 (23-06-10-14) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a cement squeeze and reperforation of the well. Yours very truly, JAB: JAM ? Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 X-5 Well File A unit of the original Standard Oil Company Founded in Cleveland Ohio in 1870, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: 2. Name of Operator Operation shutdown [] Stimulate [] Alter casing 1'3 Other [] Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 363' SNL, 60' EWL, SEC. 08, TION, R14E, UPM At top of productive interval 2097' NSL, 2927' WEL, SEC. 06, TION, R14E, UPM At effective depth 2314'NSL, 3018' WEL, SEC. 06, TION, R14E, UPM At total depth 2678' NSL, 3145' WEL, SEC. 06, TION, R14E, UPM 1. Present well condition summary Plugging [] Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) KBE-- 74.18 AMSL 6. Unit or Property name Prudhoe Bay Unit 7. Well number X-05 (23-06-10-14) PBU 8. Approval number 7-850 9. APl number 5 0 - 029-20422 10. Pool Prudhoe Oil Pool feet Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2635 Intermediate 9811 Production -- Liner 1666 Perforation depth: measured 11029 feet BKB 9574 feet 10421 feet BKB 9103 feet Size 20x30 133/8 9 5/8 Plugs (measured) Junk (measured) fill at 10421' (05/88) Cemented 10.6 c.y. 3839 c.f. 1550 c.f. 7 564 c.f. 10026'- 10050' (Sag R) 10148'-10175', 10185'-10217', 10227'-10305' true vertical subsea 8677'-8697' (Sag R) 8779'-8902' (three Ivishak intervals) Tubing (size, grade and measured depth) Measured depth 144 2669 9845 5 1/2" L-80 to 9284' with 4 1/2" tailpipe to 9400' 9361.11027 True Vertical depth BKB 144 2669 8641 8245-9572 Sqzd: 10146'-10148' 10317'-10336' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 9284'; 5 1/2" SS ~ ~ ~. ¢ ~.,, ~ 2. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 3. Reoresentative Daily Average Production or In~ection Data. Prior to well operation Subsequent to operation 4. Attachments OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1500 1529 4978 1664 233 2020 3688 555 0 245 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ~e~d ~--~~ ~~./,'~--~ Title ManagerProductionEngineering Form 1~04 Rev. 12-1-85 ¢(.~ ' Submit in Duplicate WELL ~-$ (23~06-10-14} PBU CTU I~EMENT SOUEEZE OPERATIONS A coiled tubing cement sqUeeze of existing perforations was performed as detailed below. 1. Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. 2. Performed HCI acid wash of the perforated intervals; flowed well. 3. Cleaned out wellbore, then fluid packed wellbore with produced water. 5. Pretreated thief interval with a: weighted crosslinked polymer pill to reduce high permeability. 5. Pcrformed cement squcczc of all existing perforations. 6. Contaminated cement in thc wcllborc then reversed out after 24 hours. Tested squeeze. 7. Perforated thc following intervals using Gearhart 3 1/8" carrier guns at 4 spf. 10026' - 10050' MD BKB Sag R. 10148'-10175' MD BKB _Z. 4 10185' - 10217' MD BKB Z. 4 10227' - 10305' MD BKB Z. 4 8. Returned well to production and tested. The above work was completed April 8, 1988. jm 7/14/88 9'00 ~.os! PO 8~ 196017 Anchoroge. Alosl, o 99519-6612 (9071 564.~1 ! DALLAS ARCO CHEVRON EXXON STANDARD ALASKA PRODUCTION TEXACO Date: 06/08/88 TO: MO B IL Ti: 78924 PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy'of this letter and returning it to this offlce: C-31 C-31 C-34 GC-3A G-14 R-14 X-5 CCL/Perf 04/16/88 CCL/Perf 04/18/88 CCL/Perf 04/17/88 Positioning Log/CCL CCL/Perf 04/30/88 Temp. Survey 04/27/88 CCL/Perf 04/08/88 #1 10245-11643 Gearhart 5" #1 11200-11643 Gearhart " ~1 8300-9602 Gearhart " 04/20/88 #1 2700-2830 Gearhart 5" #1 9200-9700 .Gearhart 5" #1 600-3500 Gearhart " #1 9200-10496 Gearhart " R~ce I ved Alaska ,da,d OI O~.o..n 1870 Anchorage ion Jennifer Dietz I NFORMAT I ON CONTROL Wel I Records LR2-1 TO: DALLAS ARCO c~v~o~_ EXXON TEXACO PHILLIPS_ · STATE OF ALASKA_ ARCHIVES S'i'/%NDARD ALASKA PRODUCTION Date: 06/03/88 TI: 78897 -- REFERENCE: ~APC FINAL DATA - pREssURE SURVEY DATA · %he fo! lowing materla! I$ being submitted herewith. Please ackmowledge recelp* by signing a copy.of this le~-ter and returning I~ to this office: A-6 05/05/88 C4D Static A-10 05/05/88 .GO .B-lB 05/04/88 GO , B-15 6,5/04/88 Go ,, u-a 05/20/88 GO ' ~,X-5' 05/06/88 ' GO ,, X-14 05/05/88 GO , Y-24 05/11/88 GO Oil & ~3as Co~s. Gommissi~:'~ ..... ~chomrje Received Date A u,,h ol t~,~ o,~;'".'l $,o-do,cl 0.1 Jennifer Dietz INFoRMAT ION CONTROL We! ! Recocd$ iR2-| DALLAS ,~co STAND/t. RD CHEVRON :' AL ASKA PRODL JC TION .'. E,~(ON Date: 05/11/88 TEXACO 'to: T~': 78824 HOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is belng submitted herew th. Please acknowledge receipt by slgnlng a copy of this letter and returning It to this office: A-22 Static Gradient A-35 Static Gradient C-19 Static Gradient C-27 Static Gradient C-30 Static Gradient C-31 Static Gradient H-12 BHPS static Gradient H-22 BHPS Static Gradient K-6 Static Gradient '~~,: BHPS Static Gradient X-9 BHPS Static Gradient X-15 Static Gradient X-27 Static Gradient Y-10 BHPS Static Gradient Y-21 BHPS Static Gradient o5/o5/88 05/05/8.8 05/04/88 05/04/88 05/03188 05/04188 04/30/88 ~/29/88 04/28/88 o5/o3/88 o5/o3/88 05/06/88 05/06/88 05/01/88 o5/ol/88 Camco Camco Camco Camco Camco Camco Otis Otis Camco Otis Otis Camco Camco Otis Otis Rece I ved Date ,~,,,I o! the lOon<fed ,,, " Alice Beck ...... ~,-,St ,1~, I NFORH~T { ON CONTROL Wel I Records LR2-1 DALLa\S ~¢o STANDARD CHEVRON ALASKA PRODUCTION E,~XON Date: 01/20/88 TEY~ACO TO: ri: 78458 MOBIL PHILLIPS "~.~TE OF ALASKA, REFERENCE: SA.PC FINAL DATA - PRESSURE SUAVEY DATA The following material ts being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning It to thls offlce: A-5 'X~ Y-12 Static Gradient 01/10/88 Camco " " 01/07/88 Camco " " 01/09/88 Camco Alaska 0ii & (]as Cons. Commission Anchorage Rece 1 ved Date 1870 Victoria Aldridge INFORMAI I ON CONIROL Wel I Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES 'INDEXED 5 I'ANDARD Al. ASKA PRODUCTION Oate: 12/10/87 · r#: 78352 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter end returning It to this office: 'Injection Profile 11/29/87 #1 10400-10885 Camco Caliper 11/28/87 #1 8200-9230 Camco 5" PIT/HPFM 11/29/87 #1 10000-10480 Camco 5" Rece t ved A unit of the o,~g'~ol S, tondo,d O,I Compony I:ounded ,n (~le,elond. Oh,o. in 1870 Victoria Aldridge I NFORHAT I ON CONTROL Wel I Records LR2-1 Standard Alaska f~ Production Cornp~ 900 East Benson Bo%._,,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 561-5111 STANDARD ALASKA PRODUCTION October 23, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton We].l X-5 (23-06-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, JAB:JAM~/L Enclosures (9) cc: J. L. Haas (MB12-1) X-5 Well File upervisor Production Operations RECEIVED OCT 2' 8 !8r~7 Alaska 0il & ~as Cons. Commj~or~ Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA AL OIL AND GAS CONSERVATION C .~,oSION 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 STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 363' SNL, 60' EWL, Sec. 08, T10N, R14E, UPM At top of productive interval (top Ivishak/Sadlerochit) 2156' NSL, 2953' WEL, Sec. 06, T10N, R14E, UPM At effective depth 2649' NSL, 3136' WEL, Sec. 06, T10N, R14E, UPM At total depth 2678' NSL, 3145' WEL, Sec. 06, T10N, R14E, UPM 5. Datum elevation (DF or KB) KBE = 74.18 6. Unit or Property name Prudhoe Bay Unit 7. Well number X-5 (23-06-10-14) PBU 8. Permit number 79-104 9. APl number 50-- 029-20422 10. Pool Prudhoe Oil Pool feet 11. Present well condition summary Total depth: measured true vertical 11029 feet Plugs (measured) 9574 feet BKB Effective depth: measured 10980 feet Junk (measured) true vertical 9535 feet BKB Casing Length Size Cemented Structural -- Conductor 110 ' 20 "x30" 10.6 c.y. Surface 2635' 13 3/8" 3839 c.f. Intermediate 9811' 9 5/8" 1550 c.f. Production -- Liner 1666' 7" 564 c.f. Perforation depth: measured 10146' - 10305' (three intervals) true vertical (ss) 8775' - 8902' Tubing (size, grade and measured depth) 5 1/2" L-80 to 9284' with 4 1/2" tailpipe to 9400' Packers and SSSV (type and measured depth) 9 5/8" Baker SAB packer at 9284'; 5 1/2" SSSV at 2207' Measured depth True Vertical depth BKB 144 ' 144 ' 2669 ' 2669 ' 9845' 8641 ' 9361'-11027' 8245' -9572 ' Sq. interval: 10317-10336' RECEIVED, Alaska 0il & Gas Cons. C0mmissi0r~ Anchoraae 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation October/Novez~er 1987 14. If proposal was verbally approved Su~)sequen[ Vgork Repoz~ed on ~orm No./D- ~-/0;'/-/_ Dated_.~/~_.~~ Name of approver Date approved 15.,I hereby certify that the foregoing is true and correct to the best of my knowledge SiCe?~d ~~ Title Supervisor Production Operations Date /(,,O.,~.~" ~7 /. A. Bragg ~/'~/ " Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No.. [] Plug integrity [] BOP Test [] Location clearancel '~ Approved by Form 10-403 Rev 1~:~;'85i''~':: i: ~!,' t',~:: Commissioner by order of the commission Date /~) Submit in triplicate WELL X-05 CTU CEMENT SQUEEZE PROPOSAL The following combination polymer pill pre-treatment/coiled tubing cement squeeze of existing perforations and a confirmed cement channel is proposed. The polymer pretreatment is recommended due to the high permeability thief interval eqcountered on the previous cement squeezes. Following CTU operations, all of the existing perforation interval will be reperforated. 1. Rig up coiled tubing unit and pressure BOP's to 4000 psi. 2. Clean out wellbore to PBTD or to top of solid fill. 3. Perform HCL acid wash of the perforated interval. 4. Return well to production to flow back spent acid. 5. Fluid pack the wellbore with produced water. 6. Pre-treat the thief interval with a weighted crosslinked polymer pill to reduce the high permeability. 7. Perform cement squeeze on existing perforations and cement channel. 8. Contaminate cement in the wellbore. WOC. 9. Reverse out contaminated cement after 48 hours. 10.Test squeeze. ll.Reperforate the following interval at 4 spf: 10146' - 10175' MD BKB 10185' - 10217' MD BKB 10227' - 10305' MD BKB 12. Put well back on production and test. RE,CEIVEi) Anchorage Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Of{- Blind Rams Cutter Rams ~ ~2"Chicksan(KillLin.) R E C E iV ED': Pipe Rams ,,,,%:d:~ Oil & Gas Cons. Commissior~ Pump-In Sub Anchorage (Circula te/R e turns) Well Head Swab Valve Slanda~d Alaska P~oductien Company 900 East Benson Boulevard P.O Box 196612 Anchorage. Ala$1~a 99519-6612 ~907~ 564..51 t I INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA STANDARD ALASKA PRODUCTION Date: 08/18/87 78131 TI: REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submit?ed herewith. Please acknowledge receipt by signing a copy of thls letter and returning it to ?his office: ~ B-30 08/10/87 'Static Gradient Camco //. .,, "~ C-32 08107/87 ." " " / .. ,,-.."..i \ C-_32- 0R!nq/87, " " " // J-24 07/30/87 " " " f( ',: ,,,, ,,: / ~ X-5 07/29/87 " " " / ~ X-14 08/07/87 " ,, " I. ~ ~-~ o~/o~/~ " " " I ~ ~-22 08/03/87 " " "~~.. Wel I Records LR2-1 Standard Alaska / Production Company%. 900 East Benson Boulevard PO. Box 196612 Anchorage. Alaska 99519-661;2 ~907) 564-511 I INDEXED , · DALLAS ~co STANDARD CHEla. ALASKA PRODUCTION EXXON Date: 08/18/87 TF. XACO 78131 TO: Tt: MOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA · The following material Is being submitted herewith. Please acknowledge receipt by slgning a copy of this letter and returning it fo this offlce: "~B-30 08/10/87 '""C-32 08/07./87 '""C-32 08/09/87 / '~J-19 07/28/87 / ----J-24 07!30~87 / "~JX-2 07/30/87 / ""-~N-21 08/10/87 / ~X-5 07/29/87 I '"'"~X-7 07/29/87 I "-X-9 08/07/87 I '~-'X-1408/07/87 ~ '"~Y-1 ,08/07/87 ~Y-22 08/03/87 Static Gradient Camco II II 11 11 II II II II II II II II II II II II I1 II !I 11 II 11 I! II II II II II II II II II II II II !I !1 II I! !1 11 II AUG o Oil & Gas Cons. Commission' .., Anchorage Rece I ved Dote A u,,,f of the m,9,.,,I 5to,~c1¢,,¢f C~I (.'o,.po,,y Fou,',ded ,n Clevelo,,cl Oh,o. ,. 