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Home My WebLink About211-0307. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-48C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 211-030 50-029-22635-03-00 11953 Conductor Surface Intermediate Liner Liner 8956 79 3514 3514 511 8045 9298 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8870 35 - 114 34 - 3548 32 - 8554 8341 - 8852 3901 - 11946 35 - 114 34 - 3545 32 - 8324 8146 - 8575 3898 -8957 11868 , 11870 470 3090 5410 7500 11160 9490 1490 5750 7240 8430 10570 9540 - 11900 4-1/2" 12.6# L-80 29 - 8341 8911 - 8960 Structural 4-1/2" Baker S-3 Perm, 8306 , 8117 No SSSV 8306 8117 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com 907.564.5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028306 30 - 8147 0 0 0 0 0 0 0 0 0 0 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.07.18 12:57:02 -08'00' By Grace Christianson at 11:26 am, Aug 01, 2023 RBDMS JSB 080323 WCB 3-8-2024 DSR-8/4/23 ACTIVITYDATE SUMMARY 6/20/2023 T/I/O = SSV/0/100. Temp = SI. Pre suspended well inspection. No AL. Area around well is free of debri. SV, SSV, WV = C. MV = O. IA, OA = OTG. 13:00 6/22/2023 T/I/O = 86/0/155. Temp = SI. AOGCC SU inspection. Inspector Kam StJohn. SV, WV, SSV = C. MV = O. IA, OA, = OTG. 12:45 Daily Report of Well Operations PBU 15-48C Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/31/2023 InspectNo:susKPS230623154504 Well Pressures (psi): Date Inspected:6/22/2023 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:11/1/2021 #321-554 Tubing:86 IA:0 OA:155 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:6/21/2023 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT 15-48C Permit Number:2110300 Wellhead Condition Well was in good shape no leaks or coloration on tree. All valves had gauges. Surrounding Surface Condition Area was clear of trash and debris well house was in fair shape; no sheen observed. Condition of Cellar Cellar was dry and in clean condition Comments Verified by pad map Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, July 31, 2023              MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, December 19, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 15-48C PRUDHOE BAY UNIT 15-48C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/19/2022 15-48C 50-029-22635-03-00 211-030-0 N SPT 8117 2110300 2200 138 2446 2343 2310 0 0 0 0 OTHER P Bob Noble 10/15/2022 MIT-T to 2200 as per sundry 321-544 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 15-48C Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN221016134840 BBL Pumped:1 BBL Returned:0.8 Monday, December 19, 2022 Page 1 of 1        Suspended 1-Oil completion  MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 22 Township: 11N Range: 14E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 11953 ft MD Lease No.: ADL 0028306 Operator Rep: Suspend: X P&A: Conductor: 20 O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface: 9-5/8" O.D. Shoe@ 3548 Feet Csg Cut@ Feet Intermediate: 7" O.D. Shoe@ 8554 Feet Csg Cut@ Feet Liner: 4 1/2" O.D. Shoe@ 8852 Feet Csg Cut@ Feet Liner: 2-7/8" - 3 1/2" O.D. Shoe@ 11946 Feet Csg Cut@ Feet Tubing: 4-1/2" O.D. Tail@ 8341 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bridge plug 9490 ft 9298 ft 8.4 ppg C.T. Tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I witnessed the verification on the first plug in the suspension process (well has future utility as producer). Top of cement was tagged with coil tubing that applied 7500 bls to the plug found at 9298 ft MD. No MIT. October 8, 2022 Lou Laubenstein Well Bore Plug & Abandonment PBU 15-48C Hilcorp North Slope LLC PTD 2110300; Sundry 321-554 none Test Data: Casing Removal: Cody Fenstermaker Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-1008_Plug_Verification_PBU_15-48C_ll Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:211-030 6.API Number:50-029-22635-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028306 Property Designation (Lease Number):10. 8. PBU 15-48C 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 Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11953 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended 5 Contact Name: Oliver Sternicki Contact Email: Oliver.Sternicki@hilcorp.com Authorized Name: Bo York Authorized Title: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: OtherAlter 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: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8956 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend 5 Plug for Redrill Perforate Perforate New Pool 8306, 8117 No SSSV Installed Date: Liner 8045 3-1/2" x 3-3/16" x 2-7/8"3901 - 11946 3898 -8957 10570 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 34 - 3548 34 - 3545 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 114 Structural 7240 / 8160 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 9540 - 11900 8911 - 8960 4-1/2" 12.6# L-80 29 - 8341 Liner511 8640 8640 9510 , 11868 35 - 114 470 9-5/8" 7" Contact Phone:(907) 564 - 4891 Date: 5410 / 7020 79 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3514 5750 Intermediate 8522 32 - 8554 32 - 8324 511 4-1/2" 8341 - 8852 8146 - 8575 8430 7500 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 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. 2520 12/01/2021 8397 10/20/21 By Samantha Carlisle at 9:05 am, Oct 22, 2021 321-554 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.22 08:21:10 -08'00' Bo York DSR-10/25/21 State to witness coiled tubing tag a pressure test (MIT-T) to 2200 psi. Variance to 20 AAC 25.110 (c) approved for placement of cemented reservoir plug only. MGR22OCT21 10-407 SFD 10/22/2021 dts 11/1/2021 JLC 11/1/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.01 17:55:19 -08'00' RBDMS HEW 11/3/2021 Hilcorp North Slope, LLC Bo York, PBE Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well 15-48C (PTD #211030) Application for Suspension (10-403) Dear Mr. Price, Prudhoe Bay well 15-48C was drilled in 6/2011and completed with 1010’ of perforations in Z1A/B (60’ in Z1B). The well has a 5000’ liner top extension patch that was set over two known holes at 6660’ MD and 6795’ MD in the 4.5” tubing. The IA broke MOASP on 5/27/2016 and failed a subsequent TIFL and MIT-IA. An LDL performed on 6/13/2016 found a PC leak at 5273’ MD. Under sundry 318-183, work was planned to remediate the PC leak with an IA cement squeeze with a proposed IA cement top at 4120’.This work as executed on 6/5/2021. The IA cement top logged on 6/17/2021 was at 2720’ and the AOGCC has deemed the well inoperable in a letter dated 6/23/2021. Prudhoe Bay well 15-48C has future utility as a development well. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well has previously been shown to be mechanically sound with a passing CMIT-TxIA to 2597 psi on 6/14/2021 post cement squeeze and a passing MIT-T to 2318psi on 8/12/2021 against a plug set at 8640’.As part of the proposed sundry work the current plug at 8640’ will be removed and a CBP with cement will be set and tested to satisfy the perforated interval plugging requirements under 20 AAC 25.112. Attached is an Application for Sundry Approval (10-403) in which Hilcorp North Slope, LLC requests approval of well work to convert the well to suspended status. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to be suspended in the proposed condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. In summary, Hilcorp believes Prudhoe Bay well 15-48C will be mechanically sound and secure after completion of the proposed sundry well work and meets the requirements for suspended status. If you have any questions, please call me at 907-777-8345 or Oliver Sternicki at 907-564-4891. Sincerely, Bo York PBE Operations Manager Proposed Wellwork ProgramAttachment: 10/20/2021 15-48C has future utility as a development well. AOGCC has deemed the well inoperable i Suspend Sundry Well: 15-48C Well Name:15-48C API Number:50-029-22635-03 Current Status:Not Operable Ivishak Producer Rig:SL, CT Estimated Start Date:December 2021 Estimated Duration:N/A Reg.Approval Req’d?Yes Regulatory Contact:Carrie Janowski First Call Engineer:Aras Worthington 907-564-4763 (O) Second Call Engineer:Ryan Thompson 907-564-5280 (O) Current Bottom Hole Pressure (est):3350 psi @ 8800’ TVD (Ivishak average) Maximum Expected BHP:3400 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2520 psi Gas Column Gradient (0.1 psi/ft) History 15-48C is a natural flow Ivishak producer that developed PC and Tubing leaks in 2016 rendering it Not Operable. The OA shoe was cemented via a downsqueeze in 2003 with 37 bbls of Arcticset cement displaced with 73 bbls of diesel, leaving an expected TOC in the OA of ~2600’ MD. A CTD sidetrack was performed in 2011 and completed with a 3-1/2” 5000’ liner top extension which served as a patch over 4-1/2” tubing leaks between 6660’ MD and 6795’ MD. The well was Operable for about 5 years before developing a PC leak @ ~5270’ MD in 2016 which rendered it Not Operable. In 2018 a Sundry was approved under CO 736 rules to repair the PC and tubing leaks with an IA cement job. The expected TOC in the IA was ~4120’ MD. In 2018 the approved Sundry work commenced. In 2021 the work was completed, however the TOC in the IA was logged @ ~2720’ MD (~1400’ shallower than expected). The volumes pumped during the cement job, minus losses to the PC leak, indicated clearly that the cement had not entered the 7” x 4-1/2” IA at the perforations, but rather short-circuited up the 4-1/2” x 3-1/2” annulus and entered the IA @ ~6700’ MD (see attached schematic). Current Status Not Operable and Secured with an Evotrieve plug. Objective Secure and Suspend the well with a mechanical Bridge Plug and Cement. A variance to the provisions of 20 AAC25.110 (c) (2) is also requested to allow the well to be suspended with a single, deep-set cement plug and not an additional cement plug at surface. This would allow for reversibility of the plugging of the well should AOGCC determine at a later date that the well is safe and suitable for production. Secure and Suspend the well with a mechanical Bridge Plug and Cement. A Suspend Sundry Well: 15-48C Procedural steps Slickline 1. Pull Evotrieve from ~8640’ MD. Coiled Tubing 1. MU 2.5” Nozzle and drift to 2-7/8” XO @ ~9510’ MD. 2. Tag XO and flag pipe for Bridge Plug setting depth. 3. MU 3-3-16” CBP or CIBP. 4. RIH to flag and set CBP @ ~9490’ MD (~50’ above perforations). 5. POOH and MU Pig-Shear-Cementing-Nozzle. 