1870 Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA STANDARD ALASKA PRODUCTION Date: 01/08/87 It: 77647 Page 2 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of thls lei-ret and returnlng It to this office: ~R-1 Static. Gradient 12/14/86 ~-R-16 " " 12/14/86 '~-R-19 " " 12/13/86 ---R-23 " Survey 12/15/86 ~S-1 Static Gradient 12/17/86 ~S-2 " " 12/17/86 ~S-10 " S~rvey 12/19/86 ~S-10. " Gradient 12/16/86 -~-S-13i Static'Survey 12/14/86 ~"S-19 " Gradient 12/05/86 ~-S-20 " " 12/07/86 ~X-2 " " 12/26/86 '~X-5 "' " 12/20/86 -~ Y-2 " " 12/20/86 ~¥-8 Static 12/07/86 PLS-P=es. Survey 11/04/86 -- Ca.T~ICO Camco Camco Camco Camco Cam~o Camco Camco Camco Dre8~'~''~''~ Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 INDEXED TO: DALLAS A~CO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES (Transmittal Only) STANDARD AL ASKA PRODUCTION Dote: 01/08/87 TI: 77647 Page 1 of 2:! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Pleese acknowledge receipt by slgnlng a copy of this le~-fer and returning It to thls offlce: Static Gradient 12/28/86 Camco " " 12/28/86 Camco " " 12/25/86 " Static 12/22/86 GO Static " 12/26/86 Camco Static 12/23/86 GO " " 12/23/86 Camco " " 12/25/86 " " " 12/27/86 " Static 01/02/87 GO " 01/02/87 GO " 12/30/86 " " 12/30/86 GO " 11/24/86 Camco " " 12/11/86 Camco Static Survey 12/11/86 GO Static Survey "'- 12/11/86 GO Static Gradient:" 12/12/86 Camco Static Gradient 12/11/86 Camco " " 01/02/87 Camco " " 12/13/86 Camco " " 12/12/86 -Camco Static Survey 12/12/86 GO N-19 Static Recel ved ~~~~ Victoria mldridge Dete Wel I Records LR2-1 DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSC IENCES INDEXED STANDARD ALASKA PRODUCTION Date: 11/05/86 TI: 77490 REFERENCE:' SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: - D-11 Caliper 10/27/86 #1 29-9510 Camco 5" G-19 CET 06/27/86 #1 10330-11550 Sch 5" M-4 Perf. Record 05/25/86 #1 9370-11660 Sch 5" M-17 Perf. Record 06/01/86 #1 11000-1.1749 Sch 5" N-7 Packer Depth 05/21/86 #1 9400-10450 Sch 5" R-12 Perf. Record 06/03/86 #1 10400-10968 Sch 5" R-23 Perf. Depth Record 05/06/86 #1 11490-11900 Sch 5" U-12 Perf. Record 05/30/86 #1 10800-11100 Sch 5" X-5 CET/GR 05/10/86 #1 9468-10700 Sch 5" Y-20 GCT 06/21/86 #1 Surf-12107 Sch 5" Y-23 GCT 06/23/86 #1 -8-11566 Sch 5" Rece i ved D~te A unit ~,~, 0!1 & GaS ColtS. C;om '" Anchorage tondo,d 0,1Co,npon¥ :~. Ohio. ,n 1870 Vict~ Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS · STATE OF ALASKA ~ ,.,,:..,., ~._ ~ ~ .~ .. GEOSC IF. NC~S INDEXED STANDARD AL ASK/-., PRODUCTION Date: 10/09/86 TI: 77392 A-33 B-23 H-22 J-9 M-13 M-25 M-28 M-28 R-24 t~' 5 ×-5 X-14 Y-21 Y-22 Y-22 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning It to this office: - EPL 05/22/86 #1 11000-11398 Sch 5" CET 03/04/86 #1 9150-10008 Sch 5" CBT 06/25/86 #2 8700-9974 Sch 5" EPL 03/25/86 #1 8800-9832 Sch 5" EPL 05/19/86 #2 9400-9850 Sch 5" CBT 05/01/86 #1 10250-11400 Sch 5" CBT 04/30/86 #1 8000-9215 Sch 5" GCT 04/30/86 #1 0-9200 Sch 5" EPL 05/07/86 #1 9150-9516 Sch 5" EPL 05/13/86 #1 9150-9450 Sch 5" EPL 05/09/86 #1 10000-10678 Such 5" EPL 03/31/86 #1 2100-11565 Sch 5" CBL 04/23/86 #1 11020-11550 Sch 5" GCT 04/01/86 #1 48-11400 Sch 5" CBL 04J. 01/86 #1 10650-11410 Sch 5" Rece 1 ved Date A un,t Of the or,g, nol I:ounded ,n Cle~elo.d, · Victoria Aldridge LR2-1 I NFORMAT I ON CONTROL Wel I Records LR2-1 ARCO CHEVRON EXXON TEXACO Dale: 09/29/86 TO: MOBIL TI: 77368 PHILLIPS ~.:4-~ STATE'OF ALASKA.',': GEOSCIENCES STANDARD ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submil-ted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to thls office: ~'"'~-15 Temp. 09/10/86 #1 0-3000 Camco 5" Sur,-.00 Temp. 09/11/86 #1 0-3000 Camco 5" - Temp. Fluid ID 09/2-6/86 #1-5 Surf-3500 Camco 5" ~~i~'~B 4~ EPL 04/08/86 #1 6600-10625 Sch 5" Spinner 09/08/86 #1 9400-11200 Camco 5" Collar 09/01/86 #1 2000-8834 Camco 5" ~M-25 Temp./Permafrost 09/19/86 #1 Surf-3000 Camco 5" Q-5 Collar 09/12/86 #1 9300-10370 Camco 5" \Q:5 Collar 09/14/86 #1 10100-10367 Camco 5" Collar/GR 09/17/86 #1 11100-12173 Camco 5" Temp/Permafrost 09/17/86 #1 Surf-3000 Camco 5" Caliper 07/20/86 #1 Surf-9180 Camco 5" -1I Temp. 09/10/86 #1 0-3000 Camco 5" -11 Temp. 09/13/86 #1 0-3500 Camco 5" -11 Temp. 09/15/86 #1 ' 0-3000 Camco 5" -2 Temp./multi ID 09/16/86 #2 2S61-9645 Camco -2 2 Temp./Permafrost 09/19/86 #1 Surf-3000 Camco 5" Rece 1 wed Date _ , . , . .. '- A un,! OI Iht C~K~, ! I ~om~n~ ''~ ~',. -- Fou~ed ,. (~-~o~. *n 1870 V±¢tor±a Aldr±dge LR2-1 I NF~T I ON OONTROL Wel I Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION Date: 06/09/86 Tt: 77104 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herevlth. Please acknowledge receipt by signing a'copy of this letter and returning It to this office: A-1 Static Gradient 05/18/86 Camco A-5 " " 03/22/86 " A-31 " "& BHPD 04/08/86 Otis A-34A " "& " 04/09/86 Otis :~:~,Z'~'''~ " "& " 05/17/86 GO A-35 Pres. BU Survey 05/15/86 GO B-1 Static Gradient 05/15/86 Otis B-2 " " 03/17/86 Camco B-23 " " 05/21-22/86 Camco D-6 " 03/14/86 GO D-19 " " 03/23/86 Camco D-19 BHPD & Survey 04/29/86 · Otis D-23 Static Gradient 05/23/86 Camco E-1 " " 03/14/86 Camco F-4 BHP Survey 04/03/86 Otis F-10 Static Gradient 03/23/86 Camco F-24 BHP Survey 04/04/86 Otis H-26 Static Gradient 05/25/86 Camco H-27 " " 05/25/86 Camco K-8 Static Survey 03/26/86 GO M-5 BHP Survey 05/18/86 Otis M-17 Static Gradient 05/06-07/86 Camco N-4A " " 03/20/86 Camco N-20 BHP Survey 04/05/86 Otis N-20 BHPD & PBU 6 N-22 BHPD Rece i ved Date III Victoria~ridge LR2-1 I NFORMAT I ON ¢Om~ROL Wel I RecoFds LR2-1 ... r IH;Il 06/09/86 T~77104 Page 2 of 2!! R-23 Flowing Gradient N-22 BHPD & PBU S-8 Flowing Gradient S-10 S-13 ,t ,, X-9 X-25. Y-2 Y-9 Static Gradient Flowing Gradient Static Gradient BHP Survey · BHP Survey OS/Il/S6. 05/15/86 03/13/S6 05/17/86 03/16/86 05/26/86 03/26/86 05/19/86 05/14/86 04/07/86 05/15/86 GO Camco Camco Camco Camco Cameo Camco Camco Camco Otis Otis Victoria Aldridge LR2-1 SOHIO ALASKA PETROLEUM COMPANY DALLAS A~C0 EXXON 31 1 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE {9071 265-0000 MAIL: POUCH 6-61 2 ANCHORAGE. ALASKA 9950Z TO: DAL/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS Date: 03/07/86 76922 T#: .STATE OF AK : BPAE GEOSCIENCES REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Injection Profile-Spinner ll ll II II II Il Caliper Injection Log Injection Profile-Splinter Temperature Survey Spinner Spinner/Temp. Sp~nner Spinner Spinner Pump-in Temp. Survey Injection Profile Spinner Injection Profile Spinner Injection Profile Spinner-Temp. 02/12/86 91 9600-10430 Camco 5" 02/20/86 91 9600-9960 Camco 5" 02/13/86 91 10500-10760 Camco 5" 02/13/86 91 Surf-9500 Camco 5" 02/14/86 91 9600-10000 Camco 5" 11/16/85 91 10600-11640 Camco 5" 02/28/86 #1 9200-9700 Camco 5" 03/01/86 91 10100-10700 Camco 5" 02/27/86 91 9000-9410 Camco 5" 03/02/86 #1 9600-9900 Camco 5" 10/29/85 91 9350-9830, Camco 5" 10/31-11/1/85 #1 9950-10730 Camco 5" 02/26/86 91 11400-11820' Camco 5" 02/18/86 #1 9750-10120 Camco 5" 02/21/86 #1 10600-11400 Camco 5" RECEIVED Ancn0mge DATE Victoria Aldridge LR2-1 INFORMATION CONTROL WELL RECORDS LR2-1 SOHIO ALASKA PETROLEUM COMPANY DALLAS ARCO CHEVRON EXXON To: DAL/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS 31 I 1 '°C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 1-17-86 T~: 76708 STATE OFAK BPAE GEOSCIENCES REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- R-12 R-23 ~ X-5 DFT 12-26-85 #1 surf-5000 Camco 2" Temp 1-08-86 #1 9600-10100 Camco 5" Temp 1-01-86 #1 11300-12202 Camco 5" Spinner/Temp/ 12/29-30/85 #3 10000-10550 Camco 5" Fluid I.D. RECEIVED _ Cathy Perkins LR 2-1 INFORMATION CONTROL WE'.~L RECORDS LR2-1 SOHIO ALASKA PETROLEUM COMPANY December 30, 1985 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well X-5 (23-06-10-14) PBU Gentlemen: Enclosed, in dup~iCa%e,.is Form 10-403, Sundry Notices and Reports on Wells, for the~ above-namedwell This contains our subsequent report of a cement squeeze operation. Yours very truly, JAB: JAM~ Enclosures (2) cc: Drilling Well File (MB12-1) Well Records (LR2-1) X-5 Well File RECEIVED J AN 0 2 1986 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA O~M ALASKA OIL AND GAS CONSERVATION C ' MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 79-104 3. Address 8. APINumber P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20422 4. Location of Well At surface: 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number X-5 (23-06-10-14) PBU 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 74.18' AMSL I ADL 28313 12. Check Appropriate Box lo Indicate Nature of Notice, Report, or Other Data 11.FieldandPool Prudhoe Bay Prudhoe Oil Po01 NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following work was performed on Well X-5 using coiled tUbing: 1. Cement squeezed existing perforated interVals: to shut off water channel. 2. Reperforated the following intervals at 4 spf: 10185' - 10196' BKB 10206' - 10217' BKB 10227~ - 10240' BKB 10250' - 10270' BKB 10280' - 10305' BKB The interval 10317' - 10336' was left squeezed. RECEIVED JAN 0 2 AlaSka 0[~ & Gas Cons. Commission Anchorage PerfOrated the following additional intervals at 4 spf: 10146' - 10175' BKB 10196' - 10206' BKB 10240' - 10250' BKB 10270' - 10280' BKB put well back on production. The above work was completed on November 30, 1985. ,14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~igned ~ ~~ Title Supervisor Production Operatior~te 'Thes~(~,~bel°wf°rC°mmissi°n('/~e J.A. Bragg / C°nd~t/°ns°fAPpr°val'ifany: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY S FO ARCO CIlF-VRON EXXON ~o: SFO/UN]:T/STATE: TEXACO (-.~ara t:hon) HOB~L PHILLIPS STATE OF AK BPAE 31 ! ! "C" STN6ET ANCHORAG6. ALASKA (9071 265-0000 MAIL: POUCt4 6-612 ANCHORAGE. ALASKA 99502 12-19-85 Date: T#: 76640 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is beir~ submitted herewith. Please ;u-'knowledge receipt by sig~nO · copy of this letter and returning it to this office:-- SFO/Unit/State: .~'D-7-~ ~ Packer Record ~,(~/ ~"GC31C~ DFT -----JX-2 ~ CH-CNL -:~}~ ~,~M-6" Temp ~g ~R-2~ ~L ~R-2 ~ Temp Log ~R-2,~ Inj. profil&' ' ~R-20~ EPL ~U-~ CFS %X-5 ~ Temp Log ....... 1]-21-85 #I - , 9796-10330 Sch 11-02-85 #1 surf-2830 GO 5" 11-26-85 ~1 9100-9955 Sch 5" 12-08-85 # i. surf-4500 .Camco 2" 10-10-85 #1 9300-9951 Sch 5" 11-17-85 #1 9400-10000 GO 5" 11-17-85 #1 9400-9800 GO 5" 10-24-85 ~3 11300-11900 Sch 5" 10-28-85 #1 9620-10220 GO 5" 11-30-85 #1 9950-10748 Sch 5" · , SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To: SFO/UNIT/STATE: TE~OkCO (-.Marathon) MOBIL PHILLIPS STATE OF AK BPAE 311 I "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-6 ! 2 ANCHORAGE. ALASKA 99502 Date: T#: 12-12-85 76630 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- SFO/UNIT/STATE: '"B-5 '~ 11-09-85 CH-CNL 10860-11874 Sch ~B-17-'~ 11-04-85 CNL 10250-11242 Sch .~C-3-~ " 10-27-85 EPL 9800-10140 Sch ~"C-13~~ 11-08-85 CH-CNL... 10390-11454 Sch '"E-5 11-01-85 CNL 9300-10001 Sch ~F-10" 10-30'85 CNL 9200-10026 Sch '~H-5-'~ 11-07-85-- Tie-In Log 9430-10100 Sch "X-5~/, .. 11-16-85. Gradiomanometer 9900-10735 Sob ~"~.X-6//' " 10-31-85 EPL 12150-13000 Sch ~Y-3~ 11-02-85 EPL 9100-9550 Sch t;5 5" #1 5" #1 2" 5" #1 5" #3 5" 5" #1 5" I/1 5" #1 5" RECE~V£D DAT[ Cathy Perkins LR 2-1 TeChnical Documentation Records Management INDEKED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TE~YACO TO: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) 31 i 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907l 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99.502 Date: T#: 11-13-85 76561 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- X-5 10-31-85 Static Gradient Camco RECEIVED SOHIO ALASKA PETROLEUM COMPANY 'November 7, 1985 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well X-5 (23-06-10-14) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to work over the well. Yours very truly, JAB:DOC:JAM Enclosures (3) cc: R. H. Reiley (MB12-1) Well Records (LR2-1) X-5 Well File nOperations Supervisor £CEI VEb NOVO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 79-104 3. Address 8. APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20422 4. Location of Well At surface: 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE=74.18'AMSL I6, Lease Designation and Serial No. ADL 28313 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number X-5 (23-06-10-14) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 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 [-I 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). A coiled-tubing unit (.CTU) cement squeeZe'of'existing perforations and a confirmed cement channel to the OWC in Well~X-5 is proposed, After CTU operations, the Squeezed perfora- tions will be reperforated~and additional perforations will be added. The work is outlined as follows: . 