6. RIH to top of CBP. 7. Load foam pig followed by ~1-bbl of 15.8 ppg Class G cement. 8. Launch second foam pig with shear ball in it. 9. Lay in ~1bbl of cement from CBP up to ~9360’ MD (~130’ of cement). 10. Shear Pig Nozzle and POOH. 11. WOC to reach 500 psi compressive strength. 12. Tag TOC with Nozzle (AOGCC Witnessed, ensure 24-hour notice provided for Inspectors). Fullbore 1. Conduct AOGCC witnessed MIT-T to 2100 psi. Ensure 24-hour notice provided for AOGCC. Suspend Sundry Well: 15-48C 15-48C Current Wellbore Schematic: Suspend Sundry Well: 15-48C 15-48C Suspended Proposed: CBP @ ~9490’ MD w/ ~130’ Of Cement Laid in on top. Expected TOC @ ~9360’ MD Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:211-030 6.API Number:50-029-22635-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028306 Property Designation (Lease Number):10. 8. PBU 15-48C 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 Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11953 Effective Depth MD: L-80 11. 8/23/2021 Commission Representative: 15. Suspended 5 Contact Name: Oliver Sternicki Contact Email: Oliver.Sternicki@hilcorp.com Authorized Name: Bo York Authorized Title: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: OtherAlter 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: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8956 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend 5 Plug for Redrill Perforate Perforate New Pool 8306, 8117 No SSSV Installed Date: Liner 8045 3-1/2" x 3-3/16" x 2-7/8"3901 - 11946 3898 -8957 10570 11160 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 34 - 3548 34 - 3545 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 114 Structural 7240 / 8160 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 9540 - 11900 8911 - 8960 4-1/2" 12.6# L-80 29 - 8341 Liner511 8640 8640 9510 , 11868 35 - 114 470 9-5/8" 7" Contact Phone:(907) 564 - 4891 Date:8/17/2021 5410 / 7020 79 149020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3514 5750 Intermediate 8522 32 - 8554 32 - 8324 511 4-1/2" 8341 - 8852 8146 - 8575 8430 7500 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 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. 8367 By Samantha Carlisle at 10:36 am, Aug 19, 2021 321-407 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.08.19 07:25:13 -08'00' Bo York DSR-8/20/21SFD 8/19/2021 iion Required??Subsequuent Forrm RequYesNo COMMISSIONNER tioon MIT Req'dd?Yes No tion Required?Subsequent Form Requ COMMISSIONER c ion Required?uent Form Requ COOMMISSIONER t RBDMS HEW 9/3/2021 Hilcorp North Slope, LLC Bo York, PBE Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 08/16/2021 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well 15-48C (PTD #211030) Application for Suspension (10-403) Dear Mr. Price, Prudhoe Bay well 15-48C was drilled in 6/2011and completed with 1010’ of perforations in Z1A/B (60’ in Z1B). The well has a 5000’ liner top extension patch that was set over two known holes at 6660’ MD and 6795’ MD in the 4.5” tubing. The IA broke MOASP on 5/27/2016 and failed a subsequent TIFL and MIT-IA. An LDL performed on 6/13/2016 found a PC leak at 5273’ MD. Under sundry 318-183, work was planned to remediate the PC leak with an IA cement squeeze with a proposed IA cement top at 4120’. This work as executed on 6/5/2021. The IA cement top logged on 6/17/2021 was at 2720’ and the AOGCC has deemed the well inoperable in a letter dated 6/23/2021. Prudhoe Bay well 15-48C has future utility as a development well. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is mechanically sound and secured with a passing CMIT-TxIA to 2597 psi on 6/14/2021 post cement squeeze and a passing MIT-T to 2318psi on 8/12/2021 against a plug set at 8640’. Attached is an Application for Sundry Approval (10-403) in which Hilcorp North Slope, LLC requests approval of suspension status for this well. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to be suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. In summary, Hilcorp believes Prudhoe Bay well 15-48 is mechanically sound and secure and meets the requirements for suspended status. If you have any questions, please call me at 907-777-8345 or Oliver Sternicki at 907-564-4891. Sincerely, Bo York PBE Operations Manager Attachments Wellbore Schematic Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.08.19 07:25:01 -08'00' Bo York David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-5245 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 07/22/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL FTP Folder Contents: Log Print Files and LAS Data Files: Well API # PTD # Log Date Log Type PBU 15-48C 500292263503 211-030 6/16/2021 CBL PBU B-07A 500292028501 214-091 1/20/2021 CBL PBU C-03C 500292012403 212-058 7/10/2021 PPROF PBU C-29B 500292147202 214-049 7/10/2021 PPROF PBU C-41B 500292238502 213-104 6/26/2021 CBL PBU F-10C 500292041003 213-086 7/11/2021 CBL PBU P2-34 500292255800 195-066 6/17/2021 CBL Please include current contact information if different from above. Received By: 07/23/2021 37' (6HW By Abby Bell at 9:33 am, Jul 23, 2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:211-030 6.50-029-22635-03-00 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 