2. 3. 4. 5. . . Lay in mud from PBTD to 10361' MD. Pump in cement and squeeze' off perforations and cement channel. Contaminate cement in the'Wellbore. Reverse out contaminated cement after 24' hours. Reperforate the following intervals at 4 spf: 10185'-10916'MD 10250'-10270'MD 10206'-10217'MD 10280'-10305"MD 10227'-10240'MD 10317'-10336'MD Add initial perforations to the folloWing interVals at 4 spf:~_~ 10146'-10175'MD 102 0'-1'0280'MD i j RECFIVED 10240'-10250'MD 10390'-10420'MD ~~ ---- -- Put well back on production and test. ~~. NO~ V08~ This work is scheduled to commenCe November 25, 1985. Alaska 0il & Gas Cons, C0mmissi~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The sp/~(/e below for Commission use I/ %1- A. Bragg ConditiOns of Approval, if any: L/ ~kpproved Co~ Approved by By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TO~ SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) REFERENCE: CENTRAL FILES (CCI/' s-Transmittal Only) 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99 502 Date: 6-8-84 CC#: 75369 SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- I X-5 Diff. Temp.. X-10 ~._.~Temp. 5-20-84 9200-10960 Otis 5" 5-26-84 '10600-11050 Otis 5" Alaska 0il & Gas Cons. Commission Anchorage (4/82) RECEIVED DATE 19 Carolyn Bishop Development Geology Well Records SFO/UNIT/STATE (- Marathon) SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT/STATE REFERENCE: SOttIO FINAL DATA IlL I _ IL ~ - . _1 I II · II I ii ii I I II i - ~ i cO._M~J-;'_--. J:~ I' J~NG ~r3 ~E~ K,~ --J-STAT TE~ CONFER. J II I ¢ 3111 'C" STR ANCHORAGE, Al TELEPHONE (907) MAIL: POUCH ~ ANCHORAGE, ALA.. 10122180 ~The following material is being submitted herewith. Please acknowledge receipt by'signing a copy of this letter and returning it to this office:- B-5 E?L B-5 EPL ~J2 B-17 Spinner Flow. ~/1 4-Arm Caliper ~t2 Spinner Y-1 Temp. Diff. Y-2 Spinner 9/13/80 9/18/80 8/25/80 6/16180 lO/3/8o 9/25/80 10115180 [1500-11805 [1500-11830 [0650-11070 10900-12581 9900-10400 Surf.'12864 10100-10500 51! 5" 5" 5" 5" 5" 5" Carol Kr~'eter Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT REFERENCE: · I ii _ i i II I - ~ -- Mobil -- Phillips _ -- BPAE _ - /~OHIO DATA - // The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- A-6 Bottom-Hole Pressure Data Form & Survey (Camco) 9/23/80 B-5 " " " " " " (Schl.) 9/14/80 G-2 " " " " " " (Otis) 10/6/80 '~--~'~'"~'3 " " " " " " (Otis) 10/4/80 Carol Krieter Well Records SOHIO ALASKA PETROLEUM COMPANY August 5, 1980 State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99509 Attn: Mr. H. H. Hamilton ANCHORAGE, AL~ ENG TELEi-,~ONE (907)_ 265~1:]O0~ ~ 2 ,--NG MAIL: POUCH 6-61,2 :-:,,,~.-. ANCHORAGE A LAS KA'"9 9 5'0~ Subject: Wells C-14, C-15, ~X-5 Enclosed please find, in ~ Form 10-403, Sundry Notices and Reports on Wells, and Form-IOZT[04, Monthly Report of Drilling and Workover Operations for the above referenced wells. Enclosures CC: S. R. Bundy A. E. Leske Drilling File Geology Very truly yours, SOHIO ALAS~ PETROLEUM COMPANY G. J. P lisga ii ~ ~District Field Enginee~ F%~. 10-403 R 1-10q3 Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL 17~ GAS I--I WELL ES, ZtJ WELL I.--I OTHER 2. NAME OF OPERATOR 2. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 99502 4. LOCATION OF WELL At surface 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 74.18' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTI~)N TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) 5. APl NUMERICAL CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. X-5 (23-06-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM 12. PERM.T NO. 79--104 )orr, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I:)ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. The following intervals were perforated July 27, 1980 using Schlumberger 2 7/8" hyperdc~e guns at 4 spf: 10185' - 10196' 10206' - 10217' 10227' - 10240' 10250' - 10270' 10280' - 10305' 10317' - 10336' (11') (Ref. BHCS/GR, 2/15/80) (11') (' " " ) (13 ') ( " " ) (20') ( " " ). (25') ( " " ) (19') (:. " " ). A SSSVwas set and tested' in the'ball valve nipple Ca. 2000'. hereby certify t~the forego~ i~ and correct -' -- ' ; , ri (This Sl~ce for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form No. ! 0-404 REV. SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 2. NAME OF OPERATOR Sohio Alaska Petrole~n Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 99502 4. LOCATION OF WELL At Surface: 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit West 9. WELL NO. X-5 (23-06-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM 12. PERMIT NO. 79-104 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. July 19, 1980: Pressure tested tubing and inner annulus. July 27, 1980: Rigged up Schlumberger and perforated the following intervals using 2 7/8" HYperdc~e guns @ 4 spf: 10,185'-10,196' (11') (Ref; BHCS/GR, 2/15/80) 10,206' -10.,21.7.' (L!') (" " " ) 10,227'-10.,240' .(.13') (" " " ) 10,250'-10,270' (20') (" " " ) 10,280'-10,305' (25') (" " " ) 10,317'-10,336' (19') (" " " ) Put well on production. August 1, 1980: Shut-in well in preparation for static pressure survey. August 3, 1980: Ran static pressure/temperature survey at 8800 ft. TVDss. August 3, 1980: Set and tested insert sleeve and SSSV in ball valve nipple ca. 2000 ft. Well on production. 14' I hereby certify that~e ~J~ a~ ¢°rtect //? ~"~ 4 ~ SIGI~ED-., l~~~, // %~~ TITLE Dis~ict Field mgineer DATE ' /~ ~5~- ~ ~q~ ~ ~y/ - . ~ ,,, ~ --/~, , , mu~e filed in duplicate with the NO E--Report on this' form is required for ch calendar month regardle~ of the status of operations and oil and gas conservation committ~ by the 15th of the succeeding month,unl~ otherwise directS. SOHIO ALASKA PETROLEUM COMPANY July 15, 1980 State of Alaska Depar~t of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99509 Attn: Mr. H. Hamilton Subject: Wells D-10, C-14, C-15, X-5, Y-6 ., TELEPHONE (9~7)26~-EN0 ~ ]__ ~ STAT T~C~ ~J STAT TEC~ , Enclosed ~lease £ind in ~±plicate form 10-403, Sun~ Notices Reports on wells for the above re£erenced well. Enclosures CC: S. R. Bundy A. E. Leske Drilling File Very truly yours, SOHIO PETRO~ CO. District Field Engineer Fo rm '10-403 REV. 1-10-3'3 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for prol~oSals to ¢lrill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL LJ OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Cc~Danv -- _ 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 4. LOCATION OF WELL At surface 363 ' SNL, 5220 ' WEL Sec. 8, T10N, R14E, UPM 99502 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 74.18' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL. CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN. ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. X-5 (23-06-10-14 ) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool ].1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM ].2. PERMIT NO. 79 -104 )ort, or Other Data NOTICE OF INTENTION TO: TEsT WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L...U MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Coml~letion or Recompletion Report and Log form.) 15. DESCRY'BE.PROPOSED OR COMPLETED OPERATIONS. (Clearly state all I~ertlnent ~letalls, and give pertinent dates, including estimated date of starting any proposed work. The following intervals will be perforated during July/August, 1980, using Schlumberger 2 7/8" hyperdome at 4 spf: 10,185' - 10,196' 10,206' - 10,217' 10,227' - 10,240' 10,250' - 10,270' 10,280' - 10,305' 10,317 ' - 10,336 ' (11') (ll') (13') (20') (25') (19') (Ref. BHCS/GR. 2/15/80) (,, ,, ,, ,, ) (,, ,,, ,, ,, ) (- - . . ) (- - . . ) (Ref.BHCS/GR 2/15/80) A SSSV will be set and tested in the ball valve nipple ca. 2000'. Subsequent Work Reported 16. I hereby ce h is.true and correct /" C~_ ,T.~ Pl ~ .qc~-n %1 _ (This spac~"~ for Stat~"fflc_~se) //~/) ~/ ' /P~.d COMMISSIONER CONDmONSOF~PROVAL IF~Y: BY ORDER OF THE ~ See Instructions On Reverse Side DATE l, lro Approved Returnej::l SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company . . SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT/STATE REFERENCE: .... j COMM-;:r-' J~J"-~..._~.NL~,~i~-.~J'~'3111 "C" STREET I J ~]G~JNCHORAGE, ALASKA .......... ~~l L: POUCH ' SFO ' . / SOHIO DATA //cThe following material is being submitted herewith. Please acknowledge receipt by signing opy of this letter and returning it to this office:- A-2 SFO/UNIT/STATE: C-7 FINAL CASED HOLE: E-2 (-Marathon) F-13 J-1 R-2 R-5 R-6 R-6 PRESSURE SURVEYS ::D-i~, '~¢~'~' - ,-- / E-4J Spinner 3/8/80 #1 EPA 3/3/80 #1 EPA 3/7/80 91 Temp. Log 3/4/80 #1 Spinner 3/7/80 #1 DDNLL 3/3/80 #1 TDT-M 3/14/80 #1 TDT-M 3/13/80 ~1 EPA 3/11/80 #1 Mudlog 12/25/79-1/23/80 Temp. Log 3/5/80 #1 Spectralog 2/20/80 #1 Bottom-Hole Pressure Data Form& 11 2"/5" (1 LOg) 5" 5" 5" 5" 5" 5" 5" 5" Survey 3/10/80 (Otis) " 3/17/80 (Go) " 3/16/80 (Otis) " 2/11/80 (Go). Caro rle er Well Records , RECEIVED DATE SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT/STATE REFERENCE: , SOHIO DATA ,~?he following material is being submitted herewith. Please acknowledge copy of this letter and returning it to this office:- SFO/UNIT/STATE: 'INAL CASED HOLE: (-Marathon) A-2 C-7 E-2 F-13 J-1 R-2 R-5 R-6 R-6 X-4 NW#1 Spinner 3/8/80 EPL 3/3/80 EPL 3/7/80 Temp. Log 3/4/80 Spinner 3/7/80 DDNLL 3/3/80 TDT-M 3/14/80 TDT-M 3/13/80 EPA 3/11/80 Mudlog 12/25/79-1/23/80 Temp. Log 3/5/80 Spectralog 2/20/80 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 4/18/80 #110A 'RESSURE SURVEYS: D-1 E-3 E-4 H-7 Bottom-Hole Pressure Data II II II II I! II II II II !1 II II Form& I! I! receipt by signing a #1 5" 01 5" # 1 2"/5" (1 #1 5" Mi 5" #1 5" # 1 5" 01 5" 01 5" 01 5" #1 5" Log) Survey 3/10/80 (Otis] " 3/17/80 (Go) " 3/16/80 (Otis', " 2/11/80 (Go) Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: STATE OF ALASKA 3111 "C" STREET ~,NCHORAGE, ALASKA !LEPHONE (907) 265-001D0 MAIL: POUCH 6-612 ;HORAGE, ALASKA 99502 3/24/80 #075 REFERENCE: SOHIO FINAL LOGS following material is being submitted herewith. Please acknowledge receipt by signing a copy of this le~er and returning it to this office:-- X-5 FDC/CNL 2/15/80 X-5 FDC 2/15/80 X-5 BHCS 2/15/80 X-5 DIL/SFL 2/15/80 X-5 Gyroscopic Survey 3/6/80 #1 #l #l #1 5" & 5" & 5" & 5" & 11 2" 2" 2" Well Records SOHIO ALASKA PETROLEUM COMPANY March 24, 1980 Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Well X-5 (23-06-10-14) 3111 "C" STREET ANCHORAGE, ALASK TELEPHONE (907) 265-t~ MAI L: POUCH 6-612 ANCHORAG E, ALASKA /-..~ l 1GEOL ~o'~ 2 GEOL ~ J 3 GEOL ~ j--STAT TEC-- STAT~ I' I - --! [ FI L F.-- ............ 1 Enclosed, in duplicate, is Form P-7, Ccmpletion Report, for the above-namedwell together withtheWell History, Well Logs, and Directional Survey. This well has been suspended pending perforating operations. AMR:ja Enclosures cc: Well File ~17 Geology Yours very truly, A. M. Reid Acting District Drilling Engineer Form P--7 SUBMIT IN DUP .~. £* STATE OF ALASKA (See other In- structions on reverse side) PI L AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRY r-] Other b. TYPE OF COMPLETION: NEW ~ WORK r--I DEEP- PLUG r--I DIFF. [---I WELLIZ~4~ OVER I I EN r'-] BACKI I RESER.I I Other 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, AK 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM At top prod, interval reported below Top Sag R. SST. 2097' NSL, 2927' WEL, Sec. 6, T10N, R14E, UPM At total depth 2678' NSL, 3145' WEL, Sec. 6, T10N, R14E, UPM 5. APl NUMERICAL CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit ,X_~.5LNO' (23-06-10-14) 1-0-~. FIELD AND POOL, OR WILDCAT Pructhoe Bay, PrufLhoe Oil Pool 1. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 3ec. 6, T10N, !'LI4E, UPM 12. PERMIT NO. 79-.104 1-29-80 2-14-80 2-26-80 IKBE = '~74~;18 ' ~%SL 40.28" ~AMSL 11029's' TOTAL, MDDEPTH,9574MD& TVD ,19.,____, DEPTHPLUG BACK MD & TVD,20.__ IFHowMULTIPLEMANY. COMP L.,II~i'~~ ROTARY TOOLS INTERVALS ~DR ILLED BY CABLE TOOLS 10980'MD 9535'q~h Total 22. PRODUCING INTERVAL{S), OF THIS COMPLETION -TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL '-. SURVEY MADE None Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/GR, ~ BHCS/GR,. FDC/CNL/GR/Cal CASING RECORD (Report all strings set In well) 25. CASING SIZE 20"X30" 13 3/8" 9 5/8" 7" 26. SIZE 28. PERFORATIONS OPEN TO PRODUCTION None I WEIGHT, LB/FT. / GRADE / DEPTH SET (MD) Insulated (~onduct~r 110 ' 72~ ! L-80! 2669' 47~ S00-95/ 9R45 ' I LINER RECORD (Interval, size and number) HOLE SIZE 36"' 17~" CEMENTING RECORD / AMOUNT PULLED 10.6 cU.yd~. ~cticse~ 3839 au.'~'l-.. SCREEN (MD) 127. .TUBING RECORD SIZE DEPTH SET (MD) PACKER SET {MD) 5%" 9400t 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30. PRODUCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumDIng--slze and tyDe of pump) I DATE OF TEST. I HOURS TESTED CHOKE SIZE I PROD'N FOR I TEST PERIOD FLOW TUBING ICASING PRESSURE CALCULATED OIL-BBL. PRESS. I 24-HOUR RATE 31. DISPOSITION OF GAS(Sold, used for fuel vented, Gtc.) 32. LIST OF ATTACHMENTS O I L-BBL. GAS--MCF. I I WELL STATUS (Producing or shut-In) GAS--MCF. WATER-BBL I GAS-OIL RATIO I I I lOlL GRA?ITY-API (CORR.) WATER--~;,L~ ~¢~'-" !~ / i · r' ~ ITEST WITNESSED BY Well history_; well logs; directional survey. Ala_,k~*. ~!! 33. I hereby ce[tify that the foregoing and attached information is coynplete and correct as determined from all available records. TITLE D~~NG ~G~R , A' M, ~In *(See instructions and Spaces for Additional Data on Reverse Side) · : INSTRUCTIONS . . General. This form il designed for ~subrnitting .a complete and Correct well completion report and log on all' types of lands and leases in Alaska. ' ' ' Item: 16: 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. · Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately prod.uced, showing the additional data pertinent to such interval. · ...... Item: 26: ,Sacks Cement": Attached supplemental records for this well should show the-details of any multiple stage cementing and the lOcation of the cementing tool. - . Item 28: Submit a separate completion report on this fOrm for each interval to be separately produced. (See instruction for items 20 and 22 above). . : · - -34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, , .. . WATER AND MUD . -- 35. GEOLOGIC MARKERS ~ - :' - - - NAME "' "~i '- : ,,, MEAS. DEPTH TRUE VERT. DEPTI _ · · ~ . · Sag R.'~ SST. 10035' . 8723' . . · Shublik 10053 ' 8738 ' Ivishak 10146 ' 8814 ' . · 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAs OR WATER. . ,. · . . · · · . . . · ~ X-5 (23-06-10-14) ~LL HISTORY January, 1980 Spud well at 0400 hours, January 29, 1980. Drilled 17 1/2" bole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress casing to 2669'. Cemented with 3839 cu. ft. Permafrost cement. Installed and tested BOPE. February, 1980 Tested 13 3/8" casing to 3000 psi. Drilled out to 2720', ran leak-off test. Directionally drilled 12 1/4" hole to 9861'. Ran 253 jts. 9 5/8" 47# Soo-95 Buttress casing to 9845'. Cemented in two stages: First stage with 1420 cu. ft. Class G cement; second stage through DV packer at 2571" with 130 cu. ft. Permafrost C preceded by Arctic Pack. Cleaned out to 9806', i'.tested casing to 3000 psi. Drilled out to 9900', performed formation competency tes. t. Directionally drilled 8 1/2" hole. to ~ Ran open hole logs. Ran 43 jts..7" 29# L-80 .Buttress casing to II027'. Cemented with 564 cu. ft. Class G cement. Cleaned out to 10980'. Tested casing to 3000 psi. Displaced w~ll to NaCl , ran CBL. Ran 5 1/2" ~letion string to 9400', set packer at 9284', tubing would not test. Perforated tubing above PBR, pulled tubing. Pan 217 jts. 5 1/2" 17# 8rd AB mod. tubing to packer at 9284 '.. Landed ~ v~ Installed and tested tree. Dis- placed tubing . Tested tubing to 3500 psi. Released rig at 1400 hours, February. 26, 1980. <' spemm -sun d. A. Fouch~ President March 13, 1980 Mr..GaryPlisga Sohio Alaska Petroleum Company 3111 C. Street Anchorage;.~ 99503-~.~ Re: Our BossGyroscopic-Survey~ Job No.,' Boss-16554-- Well--X~5 Prudhoe Bay Field- North Slope, Alaska Date of Survey: March 6, 1980 Dear Mr. Plisga: Please find enclosed the "Original" and sixteen (16) copies of our Boss Gyroscopic MultishotDirectional Survey On the above well~-,~./ Thank you for giving us this opportunity to beof service. Yours Very truly, SPERRY-SUN, INC. Ken Broussard District Manager KB/kc Enclosures P ETR CLE U~' SPERRY-SUN WELL ,_':;URVEYING -CcpP-~NY ANCHORAGE, ALASKA C F~ ~ r' A kY COM~UTATIO~ DATE ~RCH 12~ 1980 P/~GF .1 LATE OF SURVEY M~RCH G, 19~0 L!OSS GYROSCOPIC SURVEY ,,0~ NU~,P_,CR B0SS~16554 KELLY P, USH~NG ELEV. = 7~.1~ FT. TRUE SLJ .~-SEA 'E'~gURED VERTICAL VERTICAL DEPT~ DEPTH DEPTH ...... C OUR.S. E ............... C ~ U B~S.E ................ DO G ,L E G INCLINATION DIRECTION SEVERITY DEG NIN CEGREES DEG/1 O0 TOTAL gE CTAkGtJLAR COORDINATES NORTH/SOUTH EAST/WEST V['~T zC~'L SECTIu'~ 0 0,00 -7q, 100 100.00 25, 200 200. OD 125. 300 29q .q9 225. ~OO 399,0,9 325, ~- ..5.0.0 .........._~99..S 9 z~25.8 GOO 5~q.9~ 525.~ 700 699 ,~R 800 799.9H 725 900 899,97 g25,7 lOOO 999,97 325.7 ]]OD 1099,75 1025.7 -.. 1200 1199,9q 1125.7 1300 1299,5~ 1225.7 1.40.0 .......... 1399.92 1~25.7 1500 lq99,91 lq25.7 1600 1599,90 1525.7 1700 1699,89 1625.7 ' ~8'00 ' ........ 17'99"~R .............1'725,7 ~900 1899.g8 J~25.7 ' 2i'0''0 ................ 2099,87 ........... 2025,6 ;zoo ~.~7 2~s.~ ~.~,C O ~.~ .....~7 P22 2qO0 2399.8~ 2325.~ 2500 2~99.R3 2~25.65 260,0 ............ 2,~.~.~, 81 ................ 2525 · ;70o z~9.78 2~2~, 2RO0 2799.7~ 2725. C9~[, 2899.G2 2~25. ...................... .._ 3000 2999,10 2924, S 4.12 W 2.33 9 O 57 N 43.79 E .q7 .97 S 3.2q 7 0 51 N 46.50 E · 10 1.05 ,N 2.12 6. n ~ 3 ~' .. ~ 7~,59 E ,q6 1.69 N 4 0 50 N RO.I. 9 E ,06 2,10 N 1.77 3 O 4~ S 37,19 E ,~8 2,19 N 3.19 ~ 0 53 S 87,19 E ,09 2.12 N i O 51 S g2.30 E .09 1.9~ N O ~ 0 3~ ~ ~1,30 E ,10 ,RS -=~ ~ ~ ' ~ .... s'~S."$~ ..... E" .................... ;'~ ..................... .z2 ~ .....~.~7 90~ 2I' h 27,HO E ,33 ,qB S 10.05 ~ ~_~ ..... ~ ............... ~'. ....... ~..7_L~ .... ~._.. . ~7 .3 ~ s ~ o .7~ ~ S 37,80 E ,7A ~,~6 S 13,57 63 1~ S 66.i9 E ,09 3.2~ o 1~,91 SO ....... i ~ ................ S'"'~"9-~-'O E ................ · $i .............. -~,~2 S ............ -i"~']-'4~' N ~1 2C E 2 57 ~, . ~s"~ 7 ..... i~ ....... ~':"~'3"~' g~ ................ ~.oi ............. ~.iz N ........... ..'~'~' . ~ ., , 2-30 2.2A 1.P6- 1.05 .IA -.81 -1.9~ -30J..~ -5o2~ 27.02 -7,62 '.'0.9 ~. -10.~4 -1~.~5 iI5.~'+ -15.9~: -ll,5'Z -1.5q SPERRY -SUN WELL SURVEYING CONP ANCHORAGE,, ALASKA ALASKA DETRCLEUY CC~,'PANY COF'.PUTATI O~ DATE pDUDHCE F',ny MARCH 12, 1980 ~LASKA gATE OF SURVEY MARCH 6, 1980 EOSS GYRO$COFIC SURVEY . UOP NUMPER B9SS',,'16554 KELL__Y,_.O_~SH_I_NO_._EL_EV. : 7A.1~ ..... FT. -, TRUE ~t,B SEA COURSE COUDSE DOG-LEG TOTAL ~EASURED VERTICAL VERTICAL INCLINATION EIRECTICN SEVERITY RECIANGULAR COORDINATES DFPTH DEPTH DEPTH DEG l~Ik DEGREES DE6/1OO NORTH/SOUTH EAST/WEST . ) ~]~'b ................ ~'~¥'~' g2 ........... ~,-o'~'~ .7" ................ ~i~''"~'~ ................. ~ '--~'~' .... o ~'-~ .......... T"~'-~Ti 6 ','.i g' g ~--N-'~ 1 · 3 o ~ 320D 5196,D3 3121.85 11 57 h 55,10 W 2,03 30,3~ N 16,55 W 3300 3293,&3 3219.45 13 8 N 53,60 W 1,23 43.01 N 34,21 ~ 3~00 3390,49 33~6.31 ~5 34 N 53.79 W 2,~2 57,69 N 54.~9 W 3500 3486,30 3~t2.12 ~7 37 ~ 55.79 ~ 2.14 74,13 N 77%55 ~ 3~ 00 3PO0 56,2.9 W t,~A 91,90 SECTIO~'~ 13'79 32 ,'""~ 79,02 107.2.n 158,67 172,6~ 209,67 3873.~8 28 7 N 56.20 .W 2.24 180.91 N 235.5,9 3960.50 30 52 N 56.39 W 2.75 ;-08.23 N 276.56 ~'i~-n¥'~'~' .......... ~g--'-~-? ............. ~j .... ~5Ti'd-'~' ............ i";~5 ................ ~,.'7'O";'~'g -~ ......... ~ ~H, ~2 4207,90 Z5 57 ~ 5~,70 W ,28 .~i .... 30A,16 N 416,26 A2Hg.0I 35 39 N 54,39 W ,35 338,09 N A63,91 ~51.34 ]5 57 N 53.79 ~ .3~ 406.59 N 558.55 A532.3~ 75 5q ~ 52.89 ~ .53 44Z.62 N 605,63 4Gi3.zg. ~. zS~. aG. N ~z.3~.~ W ,32 476,73 N 652,47 385R,59 37R4,41 25 ".55 N ~.6,20 2,6~ 155,65 N 197.B6 W 2~0 67 295.~2 343,95 306.23 =000 4768.69 4694.51,,~,.~ 35 47 N 52,50 W .53 511.0 5100 . ASAO,82 4775,6~ 35 . 4a N 52,70 W ,13 :' 5~7,4 61~.2 *50'6 ................ ~ffT;'s¥ .........S i 0 [. 7 s ~-g ......... ~ ...... ~ '6 ":Jg'6-W ............... ."~ ?-': ......... .g.J ~ ,,7 ~ ~2.7.,,. W .19 725 3 c ' ~4 4 ~ .~ ' ~ ' o ' ~ ' ...00 J~98,44 Jq24.26 ~~ 50 ~ ~3,20 W .27 ~;31 ,2 ~,OOO 5579,60 5J0o.42 ~~5 '5 ~ ~3,3. W ,21 ~6E.,1 cO1,1 ~i00 ......... i~g0-;"8~ .............. 5~S~,.~5"~ .... ~ ........... ~' .... ~-;--'~ ...... ~ .................. ;'2. .............. . ~53,3~ 511,32 569,2~ 627.rjl 6~5,0q 74_3 .-~"~,.. 801.- _ 6 N 699 ,lA W 859,55 6 °N 745,58 W 917,67 a N 837.62 W 1033,1o 3 N 883.7g W 1091.15 930.12 W 114S.41 976.89 %, 1207,90 1.~23,77 W 1266,~9 1070,95 W 1324.91 11I~.04 ~ 13&3.20 11 ~..~e u 1 AA i.2i .................................... ~'P'EFR';f'" SUN UEL'I.''' LsO-F~-I~-Y~N'~"'-cc;I~P-Ai~[Y .... ' ................ PAGE' 3 AN CP:ORAGE,~ ALASKA F.¢,PIC..ALA~I<A...PETROLE.L~' C.CPPANY. ............................ . .................................................... :~ ..... DATE OF- SURVEY MARCH ~, ~8,~ .... X-5 COFPUTATIO~ DATE EOSS GYROSCOPIC SURVE'Y PRUDHOE E~AY ~ARCH 12. 1980 ~OE NUMBER GOSS~16554 ALASKA KELLY BUSHING ELEV. = 7A.1H FT. .......... ~:~ TRUE St;B SEA COURSE CoUR~- - . ....................................... eE ............... D O.G .'_.L_.E G. ............. TO TAL MFASURED VERTICAL VERTICAL INCLINATICN F. IRECTI CN SEVERITY RECTANGULAR COOR£INATES DEPTH DEPTH DEPTH DEG K~IN DEGREES DEG/IO0 NOR'TH/SOUTH EAST/WEST ......... '~'~"~'-0- ............. ~ ~"4' 1"."'9"~- ............... ~'6 7.7 ~ ............. ~. ~5 ...... 5.2. ............ ~" '6'~";'-~"0-~"-- 6300 5822,79 574P..61 ~6 13 N 52,70 W ,41 6400 5903,50 5829,32 3~. 9 N 52,39 .W 6.500 5983,~3 590~.£5 ~7 42 N 52.20 W 1,54 66'00 6062.15 5987.97 3R 26 ~ 52. 0 W .75 V'£~'T i CAE - SECTION 573.75 fl 3305.26 W 1615,~74~ 1L4~.40 N 1399,67 W 1734,21 10~2,2H N 144~,.33 Y 1795,5H ..... 670.o ......... A 1 o. 1_o 6E. O0 6217,28 6143,10 39 49 N 53,20 W 6900 629~02 6219,8~ 2g 56 N 53-10 W 7200 652~.~9 6~50, O~ ~9 ~9 ~ 53.60 7~00 6601,15 6526,97 39 32 N ~2,89 W ,53 6@65,"]2 3° H N 52,10 W ,70 1i20,80 N 1297,73 W 1857,93 1159.37 N 154B,27 W 1921,12 1197,82 N 1599,51~ W 19M4,83 N ......... ..... 127~.25'--L ....... ~7'02.6R W 2~12.22 1312,a0 N 1754.14 ~ P175.H2 1350,61 N ~805,30 ~ 2239.22 7400 6678,37 6604.1q 39 22 N 53,20 W 7500 6755, 95 66~1.77 Z8 52 I~. 52,29 W 7601} 6H34,17 6750.99 ~ 1I N 52,39 W 7700 6912.96 6838.7~ 37 50 . 7800 6992,22 691t!, OA Z7 17 7900 7071,61 69q7, a.~ 37 35 FO00 7150 72 7076 54~ ~7 A9 e]o0 7229.65 7155.~7~ 37 55 P2OO 7308.62 7234,44~ 37 51,60 W ,60 1502,96 N 2004.16 V 24Hg.,3q 50,70 W ,77 1541,20 N 2051,65 W 2549.11 50.H9 W ,31, 1579.63 N 2098.76 W 2609.,~.~ 51,10 W ,.27 161'8,12 N 2146,30 Y 2670, 51, 0 W ,12 1656,72 N 215q,05 W 2731,93 50,~9 W ,17 1695,3P.'N 2241,70 W 2793,.10 S'~O0 7467,38 7393,200~6 55 N 49.10 W 1.10 1773,05 N 2.335,28 W 2914. PF. O0 7547,97 7473,79~~5 39 N 49.50 W 1,29 1P. 11,G5 N 2380,15 W 2973. ........... ~(:'00 ........ ~628"'~'~ ............7'5~-4'7"0'~'.'-~"6 ......... i'9' ............. ~i ..... ~'F;6'O' W' ........... :' .85 ........ 1 ~50, l'7"-N ........... 2'~2'-~'"5~TM ~'0'32 · H700 7709,92 7635,74~~5" 25 N 47,39 W 1,14 1R~9,37 N 2468.08 W 30~0. 7791,2~ 7717,~2~~5''' 49 N. qT,lO U ,45 1928,91 N 2510,85 W 314q, 78'72;5"3 ................... 7794'.'~'g~"'~"-'~ ......... '~' .... ~7, ...... 6 ..... U .................... ;5~ ........... 1568'"54-'N' .......... 25~'3~'~'~-"~ ............ 3207. gO00 7gSS,lg 787g. G1''----~ ~5 5H K ~5.10 W 1,29 2008,g9 N 2595.38 W 3265. qloo ~034.73 7960,55__~"___ 57 N 44,20 W ,53 2050,7~ N 2~36,66 W 3324,24 .................... ~2-60. . ............. ~'i"i ~';"~5~ .............. ~'04"i';"i"~"~ ..........Y~--" ..... ~'4 ........... K'"""4~-~'~9 .... W .................... ;6'~ ............ 2"0-~'~.'~ 3--N .......... ~677 · 75 U 33~3-T34 .... 57 27 2~ 5~ ALASKA PETROLEL, F E ~.-; A Y ANCHORAGE, ALASKA CCKPANY CATE OF SURVEY MARCH_6~ ..1.gRD ............ CO'D, PO'~iA~IO'K DA'IE ~OSS GYROSCOPIC SURVFY ~ARCH 12, 1980 dOB NUMBER BOSS-~655A ............................................ ,K_,..~L.L_Y. B. u S.H..I K! G __E L E _V_, .... :._ _. 