11953 11911 8959 8306 9510 none 8117 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 35 - 114 35 - 114 1490 470 Surface 3514 9-5/8" 34 - 3548 34 - 3545 5750 3090 Intermediate 8522 7" 32 - 8554 32 - 8324 7240 5410 Liner 511 4-1/2" 8341 - 8852 8146 - 8575 8430 7500 Perforation Depth: Measured depth: 9540 - 11900 feet True vertical depth:8911 - 8960 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 29 - 8341 30 - 8147 8306 8117Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 8045 3-1/2" x 3-3/16" x 2 3901 - 11946 3898 - 8957 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): 92 bbls 15.8ppg Class G cement into 3-1/2" x 4-1/2" annulus IA = 613psi Tbg = 1434 psi Coil Tbg = 3842 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 33408583 00 0 39044 0 0 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: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 4102 Treatment descriptions including volumes used and final pressure: 13. 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 measured8956 Sundry Number or N/A if C.O. Exempt: 318-183 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Punch tbg, IA Squeeze Operations shutdown Change Approved Program 5 8239' - 8249' Tbg punch 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 Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028306 PBU 15-48C 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 By Samantha Carlisle at 12:51 pm, Jul 12, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.10 09:23:04 -08'00' Bo York SFD 7/16/2021DSR-7/13/21 RBDMS HEW 7/12/2021 MGR30JUL2021 ACTIVITYDATE SUMMARY 7/14/2018 ***WELL S/I ON ARRIVAL***(cement squeeze) SWCP SLICKLINE UNIT 4521 SCHEDULING STANDBY ***CONTINUED ON 07-15-18*** 7/15/2018 ***CONTINUED FROM 07/14/18 WSR***(cement squeeze) LRS LOAD TUBING WITH 151BBL KCL, 40BBL CRUDE SET 4-1/2" STANDING VALVE @ 3,891' SLM LRS PERFORM FAILING MIT-T (llr = 2.5gpm at 3000psi) PULL & RE-DRESS 4-1/2" STANDING VALVE SET 4-1/2" STANDING VALVE @ 3,891' SLM LRS PERFORM PASSING MIT-T TO 2,649 PSI DRIFT TO 4,100 W/ 8'8" OF 2-1/8" STEM W/ BULLNOSE, NO ISSUES (for e-line rct cutter) ***WELL S/I ON DEPARTURE*** 7/15/2018 T/I/O- 930/500/0 Temp= S/I (LRS Unit 72 - Load & Test) Pumped 151 bbls 110* 1% KCL followed with 40 bbls crude down TBG to load and FP, Pumped a total of 3 bbls crude down TBG to achieve a leak down rate of 2.5 gpm from 3000 psi to 2700 psi, Bleed TBG pressure, Bled back ~ 1 bbls, S/L moved standing valve up hole. MIT-T to 2500 psi (3000 psi max applied pressure) PASSED at 2649 psi. Lost 23 psi during the first 15 minutes.Lost 18 psi during the second 15 minutes. Pumped 12.7 bbls of 84* F crude to achieve test pressure. Bleed back 2 bbls. Tags hung on well, SSL in control of well and DSO notified of well status upon departure. Lateral open. WV closed.IA/OA OTG. FWHP=15/460/2. 7/16/2018 *** WELL S/I ON ARRIVAL *** (SLB E-LINE CONVEYED RST CUTTER) INITIAL T/I/O = 0/450/0 PSI. RUN 1: PUNCH TUBING 3914' - 3915' W/ 1.56", 4 SPF, 0 DEG PHASE, MEDIUM CHARGE PUNCHER. RUN 2: RIH W/ 2" POLLARD RCT. CCL NOT WORKING PROPERLY, POOH & MOVE CCL ABOVE CENTRALIZER. RUN 3: RIH W/ 2" POLLARD RCT & CUT TBG AT 3917'. ALL LOGS CORRELATED TO LINER SUMMARY DATED 6/2/2011. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 0/0/0 PSI. ***JOB COMPLETE 16-JULY-2018** 8/9/2018 CTU 9 1.75" CT Job Objective: Pull LTP and Orifice packer. MIRU. Rih with BOT fishing BHA to 3898' CTMD (3901 MD). Latch deployment sleeve. Hit 2 jar licks and pulled free on third. PU and let elements relax. Pooh with Deployment Sleeve, 45KB packer, 5.75' of 3.50" pup joint. Missing 1 element. Reciprocate on top of tubing stub with 3.69" Venturi.. Pooh. No recovery. Make up WFT Orifice Pulling BHA and RIH. Parted reel drive chain at 954'. ...Continued on WSR 8-10-18........ Daily Report of Well Operations PBU 15-48C Daily Report of Well Operations PBU 15-48C 8/10/2018 CTU #9 - 1.75" Coil ***Cont. from WSR 8-9-18*** Job Objective: Pull LTP, Pull Orifice sub and ER Packer Repair reel drive chaiin and cont. RIH with WFT Orifice Fishing BHA to 10148' ctm. Stack 7K. Pull 3k over and shear snap latch. Pooh w/ Orifice snap latch. Rih with WFT WidePack retreival too to 10153' ctm. Pull 10K over and pull free. Pooh w/o packer. Tool showing signs we were not fully engaged. Rih w/ WidePack spear to 10153' ctm. Make multiple renditions to try and engage and unable to see any overpulls. POOH. Lay down tools and trim coil. Make up Widepack fishing BHA with hydraulic GS style spear with 2.00" slick catch slips. RIH. ...Continued on WSR 8-11-18.... 