7 A. 1 P_.. F T. , TRUE SUB-SEA COURSE COURSE DOG-LEG TO TAL '~EASU~ED VERTICAL VERTICAL ....... ~' N'~ 'LI N"X'~ 'z ~-~-" Ei ~R~ '~"T' i'C. ~~ ....... ~'.F~/'~'~ ] l'Y ....... -R'~'L'T'~ N ~u L A R .... C6 °R'~'i"N-A-T E~ DEPTH DEPTH DEPTH DEG. MI~ DEGREES DEG/lOO NORTH/SOUTH EAST/WEST SECTION .................. "~'~ 6"0 ............... ~'~"9 ~:';' 7'~ ......... 8'iD J,'6~ ................ f~T:': :~'~'~ ....... ~":-'~3 ~ ~-" ~ ,~9 ~'J~:2i36,39 N 2718,68 ~00 8276,59 8202,A1 35 .:',.5~. N 42,60 ~ ,62 2179.51 N 2758.~2 W mSO0 8357,8q 8283 71 3-5 "22 N A2.20 W .54 ;':'.2222.51 N 2798.09 W 3559. PTbO 852~.6~ A4~7.50 74 40 ~ 4~,20 W ,42 2~0~,2G R 2874,36 n~OO 860a.10 ~"~ ~'~ ~/' 18 ~ ~0,60 W ,5.0 ....... 2~51,06 N 2911 ,A4 W 3730,26 9900 8686,67 8612,Aq ~4:..-:::-:22 N 77,~ W 1,52 '.~ 2~9A,7~ N 2947,12 W 5786,2n ., I - "/?' ~ ' '~ ~ ' :'~ ' '- ].OODO ~76~ q5 86q4,77 3A.::,~._,,-7:- ~ ~7,50 W 5,74-:~.-~--~442,56 N 2977,68 ~ 3P41.28 ................. ~'oi 0'0 ............. ~,'~ so. ~ z ........... ~7 7 G. ~ 3 .............. ~'~"'T'~ .............. K-'- Y~,, ~'o''''~' .................... ~'-; 6-~ ........ 2q' ~'~', ~ ~'" ~,~ ....... So o ~'. s ~-'~- ........... s~ ~s. ~ 7 10200 P~31,22 8857,04 Z7 0 ~ 22, 3 U 1,61 2549,31 ~ 3025,fi9 W 3949,16 10~00 9010,03 R~35.85 38 57 N 22,29 W 1,~6 260E,.30 N 30qR,29 .... ~ ..........~D05.21 lO,OD 9086,77 9012,59 40:47 N 23,26 W 1,94 266~.,A1 N ~073,0fi 1~500 9162.~2 ~088.6~ 40 '-10 N 21.10 W 1.50:,: L.,~., 272~.53 N ~097.57 ~ a123.~ 10600 923q.25 U165.07 qO:'/i '8 ~; 20.10 U .~5 2785.R9 N 3120.25 ..................... 1"'0700 9316.13 92A1.95 ~9 22 N 1P.g.° W 1.09 28A6.16 N 31al.60 W AR3I~.~J1 ~OgO0 93~3.78 q319.60 ~8 q5 N 1~~, O W ,.84 25~5.~3 N 3J~1.55 ~ e293.62 10900 9A72 03 ~r~ p = : ~ .. ' q = .......... 10950 9511,~6 .... ~37,'i~ ......... ~-~7~"~':: ....... ""O' ............. N'-'~7,-i-O'-' W ........... -~'"69 ~9~,~i~ N 31qo,~o ~ ~375, .... H'~R'i'ZONTAL DISF'L~CEh[..NT - TH',"'46-'~'~';'T--~'O--"~'I~; ~EST' AT MD''="~'1029 ............ 0 .T FEET AT NOR TFK CALCULATIOk PROCEDURES ARE ~~'ON THE USE 0F THREE DIMENSIONAL R.~DIU.S._O_~__.CURV~TURE NETU_~D_, ......... ANCHORAGE, ALASKA SOI~,'!c ALASKA PETROLEU,."~ CC~'PAK. Y ' ~'~' DATE OF SURVEY MARCH 6~ 19~9 X-5 COFPUTATiO~ D~TE PPUDHOE BAY MARCH 12~ 1980 dob NUM~E'R BOSS~16554 A.L._A.~._~A ................................................................................................................... KELLY BUSHING ELEV, = 74.1P FY. FOR EVEN__ZD. OO_.~.EE_T_.OFi MEASURED DEPTH. .............................................................. TRUE SUB-SE A TOT~ L ;"E A ~t!RED VERTICAL VERTICAL RECTANGULAR COORD INAlES PD-TVD -' PEPTH ............... ]~'E':P-¥i~ .......... B-ED TH ......... N¢'R~:'H:)'S;'~UT I~ ............. E-AS T/WE'-~'~ ........ '~"~"I~F E:.-P'E N CE VERTICAL CORRECTION 0 O.,O0 -74.18 0,00 O. OC ' O.UE~ J ODE, 999.97 q_25,7.9 20'00 1999 · 87 1925.6.9 70 O0 2999.10 292fl, 92 aC, O0 3947.66 3~73.~8 ~t; .q 0 a76A.69 ~694.51 ¢ O00 5579 · 60 5505 · a 2 7COL' 6370.69 6296.51 ~00 7150.72 7076.54 900U 7953,79 787q,61. ~1000 q550.76 11029 9573,62 .07 S 3,2 8.12 180.~1 N 235,5 511,56 N 69'7, 1 4 W .03 ~ E .1",, .Oq.. 2 E .9[~ .77 9 W 52,3~ 51.44 4 W 231,31 178,97 W ~, ,~ 2 '~ ....... 6 ~-9o3 i ..................208"§'1 ............................ 2008.9~. ? ." 7 7 .......................N 9476.58 3023,90 THE CALCULATICh FRCCLDUF~ES ~E BASED ON THE USE 2595, 38 W 1046,21 196.97; 2977,68 W 12'31,05 184,84 31~q 46 W 1. flq9,24 212,1° 3204,71 W ia55,.38 6.15 OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. SPERRY-mUN wELL SURVEYING COPPANY ANCHORAGE~ ALASKA ¢C'H!O ALLSKA PETEOLELP COMPAD~Y x-5 CO~iF;UTAT ION DATE PPUFt;F;E BAY PARCH 12~ 1980 AL ~$ K~ , PAGE EATE OF. SURVE.Y...P.ARC_H..G, .1980 . . d(D[~ NUMP, E'R BOSS-.,16554 KFLLY .BUSHI~..'G~__E..LE.¥_,..: .... 74_., 1~ FT. I ~'~!T ER P OL ATEO_.. V.~LUES F.O.~.~EVEN .... SUB-SE'A DEPTH · T R U E S U [~ ~F ~,SURED VER TI'C/~L VERT DEPTH DEPTH DE O 0.00 -74 7. 74.1~ 0 · 174 17~.18 lC(1 274 27A.1A 200 374 37t~. 18 300 A74 474.18 AgO ET~ 574,18 500 ....................... 67~ .... G74,1~ GC,'J 774 774.Z8 700 1074 t07~.1~ 1000 117~ 117q.18 1100 ~Z7~ lS7~.IA 1SOO -SEA TOFTAL ICZtL RECTANGULAR COORDINATES ~P-'TVD PTH N C-~ T'~i·/S C, u'F'H ............... EASTTWE:sT .... PI FF [r.:.EN .. vE ,D T I C AL CE. CORRECTION ,]g 0.00 ' D, O0 .~ .3~ S °57 .00 ,~0 S 1,2p._~ .......................... ,ul . ~ .0 "0 1,27 S 2,04 W ,01 ,0 · CO 1.49 S 2,77 W ,~1 .0 ~ GO · 0 ~ 1 52 S 4.3H · gO 1.73 S q'.6~ ~ -02 ,0 ,nO.. 1,10 S q,2~ ~' ,02 .0 · 00 1.63 N 1.28 W .Ob .0 · OO 2.03 N 1.39 E .07 .0 1474 lZ~74.18 14~(), O0 ~ 2.21 N 2,83 ] 57 ~ ................. i"fi~"4-;"i"~ .......... i s o o. c~ 0 .................... '~-~"i'T-'~-~ ...... ' ............... ~. ~'~' 177A 1774.18 1700.0G ~ 1'72 N 7.15 E .................. sPERF. Y:',SUN"~-NF'.-['C ~U-Rg'E-YIN'G ...... (~'Cpp'A't~.:y-' ' .......................... PAGE 7 ANCHORAGE,~ ALASKA .. PETROLELP CC~Pt, KY [:ATF CF~ SURVEY . CO~.~DUTAT / ON DAlE ~AF:CH 12~ 1990 dOB NUMBER BOSS~16554 KELLY BRUSHING ELE~,__~_ ..... 7.4,~H FT, ~L~SKA ................................................. : ~' C;141 P. ALA~ I'> F, _~ ""[.' I, ,.: H(i ;: A Y .................................................. INTERPCLa TEF, 1DO,_FEET,_OF,, SUpT,SiEA ...... ULP_,!H TRUE .RUB-SEA TOTAL · ~'~ ~ ~'~m if D V£RTICAL VERTICAL RECTANGULAR COOFDINATES PD TVD DE'PTH OCPTH PFPTF NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION ._ !67q I~74,18 1800.00 I,g5 N 7,92 E ~ :. ,12. __ 197A. 1 m 7 a · 1L~. ! q 00, 00.. ,37 l~ ~,61. E' ,1=., 207~ 207~,1H 2{]c~9.90 ,08..~ c.33. E .1~, ,00 2174 217q.lR 2190.00 ................................ ,.fl~ ...... $ ............. 9. ~ 9 ._.E ......................... t. i3 ........... .00 ...... 227~ 227~.1~ 220g.00 .~9 S 10.5~ E .1~ .00 2~7q ~37~.1~ 2~0.00 .27 S ll.53 E .i~ .01 2ATA 247~ 1{~ 2400,0~ ~ ~ ~ ~' ' ~ 23 E .16 ,02 257~ 257~,1/~ 2500.00 2,77 ~¢' 1~,56 E ,18 ,02 267~ 267~,1~ 260~,00 .... ~,~.. S 16,02 E ,21 277~ .... 277.~, 1R 27n0,00 .................... 4.,79 S ...... 17,6i.E ............................ ~$~ .............. 287A 2874,1~ 2H99,00 1,06 S 17,25 E ,32 ,0~ 297~ 297~,18 290C,00 5,9~ N ll,SG E ,72 .,=075 3074,1~ 3990,00 15,79 N 1,80 E 1,72 ~177 3174,1P. ~IDO,O0 27,6~ F~ 1~,7~ ~2 3,~9 1,77 5280 3274,1P, 32gO,Dh 40,Z. 2 N ~0,55 W 5,84 2,36 33H3 337a.18 ~3e0.0O 55.01 ~' 50,53 W 8,8~ 3.0~ 3487 3q74.18 3A0~,O0 71,9G N 74,36 N 13,10 4,21 3592 357q,18 3500,0~ .:~-9 0 · 5 Z~ N 101.92 .... ~ ~;.~ ........... ~3~ ?~, .~.~ ............ 3 ~ o o..~ ~..:.: ............... ~&~P-~-.. ~ .............. i ~_ 2. ~...~.~ ?CHIC ALASKA PE'[KOLE'U~ COMPANY PFUPHOE RAY ,,RY .... LN :~.:,_LL SURVLYiNG COMPANY ...... ' ..... ANCHORAGE, ALASKA COMPUTA'Y!6r~' DATE M~RCH 12, 19HO [;ATE OF SURVEY MAH, CH 6, ,JOB NUNF'F'R DOSS%]6554 KELLY ~USHING ELEV, = . PAGE 7a.lH FT. INTERPOLATED VALUES FCF EVEN 100 FEET OF SUB-SEA DEFTH TRUE SUP-SEA ,F~.eURED VERTICAL VERTICAL DF PT H DE P TH DEP TH ,,=807 377~. 1~ ,= 700. ~0'30 3~7~. 18 39g0. alA6 ~07A.18 AOOO. a266 4174,18 4100. A$~O A27A,18 4290, a515 437~. 18 aC-Z6 4474.18 4000. 476P 457~,18 ~SOC. a 8,~., 3 4674.1g 4600. 5~06 4774.18 ~700. E 130 a874.18 ~8Og. ~252 t+g74.la 4900. 537~ 5974.18 5000. 5622 5274.1H 52g0. 57~6 557a,18 5P, 70 5474.18 5~OOJ s993 5574,1R 5500. TQTAL RECTANGUL/~R COORDINATES MD-TVD VEPTICAL NCRTH/oCUTH EAST/WEST DIFFLRLNCL CO RECTION O0 13~.01 r!. 1A5.74 t,' ~2,95 _ O0 159,P6 N 204,i5 W ~5.15 OO 188.c5.. N 2~7,6'~,., 09 221.74 N 296. H0 W 72.21 no~ 25~.'7_. . ..,N 352.42 W c~2.68 O0 300.8~., N. 411.5P W 116,06 O~ 542.67 N · 470.32 . O0 ~27.51 N 586.97 W 1~5.95 O0 ~70.S8 N 644.73 }~ 209.32 O0 r;l~,Z7 N 782.2P W 2c2,59 O0 55a.08 N 759.52 ~ 255.8~ O0 601.56 N 815.6~ ~ -278',~6 O0 645.14z'"J~ ..............87'2.67 W OO 689.29 N 920.66 W 324,84 C9 ~ 733...37 ....... ~ ............... 987,~9 W O0 ~ 777.42 N 1045.62 W 372,25 flO ~.20,75 N 1104,01 W ..... 5,89 g "'l ~ ~ A 6=~ . 24 N 1161,76 7 lO 12 2 ,-~ 23 23 23 2' 23 23 23 22 23 25 23 23 · 23 .96 ,87 ,1q .47 ,37 ,2q .11 .27 .63 .10 .28 · 6.4 ........................................ ~ .77 .26 SCHTO ALASKA PETROLEU~ PRUDH6E BAY ALASKA · ' SFERRY-SUN'N'EL"L~ .SU'~V'FYiNG-cGrPAt~Y "' ..... AN£HOR~GE~ ALASKA CONPANY " BATE GF ~URVEY CO~PUTAT ION DATE MARCH ~2, 198n p'~6E dOB NUBBER ROSS~16554 KELLY BUSHING ELEV. = 74.18 FT. I"F A 5: I.? I~ E D ~7q3 713q 739~ 752 3 76,50 7777 ~.156. INT'ERFeLATED VALgES,, E..O..g_...E~EN 100 FEET OF SU.B_-_.S.,.EA .DEPTH ... TRUE VERTICAl_ DEPTk 567'~. 18 577t4. o 18 5~7,~.18 597~o18 6074,18 6174,18 62 7q. 18 6.37~4,1~ 6q. 7~.1~ 657~.18 _ . 667~.18 677q,lA 6~. 74,1H 6971+. 1,1~, 707~.1~ 717a,18 727q,18 737~,18 7~7q .18 ,.~JB,..;CEA TOTAL VERTICAL RECTANGCLAR COORDINATES NB'TVD DEPTH NCRTH/SOUTH EAST/WEST DIFFERENCE 5600,80 5700,00 5~00.00 5900, ~]0 61.00,00 620D,OD G3OO.O0 6590,00 1237.,q3 L ' 1653,47 W 6Zf¢,37 1::2,~7.61 I', 172[i,60 W 660,76 13.37.17 N !7e, 7.54 W ~90.8~ 669'0.00 1386.75 N 185~.34 6700.00 1435.98 N 1917.9q U 749.2~ 7000,00 15A0,~7 r-,: 2i00,30 W R29,06 7100,0~ 1629,56 N 2160, a7 w ~55,5.2 7300.0~ 1727,q0 K 22P, 0.9~ W 906,67 7~30.0.~~ 1776.~D N 233S.14 W 9'~,33 VERTICAL CORRECTION 23,11 23.90 ' 24,62 27,0~ 28,61 30,16 50.q3 3C'.33 }0.15 2n 28 ,8 ~ 27.q6 26.~5 25.92 . 26,46 ,,.,.~. 26,q2 · 25.66 .... S.r'p ~ C pD t~[~' HCE Ar~CHORAGE~ ALASKA * ALASKA PETROLELN CO~P~NY ................................................................................... "..i .... DA.!.E oF SURVEY MARCH .... _6,._!.98D ..... COI~PUTATION DaTE b4Y MARCH 12, 1980 COB NUFBEP BOSS-.,16554 ....................................................... . ........................................................................ KELLY BI_IS.HINO_ELE_V.., = 7~_,.1P,._.FT, INTERPOLATED VALUES'FOR EVEN l gO FEET OF SUB-SEA DEPTH TRUE SUR-S "" El ~ c ~ " . .. .... ,~Eu VERTICAL VEDTIC nE PTP DEPTH DEPT .P?-32 7574,18 75U0, II ~E. 56 767~,18 76~0.U ~.779 7774,18 7700.0 ~9~2 7~7a, 9025 797~,18 '5273 Ii17~,I8 8100,0 ~397 827~,I8 ~200,0 o519 F~374,18 8300,0 ~88~ ] 0128 10253 ~7 ~. 18 8900. 07 .i8 oSi" .......... .17 .i .......... ioo. o 106~5 927~, 18 9200. ] 0774 9374 EA ~t H ~ 1823,~6 N 239q,45 W $5t;~07 TC~aL RECTANGULAR COORDINATES ND-TVD VE NCRTH/SCUTH EAST/WEST DIFFERENCE CORRE 1~72,16 N 2~fl9,32 W 9~1,95 1920,54 t;. 2501. H4 1969,34 N 2554.2R W 1 0~7,84 201'9 44 N 2605.R6 W lv ,01 2971.35 k 2656.6~ W .... .............. ..................... 2231,08 N 2805,~6 W 1145~80 2283,52 N 2~52.65 W 11~8,03 2335,56 ~ 2R98, 15 W 1189,60 2~.87,~ c9.. N 2991,87 2q~.5,~0 N 2979,37 ~! 1232~2.0 ~5'f'b'";~ .....~ ............. ~'0'0'~). 0'6 "~ ................ ~.'E:~"-TS .......... ~F, 79 ~0 & 3037.35 ~ 1279~0 . _.2655,42 N 306~.8[i W 130~.lq 3130,32 3156.69 W 1~00,69 ICAL CTION 23,75 23,87 22,8 ¢, ' 23,01 .................................. 23.18 23,5~ 24,41 23.84 22 .g6 22.23 21,57 . 21.09 21,51 22,60 25,01 2q,39 31 .4q 30.7g 2~,22 .................................................... SFE~F~'RY='-SUN'-''i,';E'[~ ..... Sb'iR~'EY'f~"¢O~'~PA~!¥ A~-JC~ORAGE, ALASKA Fr~r ALA~A F'ETK~LE~P CGf,~PAD.~Y X-5 ............... CO¢;~p'U'TATi'oN'D'~TE' ..... PRUD~;OE bAY MARCH ].2~ 19R0 ~L.~KA PAGL 11~.. BATE OF SURVEY ~IARCH dOE NUMBER BOSS~1655~ KELLY BUSHING ELEV. = 7A.1P, FT. ............... I]4TERPOLATE.D .VA.~'L.~.(.~!,_~OR._EVE. N..JO0 FEET....._O.F .... SU_BTS;[A. DEPTH. TRUE SUB-SEA TOT.~L .,.,' .. ~'EASURED VERTICAL VERTZCAL RECTANGULAR COORDINATES MD-TVD VE. RTI C~L BEPTF ................... ,, _. ~ 0?02 947A.18 5480.00 2966.6R N 3181.5~ U 1428,55 27,86 11029 26.83 TN E CALCUt.~TIOK PROCEDbF!E$ USE A LINEAR INTERPOLATION TH L NE ARE S T''2 "O"'~ O0 T .... FD "("~'R'~'~/ R"~'[} I uS "~CF 'CuR VXT-uRT[)---p'b'I'~T SOHIO ALASKA PETROLEUM COMPANY March 10, 1980 Alaska Oil & Gas Conservation Ccn~nission 3001 Porcupine Drive Anchorage, .Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well X-5 (23-06-10-14) 3111 "C" STREE~ ANCHORAGE, AL ,A~SI TELEPHONE (907) 265- MAIL: POUCH 6-61 ANCHORAGE, ALASKA Enclosed, in dupliCate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the monthof February, 1980. AMR: ja Enclosures cc: Well File #17 Yours very truly, SOHIO ALASKA PETROLEI3M COMPANY A. M. Reid Acting District Drilling Engineer Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 OIL [] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, 3anchorage, kK 99502 X-5 (23-06-10-.14) 4. LOCATION OF WELL At surface: 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oi~l Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM 12. PERMIT NO. 79-,104 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. February, 19.180 Tested 13 3/8" casing to 3000 psi. Drilled out to 2720', ran leak~off test, Directionally drilled 12 1/4" hole to 9861'. Ran 253 jts. 9 5/8" 479 Soo-95 Buttress casing to 9845'. Cemented in t~ stages: First stage with 1420 cu,ft. Class G cement; second stage through DV packer at 2571' with. 130 cu.ft. Permafrost C preceded~Arctic Pack. Cleaned out to 9806', tested casing to 3000 psi..Drilledout .to 9900', performed formation competency test. Directionally drilled 8 1/2" hole to 11029'. Ran°penhole logs. Ran 43 jts. 7" 29~ L-80 Buttress casing to 11027". Cemented with 564 cu. ft. Class Gcement,· Cleaned out to 10980'. Tested casing to 3000 psi. Displaced well to NaCl, ran CBL. Ran 5 1/2" completion string to 9400', set packer at 9284' , tubingwouldnot test. Perforated tubing above PBR, pulled ~tubing. Ran 217jts. 51/2" 17~ 8rdABmod. tubing'to packer at 9284". Landed tubing with ball valve nipple at 2207'. Installed and tested tree. Displaced tubing to diesel. Tested tubing to 3500 psi. Released rig at 1400 hrs., 2-.26-80. 14. I hereby certify/;~ '"'z~_that the f_or~going,~s true and correct Acting District SIGNED ~ , ,(./~ TITLE Dril~il'lC[ Enc[ineer DATE II I 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SOHIO ALASKA PETROLEUM COMPANY February 7, 1980 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAG E, ALASKA 99502 Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well X-5 (23-06-10-14) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling andWorkoverOperations, for the above- named well for the month of January, 1980. PRJ: ja Enclosures cc: Well File #17 Yours very truly, SOHIO ALASKA PETROLEUM CCMP~ District Drilling Engineer RECEIVED !""~! ~.~ ~'::~ Cons, COmmission Form No. 10-404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPE RATIONS 5. APl NUMERICAL CODE 50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 WELL WELL OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface: 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. X-5 (23-06-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM 12. PERMIT NO. 79-104 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. January, 1980 Spud well at 0400 hours, January 29, 1980. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72% L-80 Buttress casing to 2669'. Cemented with 3839 cu.ft. Permafrost cemm~t. Installed and tested BOPE. EFW:ja 14. I hereby ce. tify t~~ - ~/7//0 SIGNED. ~O_ ,F~"_, illC~l~ TITLEDiStrict Drillina EngineeZbATE MOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. December 20, 1979 Re= Prudhoe Bay Unit X-5 Sohio Petroleum Company Permit No. 79-104 Sur. Loc.~ 363~SNL, 5220~WEL, Sec 8, T10N, R14E, UPM. Bottomhole Loc.= 2400'NSL, 3140~WEL, Sec 6, T10N, R14E, UPM. Mr. P. R. Judd District Drilling Engineer Sohio Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Judd~ Enclosed is the approved application for permit to dril.1 the above referenced wel.1. Well samples, core chips and a mud log are not required. A directional survey is required, if available, a tape contain- ing the digitized log t~formation on all logs shall be submitted for .copying except experimental logs, velocity surveys and diameter surveys. Many rivers in Alaska and their drainage systems have been- classified as important for the spawning or migration of anadrCSaous fish Operations in these areas are subject to AS 16.50.870 and t~e 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 Mr. P. R. Judd Prudhoe Bay Unit X-S -2- December 20, 1979 cc~mencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the we1! is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dr il led. In the event of suspension or abandonment, please give this office a~equate advance notification so that we may have a witness present. Very truly yours, Ho H. Ham il ton ~ on Alaska 0il a .G~~ ~nservat~on Commlssi Enc!osure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/eno1. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. SOHIO PETROLEUM COMPANY Division of Sohi~ Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION December 14, 1979 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil and Gas Conservation Cc~lission 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: Well X-5 (23-06-10-14) Enclosed are the following documents: 1. Application for Permit to Drill, in triplicate 2. Proposed Drilling Program Outline e e Our check for $100.00 to cover the permit filing fee. Three copies of surveyor's plat showing well location. Very' tinily yours, SOHIO P~O~ ~~ P. R. Judd District Drilling Engineer PRJ: ja Enclosures cc: Well File #17 Form 10-401 REV. 9-1-78 la. TYPE OF WORK SUBMIT IN TRIal~ (Other instructiol% .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION reverse side) PERMIT TO DRILL OR DEEPEN DEEPEN [] DRILL [~] b. TYPE OF WELL OIL GAS SINGLE MULTIPLE WELL [] ZO"E ~q ZO.E WELL ~] OTHER 2. NAME OF OPERATOR Sohio Petroleum Company, Div. of Sohio Natural Resources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 99502 4. LOCATION OF WELL At surface 363' SNL, 5220' WEL, Sec. 8, T10N, R14E, UPM At proposed prod. zone 2400' NSL, 3140' WEL, Sec. 6, T10N, R14E, UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 10 miles NW of Deadhorse E API #50-029-20422 6. LEASE DESIGNATION AND SERIAL NO. ADL 28313 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. X-5 (23-06-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Poo 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T10N, R14E, UPM 12. 14. BOND INFORMATION: TYPE Blanket Surety and/or No. American Insurance Co. 3348616 Amount $100,000.00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1898' east of ADL 47472 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2640' west of Well X-4 21. ELEVATIONS (Show whether DF, RT, CR, etc.) est. KBE = 75' AMSL 16. No. OF ACRES IN LEASE 2501 19. PROPOSED DEPTH 11094 'MD 9486 ' TVD 17. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START February 1, 1980 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE .V~D SETTING DEPTI-fi~ Quantity of cement 36" 20"x30" rnsn]ated Conductor 110' '110' 10.6 cu.yds. Arcticset concrete 17½" 13 3/8" 72# L-80 2670 ' 2670 ' 3860 cu.'ft. Permafrost ]2%" 9 5/8" 47~ Soo-95 9973' 8613' 1420 cu.ft. Class G; 130 cu. ft. 7'" 299 L-80 11094' 9486' 304 cu. ft. Class G 8%" .,, PFC See attached proposed drilling program outline. (,2, ,* , IN ~O~ SPACE DESC~BE PRO~SED PROGRAM: If pmpoml is to deepen ~ve data on present productive zone and pro~sed n~w productive zone. If propo~l is to ~ or deepen d~ection~y, ~ve pertinent data on sub~face locations and measured ~d verti~ depths. Give blowout preventer pro.am. 24. I hereby c True and Correct O~/ /.~TV Wis~ict DATE /~ nTLE Drill~q ~g~eer SIGNED __ (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED ] MUD LOG [] YES ~NO [ [] YES [~ NO DIRECTIONAL SURVEY REQUIRED ~IYES [] NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO.. 7 APPROVAL DATE $' ' ~' ~' - ~ *See Instruction On Reverse Side Dec~mber 20, 1979 DATE 12/20/79 PROPOSED DR~.LING AND CQMPLE~ON PROGRAM Dry bucket 36" hole to 80' below ground level and cement 30" x 20" insulated conductor to surface using Arcticset concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3860 cu. ft. P~ost cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer frcm 13 3/8" casing point to T.D. Directionally drill 12 1/4" hole to 8613'+ TVD. Run 9 5/8" 47# Soo-95 Buttress casing to 8613' TVD and c~_nt first stage with 1420 cu. ft. cement. Cement second stage through D.V. packer collar at 2600'+ with 130 cu.ft. Penm~frost C cement. 9 5/8" casing will be hung at surface, ~he 9 5/8" x 13 3/8" annulus will be Arctic Packed. Directionally drill 8 1/2" hole to T.D. at 9486'+ TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 304 cu. ft. Cl-ass G cement with 18% salt. Run 5 1/2" 179 L-80 Atlas Bradford Mod. 8rd tubing with a production packer assembly at 8185'+ TVD. A subsurface safety valve with dual control lines will be placed at 2000'+. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. £0 3'3 40 I0 O! (Proposed) 3;40' ~" ............... '~-"" - ~ 0TM, 2O ~0 (Proposed) I 0 910' !598' -- Et, ST COND. J"~---'-*'~"~'~ LAT. = 70°14'31.13'' I LON G.=148°~9' 19.~" I X= 666,488 Y =5~939,890 8 PORTION OF TION,RI4E, UM SCALE I": I/2 MiLE CERTIFICATE OF SURVEYOR ! hereby certify that lam properly registered to pract;ce land surveying in the State of Alaska and that this plat represents a location survey of the weilpad shown and the wells thereon. This. survey was made by me or under my supervision end (]ii dimensions and other details are correct. Bottom hole iocations ,=re furnished by others. .......... ................... Date Surveyor Ail b-.?tom hD~es ore 8800' sub sea. :'~.,.sed B'~= 'X-2' f~om 2450' to 2490' EWL. PJR 9/12/1979 ,. ' o '"'~ ~ ~ ~ - II ].~-,~sr ~ ,.z ' I~ I' -_'~ ~ ' ...-.' ~.,~' f =, I~ .~-~-,~-,~! [ =., . I -: I s, .1~ Il ' " r~,-:-,o-,~:i · ~-~ ', (~.6-/0-/4) · Ii H · ,I ~ 4~, PAD DE TAIL ~ T ~-'~-o~ ~ ~ ,,,: oo, · ~'._.~._ __~ .... ~--. _ · .~...;..L~) ...~=~ .. ~"-.. ~.~,~ ~- ~,'.¢ ~ ~ Kenneth BJenMns. "~ ~'",* . . ,.- ..-'. '- 't ~. ~. ~.., .: ~.:~ C.J.R. ~S- STAKED PA D "X" Located in ~RO'rRACTED SECTIONSS,6. TGST.~ON.,R. t4[ UM.. ..... i ..... · Surveyed for SOHIO PETROLEUM CO. Surveyed by EM. LINDSEY 8~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYC;RS Anohoroge __ CA~ECK LIST FOR NEW WELL PERMITS O~npany Yes No Is the permit fee attached ...................... ~in~ ~' "'' ......... ii~ IS v,~ll to he located ina de__.__ ~__ ......... Is a registered survey plat attached ............................ Is well located proper distance frcm property l in~ .................. Is well located 'proper distance frcm other %~lls . ................ Is sufficient unde~dicated acreage available, in this Is ~11 to be deviated .............................................. / . Is oporator tho only affected party ................................. . Can permit he approved hefore ton-day wa±t .......................... '~ · Does cx:~rator h~e a lx>nd in force .................................. · Is a conservation order needed ...................................... · Is ,:Tlm~is~ative approval needed ................................... · Is conductor string provided ........................................ · Is enough cement used to circulate on conductor and surface ......... · Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... ~ Lease & Well 'NO. ~Li~ Item j~pprove ' ~'~' lFee~ (2) Loc. / (4) Casg. ~ · Will surface casing protect fresh w~ter zones ....................... ~ · Will all casing give adequate safety in collapse, tension and barst.. ~ · Does BOPE have sufficient pressure rating - Test to $o~ psig .. ~ Approval Reccmmended: ditional Requirements: Engineering: rev: 12/12/79 Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. .o LV~~ Ot(~,F~O~ VEPlFICATION LISTING PA~E 1 SERV%CE k! A ~ E ;EDIT DATE :eO/ 6t 4 TAPE i~ A ~q E :60325 PREVIOUS ThPE : CO~ME{,~q'5 :~{!~!O{IE wFI, L T{.)E~TIPICATIf)i,; N!.{MBE~ %S 50-029-20422 CASING I.>~ILbCR 9,6~5 ~ 9a45/BIT SIZE ~,5 ~ II029/DENS ~.8/Pa lO 8/ SERVICE ~A~E VER6IC~ ~ DATE g ~AXI~U~ I,,E~!GT~{ : 102d ~iLE TYPE ** 1NFOR~-aATION RECORDS MNEN CO~T;iNTS [INIT TYPE CATE SIZE CODE WN : RANG: TOWN~ SECT~ 000 000 023 065 000 000 003 065 000 000 01! 065 000 000 003 065 oho ooo 003 065 000 000 001 065 000 000 008 065 LVP OlO,.PO? VE;RIFiCAT~Oi'~ L!STING PAGE 2 DE~')S: aO0, RLOCK$ [!NIT APl aPI LOg TYPE wT 0 0 a~ 7 1 OH~M 7 1 ~ ~}q~N 7 I 2 OH~ 7 2~ CAPl 7 3! TN 42 2§ G/C3 a2 4.a PU 42 69 0/03 42 35 c/C 42 4P CPS 42 34 CPS 42 3a CAPI 60 3~ REPR CODE aPi aP! FILE CLASS ~OD NO. 0 0 0 0 0 0 40 0 0 44 0 0 1 0 0 32 0 0 32 0 0 i 0 0 0 0 0 P 0 0 I 0 0 i 0 0 92 0 0 03 0 0 32 0 0 32 0 0 SI 000 000 0O6 065 000 000 004 O65 ZE PROC bEV 4 4 4 4 4 4 4 4 4 ESS SAMPLE REPR ED CODE 0 1 68 0 t 68 0 1 68 0 1 68 0 1 68 0 1 68 0 I 68 0 I 6a 0 1 6~ 0 1 6~ 0 1 6~ 0 1 68 0 1 6~ 0 t, 6~ 0 ! 