8/11/2018 CTU #9 - 1.75" Coil ***Cont. from WSR 8-10-18*** Job Objective: Pull LTP, Pull Orifice and Widepack Packer RIH with slick catch hydraulic release spear and latch on to packer at 10154' CTMD (10152 MD). Able to hit 19 jar licks before losing ability to latch fishing neck. POOH. Pulling tool shows signs of stripping out fishing neck. Weatherford redress another spear. Rih and tag at 9980' ctm. Friction bites. Pooh to inspect tools. Recovered 2.25" WFR Widepack. (Missing slip segments, springs and elements and part of slip carrier housing). Drift with 2.75" JSN to 8783' ctm. POOH and FP well. RDMO CTU ***Job Complete*** 12/29/2018 T/I/O = SI/20/20. Temp = SI( -3°). Wireless install (WOLP). Installed wireless devices, Verified tag creation, Local indication and Transmitter values through gateway on IA/OA & Temp transmitter. Installed temperature transmitters on S- riser and flow line. FCO Complete and ready to turn over to operations. SV, WV, SSV, = C. MV = O. IA, OA = OTG. 1800 hrs. 3/9/2019 T/I/O = Vac/Vac/10. Temp = SI. LTSI Wells. No AL. Performed MV LTT = Pass. SV, WV (LOTO), SSV = C. MV = O. IA, OA = OTG. 02:30 5/26/2019 ***WELL S/I ON ARRIVAL*** RAN 2.71" CBP DRIFT, UNABLE TO PASS 3925' ELM (700# overpull) LRS PUMPED 150 BBL'S OF CRUDE DOWN TUBING. RAN 2.63" SWAGE, 2' x 1-7/8" STEM & 2.60" G. RING, UNABLE TO PASS 3925' ELM (clean p/u). ***JOB CONTINUED ON 27-MAY-2019*** 5/26/2019 T/I/O= vac/vac/5 Temp= S/I (LRS Unit 70 - Assist E-Line: Load & Kill) Pumped 150 bbls of 70* crude to flush metal shavings from TBG. E-Line in control of well upon LRS departure. FWHP's 1/2/7 5/27/2019 ***JOB CONTINUED FROM 26-MAY-2019*** DRIFT FREELY W/ 2.60" DECENTRALIZER & 2.59" SWAGE TO 8650' ELMD. ***JOB CONTINUED ON 27-MAY-2019*** 5/27/2019 T/I/O= 134/vac/7 Temp= S/I (LRS Unit 70 - Assist E-Line) Rigged up to choke trailer and pressure tested. ***Job continued 05/28/18*** Daily Report of Well Operations PBU 15-48C 5/28/2019 ***JOB CONTINUED FROM 27-MAY-2019*** SET 3-1/2" BAKER CBP AT 8310' MD MID-ELEMENT. TOP OF PLUG AT 8309'. LRS PERFORMED MIT-T AND CMIT-TxIA TO 2500 PSI. SEE LRS LOG FOR DETAILS. PUNCH 3-1/2"x4-1/2" @ 8,250' - 8,255' MD W/ 2", 6 SPF, 60 DEG PHASE, JRC BH CHARGE GUN. LRS PERFORMED MIT-T AND CMIT-TxIA TO 2500 PSI, SEE LRS LOG FOR DETAILS. ALL LOGS CORRELATED TO TUBING TALLY DATED 10-MAR-1996. ***JOB COMPLETE 28-MAY-2019*** 5/28/2019 *****Job continued from 05/28/19 T/I/O= 134/vac/7 Temp= S/I (LRS Unit 70 - Assist E-Linel) Pumped 26 bbls down TBG taking returns up IA to open top tank. Established a LLR of 1.55 bpm. Pumped 9 bbls down TBG & IA through PC leak establishing a LLR of .28 bpm. E-line shoot perforation Pumped down TBG up IA through choke to open top tank with 90* crude pumped 14 bbls before establishing LLR @ 2.2 bpm @ 2400 psi for 21 bbls Pumped down TBG & IA @ the same time to PC leakwith 90* crude pumped 10 bbls before establishing LLR @ .70 bpm @ 2450 psi for 10 bbls Circ-out well 260 bbls of 40* diesel down TBG up IA through choke down neighboring well 15-04 WIng shut swab shut ssv shut master open casing valves open to gauges Final WHp's=300/300/28 1/23/2020 T/I/O = 620/620/VAC. Temp = SI. WHPs (LTSI). No AL. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:00 1/5/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line Tubing Punch) RIH W/ 2-1/2" x 10', 6 SPF, 60 DEG PHASE, TITAN BIG HOLE CHARGE GUN. S/D IN PREVIOUS TBG PUNCH, UNABLE TO GET FREE. PUNCH 3-1/2" x 4-1/2" AT 8,238.5' - 8248.5'. ***JOB COMPLETE ON 05-JAN-2021*** 1/7/2021 LLR (CEMENT SQUEEZE (OA/IA DWNSQZ) Pumped 41 bbls crude down Tbg to IA taking returns to open top tank. Got a LLR of ~2.75 bpm @ 2500 psi. Pumped 32 bbls crude down Tbg and IA at the same time taking no returns and got a LLR of ~1.85 bpm @ 2480 psi. Pumped 18 bbls crude down Tbg taking no returns and got a LLR of ~1.6 bpm @ 2480 psi. Pumped 28 bbls crude down IA taking no returns and got a LLR of ~2 bpm @ 2475 psi. SV,WV,SSV=C MV=O IA,OA=OTG 6/4/2021 CTU #9, 1.75" Coil - 33.6bbl, Job Objective: IA Cement and Mill Retainer and CBP. MIRU CTU. Make up 2.75" DJN drift BHA. Perform injectivity test of 1.5 bpm @ 2108 psi down the tubing, and 2.0 bpm @ 2105 psi down the IA. RIH and Tag. ...Job in Progress... 6/5/2021 CTU #9, 1.75" CT, Job Objective: IA cement job Set Alpha One Trip cast iron cement retainer ME at 8,225'ctm. LRS circulate 80bbl of 90degF diesel, 20bbl returns taken to formation then 60bbl circulated up IA. Circulate 91bbl bbl 15.8ppg Class G cement down the coil, placing it in the 3-1/2" x 4-1/2" annulus as well as the IA. Unsting from the retainer and lay in 1 bbl of cement and POOH pumping pipe displacement. Wait for cement to reach 500 psi of compressive strength. Make up 2-1/8" motor and 2.80" junk mill. Dry tag at 8126'ctm. Mill through cement and retainer at 8221'ctm. Currently milling ahead at 8276'ctm. ...In Progress... Daily Report of Well Operations PBU 15-48C 6/5/2021 ***Assist coil*** Pump 80 bbls diesel at 90* down coil. Coil on well at time of departure. 6/6/2021 CTU #9, 1.75" CT, Job Objective: IA cement job Mill cement between retainer and CBP. Milled CBP at 8305'. Remnants pushed to seal stinger 8786'ctm. POOH. RIH with 2.30" junk mill. Mill CBP and Retainer remnants and push to 11868' CTMD. POOH and FP well. RDMO CTU. ***Job Complete*** 6/11/2021 **WELL S/I ON ARRIVAL** DRIFT w/ 2.72" CENT,3'x1.75",2.74" GAUGE RING TO SEAL STINGER @ 8773'MD. **WSR CONT ON 6/12/21** 6/12/2021 T/I/O= 0/0/0. LRS unit 72 Assist Slickline (CEMENT SQUEEZE). Pumped 100 bbls of 1% KCl and 40 bbls of diesel into the TBG. Final T/I/O= 300/0/0. 6/12/2021 **WSR CONT'D FROM 6/11/21** LRS LOADED TBG w/ 100BBLS 1% KCL SEAWATER & 40BBL DSL FP SET 2.70" AD-2 SLIPSTOP @ 8648'MD SET 2.70" D&D PLUG @ 8643'D SET P-PRONG ON GUTTED JD & BAITSUB IN D&D PLUG ATTEMPTED 2500PSI MIT-T *TBG HELD 2500PSI FOR ~1MIN & WENT ON VAC* PULLED PRONG *PACKING MISSING & TORN* RE-SET PRONG @ SAME ATTEMPTED TO PT PLUG *TBG DID NOT BUILD PRESSURE* **WSR CONT ON 6/13/21** 6/13/2021 **WSR CONT'D FROM 6/12/21** TESTED TBG TO 1000PSI w/ D&D HOLEFINDER ON BAITED PRONG @ 8636'MD PULLED BAITSUB & PRONG @ SAME. PULLED D&D PLUG @ 8643'MD *RUBBER ELEMENT MISSING* RAN 3 1/2" WIRE GRAB TO AD-2 SLIPSTOP @ 8648'MD *DID NOT RECOVER MISSING ELEMENT* SET NEW D&D PLUG @ 8643'MD SET P-PRONG ON GUTTED JD & BAITSUB 8636'MD. 2500PSI MIT-T *FAILED BY .5PSI IN SECOND 15MIN* 2500PSI C-MIT *PASSED* *WSR CONT ON 6/14/21* 6/14/2021 T/I/O= 174/172/0 Temp= SI. LRS unit 72 AOGCC (Lou Laubenstein) CMIT-TxIA to 2500 psi *PASSED* at 2632 psi (2750 psi max applied). T/IA lost 78/78 psi during the first 15 minutes and 37/37 psi during the second 15 minutes. T/IA lost 115 psi during the 30 minute test. Pumped 2 bbls of 67* F diesel to achieve test pressure. Bled back 0.2 bbls from the IA. TBG came down to 2594 psi. MIT-T to 2500 psi *PASSED* at 2509 psi (2750 psi max applied). TBG lost 37 psi during the first 15 minutes and 27 psi during the second 15 minutes. The test was run out a third 15 minutes. It lost 23 psi which demonstrated stabilization. Bled back 1.8 bbls to final T/I/O= 200/200/0. Daily Report of Well Operations PBU 15-48C 6/14/2021 **WSR CONT'D FROM 6/13/21** LRS CONDUCTED STATE WITNESSED C-MIT. *PASSED* LRS CONDUCTED STATE WITNESSED MIT-T. *WELL WENT ON VAC AFTER 3MIN* PULLED BAITED P-PRONG @ 8636'MD PULLED D&D PLUG @ 8643'MD *ELEMENT MISSING* RETRIEVED 2/3 OF MISSING ELEMENT FROM SLIPSTOP @ 8648'MD PULLED SLIPSTOP @ SAME. SET EVO-TRIEVE PLUG @ 8640 *MID ELEMENT* LRS ON LOCATION TO RE-DO STATE TEST. **WSR CONT ON 6/15/21** 6/14/2021 T/I/O= 868/865/0 Temp= SI. LRS unit 72 AOGCC (Lou Laubenstein) CMIT-TxIA to 2500 psi *PASSED* at 2597 psi. (2750 psi max applied). T/IA lost 93/74 psi during the firsr 15 minutes and 58/29 psi during the second 15 minutes. T/IA lost 151/103 psi during the 30 minute test. Pumped 2.12 bbls of 88* F diesel to achieve test pressure. Bled back 0.4 bbls from the IA to T/I/O= 2486/1020/0. MIT-T to 2500 psi *FAILED* after 5 minutes. TBG abruptly dropped to 0 psi. Pumped .14 bbls of diesel to reestablish test pressure. Final T/I/O= 0/850/0. 6/15/2021 **WSR CONT'D FROM 6/14/21** 2500PSI MIT-T *PASSED* RAN CBL, LOGGING FROM 8400' TO 2900'SLM. SET 4 1/2" WHIDDEN CATCHER ON TBG STUB @ 3917'MD PULLED INTG-DMY @ 3677'MD BLED TBG TO 150PSI & PT'D TO 1500PSI, 100PSI CHANGE ON IA, DOES NOT APPEAR TO BE COMMUNICATION THROUGH OPEN POCKET. **WSR CONT ON 6/16/21** 6/16/2021 **WSR CONT'D FROM 6/15/21** TESTED TBG TO 2500PSI w/ OPEN POCKET @ 3677'MD *NO TxIA COMMUNICATION* TESTED IA TO 2500PSI w/ OPEN POCKET @ 3677'MD *NO IAxT COMMUNICATION* SET INTG-DMY IN GLM # 1 @ 3677'MD PULLED EMPTY WHIDDEN @ 3912'MD CBL DELAYED TILL 6/17/21 **WSR CONT'D 6/17/21 6/17/2021 **WSR CONT'D FROM 6/16/21** RAN CBL, LOGGED FROM 8300'MD TO SURFACE. PULLED EVO TRIEVE PLUG @ 8637'MD **WELL S/I ON DEPARTURE** MEMORANDUM To: Jim Regg�rr /2�� { 1'.1. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, .lune 17, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 15-48C PRUDHOE BAY UNIT 15-48C Src: Inspector Reviewed By: P.I. Supry �`— Comm Well Name PRUDHOE BAY UNIT 15-48C API Well Number 50-029-22635-03-00 Inspector Name: Lou Laubenstein Permit Number: 211-030-0 Inspection Date: 6/14/2021 ' Insp Num: mitLOL210616083848 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I- - --- - - - I - Well 15-48C Type Inj N !TVD Tubing! 2632 - 2594- 2559 2532 - 2509 - PTD 2110300 Type Testl SPT iTest psi 2500 IA ; 2633 1994 - 2024 2020 - 2014 BBL Pumped: BBL Returned: 1.8 OA 0 0 0 0 0 Interval. OTHER IP/F P i Notes: MIT -T to 2500 psi per Sundry # 318-183. This is the second test after the Tubing plug failed and was reset. The IA was bleed down after the MIT-T/1A test and MIT -T was started. Thursday, June 17, 2021 Page I of I MEMORANDUM TO: Jim Regg �C� � �� ( 7 P.I. Supervisor FROM: Lou LaubenStein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 15-48C PRUDHOE BAY UNIT 15-48C Sre: Inspector Reviewed By: P.I. Supry ►' Comm Well Name PRUDHOE BAY UNIT 15-48C API Well Number 50-029-22635-03-00 Inspector Name: Lou Laubenstein Permit Number: 211-030-0 Inspection Date: 6/14/2021 Insp Num: mitLOL210616083057 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 15-48C - 'iType Inj N -TVD Tubing 2486 _ 2765 PT�i 10300 Type Test SPT_ Test psi 2500 IA 1020 - 1081 ' — —1 -i-- --- — -- - — - BBL Pumped: 01 1 BBL Returned: j OA o o Interval OTHER P/F I Notes: MIT -T to 2500 psi per Sundry # 318-183, The IA was bled down from the combo test and the tubing was brought back up to test pressure. 