6~ 0 1 6~ DEPT DRHO NCNb DEPT NCNb DEPT SF!.,U DRH© NCML DEPT S F L U NCMb DEPT 11030 0000 SP n.. 06.45, ~TpH1 2698. O000 FCNL 11o0o,no05~ 76! 270~.0000 10900.0000 SP a,4922 GR O.ObBt NPH,t 3692,0000 FCNL !070fl.0000 SP 9.~000 ~R 0.0527 NPHt ~7 !1!, 2~, 091, 111. 25. 10!2, 4!, 20, i535, 25, 24, 1309, -86, 2~. 8594 4375 5645 5000 3750 4375 2441 5O00 ~'750 P!~7 0000 6250 7031 ~445 0000 3750 ~R C R T hD ~R PHOB !21. 94, !21. ~,03. 0, 47, 40, 25, 2. 24, . 21, 2. 4609 6250 4316 3750 367 6902 7500 5859 2187 5293 oooo 3105 2969 3828 8906 6973 7344 4727 CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT IBM CALl DT CALl NRaT 4,6406 5,3086 2,7168 72,0000 4,4336 9,1328 2,7539 72,0000 4 0781 810469 ~ 3730 82 3750 3,72~5 8,1875 2,5371 97,1.875 3,0332 8,3672 2,4160 ,wCWL 3936. a00 0 SP D~:PT I C-'508.. hOOt' SFT.~U ?, 7969 OR.HO O, 0t72 MCteL 3354. 0000 SP 3700.0o0'o SP r;' C V I5 N p !41 OEPT 99t.~0. 0000 SFI,U 3,23f~5 O R H O 0. () 3 !. 7 NCUL I7-3! ,O000 SP ;'CNL DEPT 9700. 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O,jOO ~' H OB T hO I J bO ?HOB RHOB ~R GR RitOB I L D R I bP 99,9375 CALl -999.~500 NRAT -999,2500 DT -~99,2500 IbN 8~,0000 CALl -990.2500 NRAT -999,2500 DT -99~,2500 IbM 13].1250 CAbI -99q.7500 NRAT -999,2500 BT 5. 3438 CALl . o.=soo · 99,2500 DT '999.2500 IbM 65,0625 CALI -999.2500 NRAT -999.~500 DT -999.2500 Ib~ b4.6875 CALl -990,2500 NRAT -999,2500 PT -999.2500 IbM 49,~125 CALI '990.2500 NRAT -999,2500 DT -099,2500 IbM ~9,8750 CAI, I -999,~500 MR~_I -g90,2500 DT -999.2500 57,4688 CALl -999,2500 MRAT -09o,2500 PT -999.2500 ILM 54,9375 CALI -999.2500 NRAT -099,2500 DT -g99,2500 56,2813 -099,2500 MRAT-99g,2500 DT -990 ~5000. -999! ~50 -099 2500 -999 2500 -999:2500 -999.2500 -999.2500 -999,2500 '999,2500 '999.2500 '999.~500 i99~,2500 999.2500 999,2500 999,2500 'g9g,sbo0 -999,2b00 -999,2500 -999,2b0() -999 2500 '999,2500 '999,~500 '999.~500 -099,2500 -999.2500 '999,2500 '099,2500 '99g.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999'2500 -999:2500 -999,2500 ,999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 LVP O].a. NO? VEPlFICATln?~ LISTING PAGe; 6 SFLU DEPT SFLU OReO ~o99.)500 i:iPHl -999 -99 0000 gp 0'~00 CR 9.~500 ~PUi OEPT 'llO~.OOOO SP -g SFI. U 'q99, ...... DRgU -~99.~500 ~)P)-!i -999 NCnb -o99.7500 FCHL -q SFLt! -gga. 2500 DRHO -999. 2500 ~qPl'{I -q9O 8FbU ..,EP! b~O0 no00 SP 9 S ~"t,~'~ -999.2fi00 GA t- x.- %~ ' .. . a, DRanO -999 0060 ~pNf q q ,~u,,L -09~. 9500 FC~-~b -9 DEPT .. 90 ~500 DRNO -090. 2500 NCaYL -99q, 2500 SFI, U 999,9500 ?500 DR~iO ~9q'95o0 ~CL!L ' 90.2500 9o.2500 99.2500 99 2500 9 : soo 25. 0000 9q.2500 99 9~,2500 25,0O00 9q. SbO0 99.9500 90,2500 25.00o0 90,P500 9o 25o0 2.5. OOO0 99..7500 9n.2500 90.25*,)0 25. 99,2500 99,2500 9O,2bC)O 99 2500 99!2500 25 0000 9g.2500 9q.25o0 9q.2500 2= 0000 99~2500 90.2500 99,2500 25,0000 90,25OO 99.2b00 9n-25oo 25.0O00 90.2500 T L,P ~a R~OB :HO~ I L D CR !LO -o99,2500 63,531.3 CAbl -999.2500 NRAT -999,2500 DT -999,2500 I~ 59.53J3 CALl -~99.2500 NRAT -999,2500 PT -999,2500 !bM 57.0938 CAI, I '999.2500 MRAT '999,2500 DT -999.2500 Ib~ 57,0313 CALl -99~.2500 NR~T -999.2500 DT -9~9,2500 th~ "'3,9687 CALl -999.2500 NRAT -990.2500 DT -99o_,2500 4.q,6250 CALl -999,2509 NRAT -~99,~50 DT -q99,2500 IL~ 51,8437 CALl -~9~, 2500 ~RAT -09~.2500 PT -099.2500 Ibm 99,2500 DT '990.7500 IL~ 46,28i3 CALf -999.2500 NRaT -990,2500 OT -~9n,2500 40.4375 CALX -999,2500 NRAT -99~,~500 :,.1- -990.2500 IbM 46.0~13 CALl -099,2500 ~{R~T -990.2500 PT -999 2500 -999!2500 -~90 2500 -999,2500 -999,2500 -999,2500 -999,2500 -099,7500 -990 2500 -99~:2500 -099.2500 -999.2500 -990.2500 -999.2500 '099.2500 -990.2500 -099 2500 'q9q' ,2500 -999.2500 -999,2500 -999 2500 -999' ,2500 -999,2500 '999,2500 -999 2500 ~999i2500 -999 2500 -999 2500 -099 2500 -999,~500 -09~.250u -999.2500 -999 ~500 . 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GR -999 DRHO -099, ?500 ?lPHI -q~025 gC~i5 -990.2500 wC~,] b 999 -999 . '~9~, -99~25, '~99, c~gg -99925 -999. -999 -999' .09 {~ -99925. -099. -999, -9902g. 999, :q99 -0~925, 99Q. SFLU -099. ~bO(') GR DRHO -99c~ 9., 500 NPHi NCW [., -099: ~500 F'CNL DEPT 4600.0000 aP 8FLtJ -999. ?.. 500 Ga DR Hl"~ -ogq 0500 i~)P H I NC~b -09o. 2500 ~'C ~-~!.~ 4200 .25~0 ?L00 , ~500 250O '25o0 .25no ..2500 .2500 ,0000 .250O '2500 0000 2500 ?500 2500 0000 2500 .9_50O 2500 0000 7500 250O 2500 ~590 2500 2500 25~0 2500 0000 ?5o0 2500 2.5.{)0 TbD -099,7500 ¢'r -~99.2500 IbM 34.4063 CALl -990.~500 MRAT-099,2500 DT -999.2500 Ib~ 2~,6875 CALI '990,2500 NRAT '999,2500 DT !br~ -999,2500 ~R 48,5938 CALl PHOB -999,~500 NRAT ~R '099, ~500 DT GR TLD ~HOB ~R PHOB GR 1999,~500 Tb~ 22, 719 CALl '990.2500 NRAT -999,~500 DT 46,2813 CALI -999,~500 NRAT -999.2500 DT -999,2500 IbM 1fl.0~25 CALl -~99,~500 -999.2~00 DT -~99.2500 IbM 22.8906 CALl -999,~500 NRAT -999,2500 -99o.~500 IBM 46.4688 CAt. 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PA~}~ 10 SFT, U -Ogg '?500 DEPT 3000 0,900 SFLLi -099' ?500 NC~b -990 25~0 TGD ,.,.. ,2 oo Ga -99~25.0 O0 PHOB DEPT 2~00. 0000 $.FLL! -999, -999,2500 -990,2500 -09025,0000 ~HmB DEPT 2700,0000 8FL, U -o90 ?_.500 DRHU q9g ?500 N'PHI ~ c,,, L lOo,~: ?soo -qgq,2500 T h ~,,. -099,2500 GR -9.9925,0000 P i-i OB q9q,2500 GR i 990,25n0 ThO 990,2500 CR -999'2500 ca DEPT 25t4. o0o0 -090,9500 -q90,~500 ~CLu FILE TYF~ ********** Ef!F **:******** SE~VTC['. ~ ..... ~JA~E DATE :nO/ 6i 4 TADF/ ~A~ CO~TTN~]ATi~3]~ ~ :gl NEXT T~PE NA~E : 65 0000 CAt. i -999~2500 NRAT -099,2500 DT -999 2500 I5~ -999,2500 NR~T -999.2500 DT -990,2500 1~ 46.9062 CALl -999,2500 NRAT -999.2500 DT -999 2500 IbM 43~2500 CALl -099.2500 NRAT '999,2500 DT -999.g~00 Ib~ 26. , 00 CALI -999,2500 NRAT -999.2500 DI' -999.2500 IbM IB,!406 CALI -990,~500 NRAT -999.2500 DT -999,2500 26 7031 CALf -999~2500 gRAT-09~,2500 -999 2500 ~999i2500 -g9O 2500 '999,2500 -999,2500 -999,2500 '999,2500 -099,2500 -999,2500 '999,2500 -999,2500 -999 2500 -999i2500 -999 2500 '999,2500 -099 2500 '999,2500 '999,2500 '999,2500 '999,2500 -999.2500 -090,2500 '999.2500 -999 2500 -990!2500 -q99 2500 -999,2500 11 11 1111 1111 11 11 11 11 11 11 11 11 1111 1111 11 11 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 '77 '77 77 77 '77 7.7 71 77 77 77 77 660666 666666 66 66 66 66 66666666 66666666 66 66 66 66 66 66 66_ 66 666666 666666 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 00oo0o 333333 333333 33 33 33 33 33 33 33 33 33 33 33 33 33 33 333333 2 22 22 22 22 22 22 22 22 22 22 22 22 22222'222'22 2222222222 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 55§555' 555555 CCCC M t~ CCCC C MI~ mM C C M 1~ M C C M M C C M M C C 1~ 1~ C CCCC ~ M CCCC PPPP RRRR U U DDDD P P R R U U D P P R R U U O PPPP RRRR U U D P R R U U O P R R U U O P R R UUUOU DDDD H H OOO D H H O O D H H O O D HHHHH U O O H H O O O H H O O H H OOO EEEEE E EEEE E E EEEEE mSTART* USER PCAL MONITOR SWS K[.lOE37 *START* USER PCAL MONITOR SWS KLIOEJ7 [10707,60325] dOB APR-80. ,START, [10707,60325J jOB APR-BO. mSTART~ SHIP SEQ. SHIP 1414 DATE 05-dUN-80 1414 DATh 05-jUN-80 02:01:20 02:01:20 ¥¥ V¥ EEEEEEEEEE RRRRRRRR ¥¥ YV EEEEEEEEEE RRRRRRRR VV VV EE RR RR VV VV EE RR RR V¥ VV EE RR RR VV VV ~E RR RR VV VV EEEEEEEE RRRRRRRR VV VV EEEEEEEE RRRRRRRR VV VV EE RR RR V¥ YV EE RR RR VV VV EE RR RR VV VV EE RR RR VV EEEEEEEEEE RR RR VV EEEEEEEEEE RR RR lllIII 1IIIII II II 1i II ii II I1 1I II II Iiiiii IIIIII YY YY YY YY YY Y¥ YY YY 000000 000000 666666 000000 000000 666666 O0 O0 O0 O0 66 O0 O0 O0 O0 66 O0 0000 O0 0000' 66 O0 0000 O0 0000 66 O0 O0 O0 O0 O0 O0 66666666 O0 O0 O0 O0 O0 O0 66666666 0000 O0 0000 O0 66 0000 O0 0000 O0 66 O0 O0 O0 O0 66 O0 O0 O0 O0 66 000000 000000 666666 000000 000000 666666 66 66 66 66 ~START* USER PCA6 [10701,60325] JOB SHiP SEQ. MONITOR SwS K610E]7 APR-BO. *START~ FILE: DSKH:VERIF~.006<05Y>[10707,60325] CREATED: PRINTED: 05-JUN-80 02:01:38 QUEUE SWITCHES: /FILE:FORT /COPIES:I /SPACING:) /LIMiT:B2 /FORMS:NORMAL 1414 DATE 05-JUN-80 '0 05-dUN-80 02. 1:20 01.:54:25 ,: ..... , ./ SCHLUMBERGER COMPUTING CENTER 10707,60]25 REEL HEADER LENGTH: 132 BYTES REEL NAME: P.C.A.b. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 0] PREVIOUS REEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 80/ b/ 4 TAPE HEADER LENGTH: ]32 ~YTES TAPE NAME: 00325 DATE: 80/ 6/ 4 SERVICE NAME: ED1T TAPE CONTINUATION NUMBER: 0! PREVIOUS TAPE NAME: COMMENTS: UNIQUE WELL IDENTIFICATION NUMBER IS 50'029'20422 TAPE COMMENTS CASING DRILLER 9.625 ~ 9845/BIT S1ZE 8.5 ~ l1029/DEN$ 9.8/PH i0.8/ ~'LUID TYPE GEL'POLY/VISC 38 SEC/FLUID LOSS 6.0 ML/RM 2.38 ~ 75 DF/ RMV' 2.19 ~ 75 D~'/RMC NA/ HEADER LENGTH: 62 BYTES FILE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL 8ITE INFORMATION RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECTION: COUNTY: STATE: 176 BYTES SOHIO ALASKA PETRO. CO. X-5 PRUDHOE BAY 14E lin N. SLOPE ALASKA DATA fOMMAT SPECIFICATION bENGTH: 650 ~XT~$ ENTRY BLOCKS: 0 SIZE REP CODE ENTI{X 1 b6 0 DATUM SPECIFICATION BiLJOCK$: ENTRY lC TUU6 SVURD# UNITS APl AP1 API AP1 FIbE# SIZE EXP PROC SAM REP DEPT SHIFT 1 DEPT BP 4 ILM 5 SFLU GR 7 GR CNL 8 CAL! CNL 9 DRHO FDC NPHI CNL RHOB CN5 NRAT CNL NCNL CNb ~'CNL CNL {5 GR BHC 16 DT BHC fT MV OHMM GAPI GAP1 IN G/C3 PU G/C3 C/C CPS CPS GAPI US/F 0 0 0 0 0 4 0 0 I 68 0 0 ? 1 0 0 0 4 0 0 I 68 0 0 7 12 46 0 0 4 0 0 1 68 0 0 7 12 44 0 0 4 0 0 ! 68 0 0 7 22 ! 0 0 4 0 0 I 68 0 0 7 31 32 0 0 ~ 0 0 1 68 0 0 42 ]1 32 0 0 4 0 0 1 U8 0 0 42 28 I 0 0 4 0 0 1 ~8 0 0 42 44 0 0 0 4 0 0 1 68 0 0 42 68 2 0 0 ~ 0 0 ! b8 0 0 ~2 35 1 0 0 ~ 0 0 ! 68 0 0 42 42 I 0 0 4 0 0 I 68 0 0 42 34 92 0 0 4 0 0 1 08 0 0 42 34 93 0 0 4 0 0 I b8 0 0 bO 31 32 0 0 4 0 0 I 68 0 0 60 52 32 0 0 4 0 0 I 68 0 0 D~PTH 110]0o000 11000.000 10900,000 10800.000 10700.000 10600.000 10500,000 10400.000 10300.000 10200.00O 10100.000 MNEMONIC SP GR NPHI FCNL SP NPHI FCNL SP GR NPHI ~CNL SP GR NPHI FCNL SP NPH! FCNb SP GR NPHi FCNL SP 'NPHI f'CNL SP GR NPHI FCNL SP GR NPHI FCNL SP GR NPHi FCNb SP GR NPHI ~CNL VALUE -7.85 111.43 28.56 991.50 -8.37 111.43 25.24 1012.50 -69.87 41.21 20.89 1535.00 -81.62 25.70 23.14 1309.00 -86.37 20.71 21.14 1566.00 -73.68 29.12 22.90 1497.00 -76.37 22.28 23.09 1325.00 -61.37 25.45 19.38 1554.00 -76.62 24.54 24.46 1284.00 -68.62 23.76 22.36 1305.00 -40.65 130.87 17.33 1710.00 MNEMONIC 1LD Gl{ RHOB GR iLL GR RHOB GR iLL GR GR ILD GR RHOB ILL GR GR ILL GR RHOB GR GR RHOB GR ILL GR RHOB GA- ILL GR RHOB GR GR RHOB GR ILD GR RHOB GR VALUE 5.4bl 121.625 2.4,32 94.375 4.367 121.063 2.699 103.750 3.586 47.219 2.529 40.O00 3.311 25.297 2.383 24.891 2.697 21.734 2.473 18.172 4.004 28.172 2.498 32.469 2.674 25.813 2.340 21.828 16.766 25.125 2.686 31.000 15.781 23.984 2.451 25.703 34.031 25.547 2.357 29.625 29.313 158.125 2.893 172.250 MNEMONIC kLM CALk NRAT DT CALk NRAT DT IbM CALl NRAT DT kLM CALl NRAT CALk NRAT DT IbM CALl NRAT OT CALl NRAT DT IbM CALl NRAT DT IbM CALk NRAT DT 1bM CALk NRAT OT CALl NRAT DT VALUE 4.641 5.309 2.717 72.000 4.434 9.133 2.754 72.000 4.078 8.047 2.373 82.375 3.729 8.188 2.537 97.i88 3.033 8.367 2.410 84.563 4.523 8,266 2.527 84.563 2.652 8.328 2.545 92.188 20.297 8.883 2.342 80,750 13.031 8.688 2.666 89.375 26.625 8.547 2.516 90.375 28.531 10.133 2.307 66.750 MNEMONIC SFLU DRHO NCNb $FLU DRHO NCNb 8FLU DRHO NCNb DRHO NCNb SFLU DRHO NCNb SFDU DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb 5FbO NCNb SFLU L)RHO NCNb SFbO DRHO NCNb i' VAbUE 9.414 0.064 2698.000 4.762 0.069 2702.000 8.492 0.058 3692.000 9.039 0.050 331b.000 9.500 0.053 3836.000 9.313 O. 070 373b.000 2.797 0.012 3354.000 15.344 0.010 3710.000 19.047 0.050 3422.000 33.15b 0.021 3200.000 4'1.250 0.001 3968.000 DEPTH 10000.000 9g00.000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200,000 9100.000 9000.000 MNEMONIC VALUE MN EMONIC SP -ll.b09 iLL GR 93.000 GR NPHI 40.820 RHOB F'CNL 428.500 GR SP -15.359 GR 102.438 GR NPHI 32.617 ~'CNL 483.000 GR SP -12.375 iLD GR 50.406 GR NPHi 50.293 RHOB P'CNL 381.500 GR SP -999.250 ILD GR -999.250 GR NPHI -99925.000 RHOB f'CNb -999.250 GR SP -999.250 ILL GR -999.250 GR NPHi -99925.000 RHOB FCNL -999,250 GR SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 SP -999.250 GR -999,250 NPHI -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 GR RHOB GR GR RHOB GR GR RHOB GR ILL GR RHOB GR SP -999.250 ILD GR -999.250 GR NPHi -99925.000 RHOB FCNL -999.250 GR SP -999.250 ILD GR -999.250 GR NPHI -99925.000 RHOB FCNL -999.250 GR VALUE 1.912 92.938 2.309 103.813 1.409 98.688 2.477 92.625 7.375 54.875 2.076 61.750 -999.250 69.063 -999.250-999.250 -999.250 69.813 -999.25O-999.250 -999.250 59.906 -999.250-999.250 -999.250 65.250 -999.250-999.250 -999.250 65.938 -999.250-999.250 -999.250 70.375 -999.250-999.250 -999.250 62.625 -999.250-999.250 -999.250 5b. O00 -999.250-999.250 MNEMONIC CAb1 NRAT DT ibm CALl NRAT DT CA6i NRAT DT CALl NRAT DT IbM CALl NRAT DT ibm CALl NRA~ DT CALl NRAT DT CALl NRAT DT IbM CALi NRAT DT CALl NRAT DT IbM CALl NRAT PT VALU~ i.959 12.656 3.959 107.375 1.438 17.719 3.555 107.000 2000.000 8.750 4.363 73.150 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999.'250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFbU DRHO NCN6 SFLU DRHU NCNb SFbU DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFLU DRHU NCNb SFbU DRHO NCNb SFbU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb VALU~ 3.348 0.020 1731.000 3.230 0.032 1731.000 2000.000 -0.987 1598.000 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DE~TH 8900,000 8800,000 8700,000 8600,000 8500,000 8400.000 8300,000 8200,000 8100.000 8000.000 7900.000 MNEM(JNIC VALUE SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 6P -999.250 GR -999.250 NPMI -99925.000 ~CNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 ~CNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 ~'CNL -999.250 SP =999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 SP -999.250 GH -999.250 NPH! -99925.000 ~CNL -999.250 SP -999.250 GR -999.250 NPH1 -99925.000 FCNL -999.250 $P -999.250 GR -999.250 NPHI -99925.000 ~'CNL -999.250 $P -999.250 GR =999.250 NPHi -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPH1 -99925,000 FCNG -999.250 $P -999.250 GR -999.250 NPHI -99925.000 ~CNL -999.250 MNEMONIC ILD GR RHUB GR GR RHOB GR ILD GR RHOB GR ILD GR RHOB GR ILO GR RHOB GR GR RHOB GR ILD GR GR ILD GR RHOB GR GR RHOO GR ILD GR RHOB GH iLO GR RHOB GR VALUE -999.250 117.438 -999.250-999.250 -999.250 1]0.000 -999.250-999.250 -999.250 66.625 -999.250-999.250 -999.250 88.313 -999.250-999.250 -999.250 99.9]8 -999.~50-999. 50 -999.25O -999 50 -999.250 -999.250 133.125 -999.250-999.250 -999.250 5~.]44 -99 .250-999.250 -ss :2so 6 063 -999.250 -999.250 -999.250 -99 250 -999.250 -999,250 49.313 -999.250-999.250 MNEMONIC CALl NRAT DT CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT CALl NRAT DT ibm CALl NRAT DT ibm CALl NRAT OT IbM CALl NRAT OT CALl NRAT OT CALl NRAT OT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99 250 -9999:250 -999.250 -999,250 -999.250 -99~,250 -99 .250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~999.250 999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFLU DRHO NCNb SFLU ORHO NCNb 8FLU DRHO NCNb SFLU DRHU .NCNb SFLU DRHO NCNb s~'Lu DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHU NCNb VALU~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 7800,000 7700.000 7600.O00 7500,000 7400,000 7300,000 7200.000 7100oOO0 70O0,OO0 6900,000 6800,000 MN~MUNiC VALUE SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 f'CNL -999.250 MNEMONIC ILL GR RHOB GR ILD GR RHUB OR SP -999.250 GR -999.250 GR NPHi -99925.000 RHOB FCNL -999.250 GR SP -999.250 GR -999.250 NPHi -99925.000 ~'CNb -999.250 SP -999.250 GR -999.250 NPH1 -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 F'CNL -999.250 ILD GR RHOB GR GR GR iLL GR RHOB GR VALUE -999.250 49.875 -999.250-999.250 -999.250 57.469 -999.250-999.250 -999.250 54.938 -999.250-999.250 -999.250 56.281 -999.250-999.250 -999.250 6].531 -999.250-999.250 -999.250 59.531 -999.250-999.250 ~P -999.250 ILL -999.250 GR -999.250 GR 57.094 NPH1 -99925.000 RHOB -999.250 FCNL -999.250 GR -999.250 SP -999.250 ILD GE -999.250 GR NPHI -99925.000 RHOB f'CNb -999.250 GR SP -999.250 GR -999.250 NPHI -99925.000 FCND -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 GR GR ILL GR RH00 GR 1LD GR RHOB GR SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 -999.250 250 -999.250 -999.250 53.969 -999.250-999.250 -999.250 48.525 -999.250-999.250 -999.~50 51. 44 -999.250 -999.250 MNEMONIC IbM CALl NRAT DT CALl NRAI' DT CALl NRAT DT CALl NRAT DT CALl NRAT DT IbM CALl NRAT CALl NRAT CALl NRAT DT CALl NRAT DT CALl NRAT DT ibm CALl DT VALU~ -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999.250 -999.250 -99 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99~.250 -99 .250 -999.250 -999.250 -999.250 -999.250 -999. 50 -999.~50 -999.250 -999.250 -999.250 -999 5O -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFLU DRHO NCNb SFGU DRHO NCNb SFGU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHU NCNb SFLU ORHO NCNb $FLU DRHO NCNb SFLU DRHO NCNb SFLU ORHO NCNb SFLO DRHO NCNb VAbU~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Di".P'I'H 6700,000 6600.000 6500.000 6400.000 6300,000 6200,000 6100.000 6000.000 5900,000 5800,000 5700,00O MNEMUN1C VALUE MNEMONIC SP -999.250 GR -999.250 GR NPH! -99925.000 RHOB ECNL -999.250 GR ~P -999.250 GR -999.250 GR NPHi -99925.000 RHOB FCNG -999.250 GR SP -999.250 GR -999.250 NPH! -99925.000 ~CNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 ~'CNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 f'CNb -999.250 SP -999.250 GR -999.25O NPHI -99925.000 FCNL -999.250 ILD GR RHOB GR OR GR GR GR RHUB GR SP -999.250 GR -999.250 OR NPHI -99925.000 RHOB FCNL -999.250 GR SP -999.250 GR -999.250 GR NPHI -99925.000 RHOB ~'CNL -999.250 GR SP -999,250 GR -999.250 GR NPHI -99925.000 RHOB f'CNL -999.250 GR SP -999.250 OR -999.250 NPHi -99925.000 ~'CNL -999.250 SP -999.250 GR -999.250 NPH1 -99925.000 FCNb -999.250 ILL GR RHOB GR GR RHOB GR VALUE -999.250 36.938 -999.250-999.250 -999.250 46.281 -999.250-999,250 -999.250 40.438 -999.250-999.25O -999.250 46.031 -999.250-999.250 -999.250 32.344 -999.250-999.250 -999.250 39.094 -999.250-999.250 -999.250 51.656 -999.250-999.250 -999.250 30.484 999.250 29 9.25o -999.250 ]5.844 -999.250-999.250 -999.250 27.484 -999.250-999.250 -999.250 26.797 -999.250-999.250 MNEMONIC ILS CALl NRA~' DT IbM CALl NRAT DT CALl NRAT DT CALl NRAT DT CALl NRAT DT IbM CALL NRAT CALl NRAT DT CALl NRAT OI' ibm CALl NRAT DT CALl NRAT OT CALl NRAT DT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -99 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFbO DRHO NCNb SFLU ORHO NCNb SFbU DRHU NCNb SFLU DRHO NCNb SFbO ORHO NCNb SFLU DRHO NCNb SFbO DRHO NCNb SFLU ORHO NCNb SFbO DRHO NCNb SFbU DRHO NCNL SFbU DRHO NCNb VAUUE -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2b0 =999.250 -999.25O -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 =999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DLPTH 5600,000 5500,000 5400,000 5300.000 5200,000 5100.000 5000.000 4900.000 4800.0OO 4700.000 4600,000 MN~MUNIC VALU~ SP -999 GR -999 NPB1 -99925 ~CNG -999 .250 ,250 .000 ,250 SP -999 GR -999 NPHi -99925 fCNL -999 .250 .250 .000 .250 SP -999 GR -999 NPH1 -99925 ~CNL -999 .250 .250 .000 .250 SP -999 GR -999 NPH1 -99925 ~'CNL -999 .250 .250 .'000 .250 SP -999 GR -999 NPhI -99925 FCNL -999 .250 .250 .000 .250 SP -999 GR -999 NPBI -99925 f'CNL -999 .250 .250 .000 .250 ~P -999 GR -999 NPHI -99925 ~'CNL -999 .25O .250 .000 .250 SP -999 GR -999 NPHI -99925 fCNL -999 .250 .250 .000 .250 SP -999 GR -999 NPHI -99925 ~CN~ -999 .25O .250 .000 .250 SP -999 GR -999 NPHI -99925 ~CNL -999 .250 .250 .000 .250 SP -999 GR -999 NPH1 -99925 FCNL -999 .250 .250 .000 .250 MN EMONIC ibD GR RHOB GR iLL GR RHOB GR GR RHOB GR GR RHOB GR GR RHOB GR 1LD GR RHOB GR iLD GR RHOB GR ILD G~ RHOB GR ILD GR GR GR RHOB GR ILD RHOB GR VALUE -999.250 39.813 -999.250-999.250 -999.250 33.063 -999.250-999.250 -999.250 35.969 2999.250 999.250 -999.250 28.313 -999.250-999.250 -999.250 34.406 -999.250-999.250 -999.250 21.688 -.999.250 999.250 -999 250 48:594 -9999:2 o -99 250 -999.250 -99 . 50 -999.250 -999.250 46.281 -999.250-999.250 -999.250 18.063 -999.250-999.250 -999 50 -999.250 -999.250 MNEMONIC CALl NRAT DT IbM CALl NRA~ DT CALl NRAT CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT CALl NRAT DT ibm CALl NRAT DT iLM CALl NRAT DT CALl NRA1~ DT CALl NRAT DT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 250 : 9999: so9 -999,250 -999.250 9 :, 999:2 ° so -999.25O -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999. 50 MNEMONIC SFLU DRHO NCNb SFLU DRHU NCNL SFLU DRHO NCNb SFbU DRHO NCNL SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbO DRHU NCNL SFLU DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4500.000 4400.000 4300.000, 4200.000 ~tO0.O00 4000,000 3900.000 3800.000 3700.000 3600.000 3500.000 MNeMONiC VALU~ MNEMONIC SP -999,250 ILD GR -999,250 GR NPHi -99925.000 RHOB fCNb -999,250 GR SP -999,250 GR -999,250 NPHI -99925,000 FCNL -999,250 ILD GR SP -999,250 ILD GR -999,250 GR NPHI -99925,000 RHOB FCNL -999,250 GR SP -999,250 ILD GR -999,250 OR NPHI -99925,000 RH00 fCNL -999,250 GR SP -999,250 iLD GR -999,250 GR NPHI -99925,000 HHOB FCNL -999,250 GR SP -999,250 GR -999,250 NPHI -99925,000 fCNL -999,250 SP -999,250 GH -999,250 NPHI -99925,000 f'CNb -999,250 SP -999,250 GR -999,250 NPHi -99925,000 ~'CNL -999,250 ILD GR RHOB GR ILD GR RHOB GR ILD GR RHOB SP -999,250 GR -999,250 GR NPH1 -99925,000 RHOB FCNL -999,250 GR SP -999.250 GR -999,250 GR NPHI -99925,000 RHOB f'CNL -999,250 GR SP -999,250 GR -999,250 GR NPHI -99925,000 RHOB FCNL -999,250 GR VALUE -999.250 46,469 -999.250-999,250 -999.250 49.719 -999,250-999,250 -999,250 53,094 -999,250-999,250 -999,250 26,000 -999,250-999,250 -999,250 29,250 -999,250-999,250 -999.250 39,875 -999,250-999,250 -999,250 41,500 -999,250-999,250 -999,250 27,406 -999,250-999,250 -999,250 56,094 -999,250-999,250 -999,250 43 469 -999;250-999.250 4 750 -999,250 -999,250 MNkM(JNIC CALl NRAT 1bM CALl NRAT DT CALl NRAT DT 1LM CALl NRAT DT CALl NRAT DT IbM CALl NRAT DT CALl NRAT UT CALl NRAT UT CALl NRAT DT CALl NRAT OT CALl NRAT DT VALUE -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -9.99,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 MNEMONIC SFbU DRHO NCNb SFLU DRHO NCNb DRHU NCNb DRHU NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFbO DRHO NCNb VALU~ -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.25o -999.250 -999.250 /0 DEPTH ~400.000 t{O0.O00 ~200.000 ]100.000 ~000.000 2900.000 2800.000 2700.000 2600.000 2514.000 NNEMONIC VALUE MNEMONIC SP -999.250 ILO GR -999.250 GR NPHZ -99925.000 RHOB ~'CNU -999.250 GR SP -999.250 GR -999.250 NPHI -99925.000 FCNU -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNG -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNb -999.250 SP -999.250 GR -999.250 NPHI -99925.000 FCNL -999.250 8P -999.250 GR -999.250 NPH1 -99925.000 ~CNL -999.250 GR RHOB GR GR RHUB GR GR RHOB GR 1LD GR RHOB GR iLD GR RMOB GR ILO GR RHOB GR SP -999.250 GR -999.250 GR NPHI -99925.000 RHOB FCNL -999.250 GR SP -999.250 lhD GR -999.250 GR NPHI -99925.000 RHOB FCNb -999.250 GR SP -999.250 GR -999.250 GR NPHI -99925.000 RHOB ~CNL -999.250 GR VALUE -999.250 37.563 -999.250-999.250 -999.250 50.906 -999.250-999.250 -999.250 35.375 -999.250-999.250 -999.250 65 000 -999~250-999.250 37 469 -999.250 -999.250 -999.250 46.906 -999.250-999.250 -999.250 43.250 -999.250-999.250 -999.250 2b. O00 -999.250-999.250 -999.250 18.141 .-999.250 999.250 -999.250 26.703 -999.250-999.250 MNEMONIC CALk NRAT DT CALl NRAT DT ibm CALl NRAT DT CALl NRAT DT CALl NRAT DT CAbI NRAT DT ibm CALl NRA~ DT kLM CALl NRAT DT CALl NRAT DT CALl NRAT DT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25O -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .-c~9 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC SFbU DRHO NCNh 8FbU DRHO NCNb DRHO NCNb SFLU DRHO NCNb SFLO DRHO NCNb SFLU DRHO NCNb SFbU DRHO NCNb SFbU DRHO NCNb DRHO NCN{~ SFLU DRHO NCNb -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999. 50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SUMMARY O~' DATA RECURD$ NUMBER UF RECORDS: 1!36 LENGTH 0~' RECORDS: 906 BYTES LENGTM OF LAST RECORD: 518 BYTES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~'ILE NAME: 1024 BITES TAPE I~RA1LE~ LENGTH: 132 BYTES TAPE NAME: 60325 DATE: 80/ 6/ ~ SERVICE NAME: ~DIT TAPE CONTINUATION NUMBER: Ol NEXT TAPE NAME: COMMENTS: UNIQUE WELL IDENTIFICATION NUMBER IS 50-029-20422 ~-"' )~:i 1:~ H C]F' :0 C:: G / [:.'.' :3 .'l. 0 N F:' H I [:: N L. 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