5 minutes in the test plug packing leaked causing the tubing pressure to go to zero . Thursday, June 17, 2021 Page 1 of I MEMORANDUM TO: Jim Regg 1 P.I. Supervisor '� I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 15-48C PRUDHOE BAY UNIT 15-48C Sre: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT 15-48C API Well Number 50-029-22635-03-00 Inspector Name: Lou Laubenstein Permit Number: 211-030-0 Inspection Date: 6/14/2021 — Insp Num: mitLOL210616082538 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 188 2748 2655 2567 - - Well f 15-48C —Type Irij [NN: 'TVDTpSi2500 PTD 1 2110300 ' Type Test sPT Test Ip 18s 2701 - 2627 zs9s ' BBL Pum ed: 2.1- BBL Returned: p o.a OA o 0 0 0 Interval OTHER P/F P Notes: CMIT TxIA to 2500 psi per Sundry #318-183` [his is the I st test and was retested due too the plug in the tubing failing during the MIT -T. Thursday, June 17, 2021 Page 1 of I • ®T• Tb • • fyP`\\� / THE STA$ \� ///� Alaska Oil and Gas ��►�."s4a�, of [AsKA Coservati®n Commission - __ � x �= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 , Main: 907.279.1433 AS Fax: 907.276.7542 www.aogcc.alaska goy Aras Worthington JUN0 LUT Interventions and Integrity Engineer scale BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-48C Permit to Drill Number: 211-030 Sundry Number: 318-183 Dear Mr. Worthington: 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, Cathy . Foerster Commissioner - DATED this /r"day of June, 2018. RBDMS1 JUN 14.2018 STATE OF ALASKA -- R$�.' CEiviD •ALASKA OIL AND GAS CONSERVATION COMMON 6 l II f APPLICATION FOR SUNDRY APPR S f 20 AAC 25.280 APR d 2018 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well B ' O.era ions shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing 0 Chan. :,. °$ •w' y�yi ❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other IA Squeeze l? • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 211-030 ' Exploratory 0 Development I?. 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-22635-03-00 99519-6612 Stratigraphic 0 Service ❑ 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 RI PBU 15-48C 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028306 • PRUDHOE BAY.PRUDHOE OIL • 1 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11953 t 8956 - 11911 8959 9510 1 • Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 35-114 35-114 1490 470 Surface 3514 9-5/8" 34-3548 34-3545 5750 3090 Intermediate 8522 7" 32-8554 32-8324 7240/8160 5410/7020 Liner 511 4-1/2" 8341-8852 8146-8575 8430 7500 Liner 8045 3-1/2"x 3-3/16"x 2-7/8" 3901-11946 3898-8957 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):. 9540-11900 8911-8960 4-1/2"12.6#L-80 L-80 29-8341 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 8306/8117 No SSSV Installed No SSSV Installed 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 0 • Service 0 14.Estimated Date for Commencing Operations: May 20,2018 15. Well Status after proposed work: Oil I0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 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: Worthington,Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington©bp.com Authorized Name: Worthington,Aras J Contact Phone: +1 907 564 4102 Authorized Title: Interventions&Integrity Engine � Authorized Signature: Date: .6/i /Aw/ COMMISSION USEONLYo�! Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3131s_. Plug Integrity 0 BOP Test 0 Mechanical Integrity Test V Location Clearance 0 Other: �helvde ivl a 1-'1 vzL I Por rcpnf+ on MA C�h-,r� -1. 5"-Lvcr3r5 /,- CVItvt/ t----7-Sv115 o f` sem 7` 1-1 ,+-0 b C - �t 5 rc�, k!9vlg � "Z' v /Yt vl �TcJ Q r- Jr 4-1 rt--1 n r ✓'-•`rLl �-.5 Post Initial Injection MIT Req'd? Yes 0 No Er" d am/ Spacing Exception Required? Yes 0 No Subsequent Form Required: / �7 12 ' Li / / APPROVED BYTHE Approved by: , 1.44r • COMMISSIONER COMMISSION Date:G _./€1.,/ !/'TL 10//3//5 u , , , RBOMs JUN 1 4 2018 ORIGINAL 3 S Submit Form an Attachments in Duplicat Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • �, • • Well: 15-48C 15-48C IA Cement API #: 50-029-22635-03 Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Paulina Meixueiro (907) 546-5971 Expected Start Date May 20th 2018 History 15-48C was drilled in 6/11 and completed with 1,010' of perforations in Z1A/B (60' in Z1B). The well has a 5000' liner top extension 'patch' (over 2 known tubing holes @ 6660' MD and 6795' MD). The IA broke MOASP on 5/27/16 and failed a TIFL two days later. After slickline dummied the GLV off, and MIT-IA failed. An LDL performed on 6/13/16 indicated a production casing leak at 5273' MD. The OA has shown no signs of integrity issues or sustained casing pressure (see attached TIO plot). Objective Well 15-48C was found to have a PC leak at 5273' MD and has been shut-in since 2016. By repairing this well with an IA cement squeeze, it is estimated that an incremental 140 mbo can be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the forese abe le future. The proposed TOC in the IA is -4120' MD which is -500' MD shallower than the top of the UG4 marker at 4621' MD and -570' TVD deeper than the surface casing shoe. Post-Job Evaluation 7 Coacyr. The &OI 'far r1i) (,rel' had 1. C • • CMIT TxIA and MITT • SCMT to locate TOC ro V9-i- 0040 'tJ airemtd to mkt rite Long-Term Integrity Monitoring Oc(l Mor(. COMpth.tioe 4f f 0 Q�er7 �' .4'0 • Record WHPs daily. p ,,q/' �,�eArive q„," 01 • Biennial CMIT TxIA and MITT. OtOrr-- Jiff/If-Mt f 4f5 4t e � e1114 q wor Vef 1,ovld pfo'e Cosr e " - q/d/or /e4v To qriccnrf ?f1 'ox(41 reCoiri. -pedaly mete 5/44 ylbw for oic "aced sp � P' °' ' Fe co 45, Cron 016' well. ," 57/4 Current Wellbore: • • 1746. 4.1116"ClW FLS SAFETY NOTES' WELL ANGLE m 1O fa 9341'''''3-1/2" AELLJ-EAD= RIC 1 5-48C CIROMELMR"' PPEIIIOUSWELL BORES NOT ACTUATOR__.____.BAKER C SHOWN"" OPV MGR PROFILE BALI,UNABLE TO SET 143.REV--= 88.7 TYIC 12!3113' BF BEV= KOP= 6548' 120'COFDUCtOR -{ ? � 2184' -I4-1(2'HES UO sSSV NP,D=3.613' Mu Angle- 94' 11772' I S+ DaumhO= 9290' �� _._... Wein 8800'SSV GA5�Mu, g 9-543'CSG 404,L-0O,t3TG+( 1fD- tf3t3' 1-1 341' �r/j I Si ND TVD DIS! 1YFE viv LATCH RAT CATE 1 3677 3675 1 KGB2-LS OAA' M 0 06/05/18 9-57'CSG,474,1-80,NSCX-ti D=8.88_.1'J--L 3548' si 2 8 8284 5 KGB2.LS '[78M M 0 07120+03 5283 8237 8059 34 K062-LS TIM M 0 03110'96 ALL MANDRELS FBiJF>E A MOORED LATCH 13.70'BOT OE4UY SLY,D=3.000" 3901 F 'STA'S R2&/3- • t- : ' PC Leak @ -5300'MD $ 390' -45 KB LAP TOP MRD=2.450" 0.4 BPM 141)@ 2200 psi - �+.- TBG Leaks from 6660' - 6795' MD . �.....� - 1 —x x 0.2 bpm @ 2500 psi S f ' IIII I — t , ' PIPE 8341' 14-112'Iii NA GG,D.3.068" 4-12TB ' G.1268,L-80 BM -• 8341' 8341' 1-7'X 4-12'TM'LTP w 17.35'TBR D 5248' .0152 hpf,D-3 958" �—-• 8357 1--17'X4-1/2'TMP LHR Hf ORD HcR D-3.915' 17"CSG,294,L-80 BTS.0371 bpi,D-6.184' H 8664 1 li 8773' I-3'SEAL 8TT3w 11-Q0.D•2.375" 3112 LP 9.211,17CRL8 STL,.0087 bp',D-2.997 H 8773 8778' I 3.70'OH'LCr'SLY w 145 KB LIP,D=3.00" _itJ 870W H45KBLNRTOPE I)-2.45' B9Tt3A11T8)TOP OF CEMENT -8806 8800' 13"BKR SEAL SITG8)&3.717'BTT G 12 LNR DQLOY SLY,D-2.375' ' 0 Y 31(2 LMR 9.34.L-80 511_,,0087 bpf,D=7 992' - 8832' ' M ► 8832' -3112"X33116'KO,D•2,7137 o Y.1 14 4-1/1'VM�STOCK(TAGGED 0922/11) 8860' Y,' ji - 14-117`LIR, 12.64,L-80 NSCT,.0152 bpt.D=3.958" H '.885. Y� +1 II<L W F vMr41L1,nr!1I-4iC) 5,35,7- [1838 PERFCRAT ON SUMMARY a 4'.tl�. — 9610' -3-3/113'X 2-718'XO,D-2.377' 1 REF LOG'SLB A®il C R/CCL 1 CM_ON 5/31111 `• T • 10157-11)1115'1-.2-7f8'WFO WDFC EPACK R TO ANGLEAT P FHS. 92"0 95417[ ' 0- CR 25' FMCE 111)08115) Noir Refer lo Roduction DB for hist/Hull poi dila - SIZE SIF PIT6iVAL OpruSgt SIM SOZ 2' 6 •9540-9570 0 11+07115 2' 6 9660 9720 0 1107115 , 2' 6 9815-9675 O 1107115 9510' (DBP(M MILLED Fn 2' 6 10220-10270 S 0601/11 12/27/13 &PUSHED IO 2' 6 10430-10770 $ 06,01/11 12127/13 3-3116'LFR 624,L-801011, 5510' �' 871001103[14) 2' 6 10810.1(600 $ 08+01/11 12/27/13 0078 6pf,D=2.97 2' 6 11100-11170 0 06101/11 2' 6 11210-11400 0 0601/11 2' 6 11dBD 11580 0 0601/11 PBTD11908' ~ 2' 6 11650-11790 0 0601/11 - 2-7113'LPR 0.184,L-60 STL,.0058 bpf,ID-2441" 1 ' 148' 19 �� 7 6 11850.11900 0 0841111 - DATE -REV BY COMENTS DATE FSI/BY =NEWS F+RUQHOE BAY UHT 01/2M911 INITIAL C OM PLLETION 01)07/14 TM PJC PAL /R.L3H COP B1U(0103114) VAR.L. 1 4EC 0221103'.11_11904 CTD SIDETRACK 115-48A} 11)17/15'TBLXM) GLVC )(11/12/15) FERharNo 2110300 11128)05 NOR=1CTD BIDETRAC!(115-486) 11117)15'JTA4'JLI3 SET F#t1ACFERFS(11107-08115) AHNo. 50-029-22635-03 0[1[06111 NOF1302CTDBIDE11 CK(15-48G) 06/07/16 JGUJAQ GLV 00(06105116} SEC 22,T11N,R14E 1309 FM_&259'FY _ 12477)13 DU PJC TREE C701 SFlY NOTE(12/3/13) 01107114 TTRPRFC CMT SOZ(1212 7,13) 13P eipinratlon(Alaska( 2 • • i TREE= 4-1/16"OW FLS SAFETY NOTE: WELL ANGLE>70'tip 9341''"'3-111" WELLHE/AD= FAAc 15-48 Proposed CTROMELW'"" PREVIOUS WEL.LBORE•S NOT ACTUATOR= BAKER C SHOWN"' BPV HGR PRORLE BAD;UNABLE TO SET KB.ETEV= 66.7' TWC 12/3/13"' BF.ELEV= ?� i KOP 8 20"OO�DUCTOR — ? ) 2184' —4-1/2'HES HXO SSSV NP,E)=3.813' 0 MUz Angle= 94"@ 11772' 1 [Mum NO= 9290' Datum ND= 8800'SS GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 9-5/8'CSG 40#,L-80,BTGM D=8.835" H 3461' 1 3677 3675 1 KGB2-LS TAW INT 0 06105/16 9518"CSG,47#,L-80,NSCC 13=8.661` H 3548' Krtri2 6288 6284 5 KGB2 LS `D 4V INT 0 07/20/03 �� 3 8237 8059 34 KG82-LS *DAV NT 0 03/10/96 o ALL MANDRELS REQUIIREA MODIRED LATCH 310•BOT DEFOY SLV,D=3.000' 3801' • g •STA'S 82&83=a _ :.:. .o ;‘,:i TOC in IA 4120'MD �e, I 3907' H45 KB LNR TOP PKR,D=2.450' v V v'0 66604 6660'-679E —{TUBING HOLE BEHIND PIPE r CSG,26#,L-80 BTC-M,.0383 bpf,ID=6.276` H81 8306' H 7'X 4112'BKR S-3 PKR D=3.875' 01 o� w� 8329' H4-1/2"FE,SXMP,0=3.813' BEHIND TV C i - v� lePIPE 4196 8341' H41/2'TES WILG,D=3.958' 4117 TBG,12.6#,L-80 BTM 8341' ► -4 WM. T X 41/2"TNN LTP w/7.35•TBR,ID=5249" .0152 bpf,ID=3.958" 8352' Hr X4-1/2"TIN LNR HYDRO HGR,ID=3.915' 7'CSG,29#,L-80 BTC-M,.0371 bpf,D=6.184' — 8554' 8773" H3'SEAL STINGER w/NaGo,ID=2.375' 3-1/2 UR,9.2#,13CR-80 STL .0067 bpf,D=2.992' H 8773' 8778" —{3.70'DEPLOY Sly w 145 KB LTP,D=3.00' f I 8784' —45 KB LNR TOP FKR 13=2.45" ESTIMATED TOP OF CEMENT 41808 8808' 3'BKR SEAL STINGER&3.70'BTT GEN 2 • LM2 DEPLOY SLV,ID=2.375' i 3-1/2 LTA 9.311,L-80 STL,.0087 bpf,D=2.992' H 8832' ; 8832' f--I3-112"X 3-3/16'X0,D=2.786" 4-1/2'WHPSTOCK(TAGGED 05/22/11) — 8850' ! • 4-1/2'LTR,12.6#,L-80 NSCT,.0152 bpf,D=3.958" -4859 4 MLL OUT WNDOW(15 48C) 8852'-8859 i PERFORATION SPRY 14Nte,.LNR ,.. 16'X 2-7/8"XO,D=2.377" REF LOG:SLB AHEM GR/CCL/CNL ON 5/31/115 �-2-716'vuFD vuDEPAac PKR ANGLE AT TOP PERF: 92'@ 9540' D=25'ORFRS(11/08/15) Note:Refer b A-oduction DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 2' 6 9540-9570 0 11/07/15 2' 6 9660 9720 O 11/07/159510' —CBP(FLE) 2" 6 9945-9975 0 11/07/15444‘ 2" 6 10220-10270 S 06/01/11 12/27/13 &PUSHH)TO 2' 6 10430-10770 S 06/01/11 12/27/13 3.3116'LM ,62#,L-80 TCBTM 01103/14)2' 6 10810-10900 S 06/01/11 12/27/13 ::.0076 bpf,D=2.80"2" 6 11100-11170 0 06/01/112' 6 11210-11400 0 06/01/11 2" 6 11490-11560 0 06/01/11 1908' N` s! 2' 6 11650-11790 0 06/01/11 2' 6 11850-11900 0 06/01!11 2-7/8"LNR 6.16#,L-80 STL,.0058 bpf,ID=2.441' 11946' DATE REV BY CONSENTS DATE REV BY COMMENTS PRLDHOEBAY UNIT 01/28/96 INITIAL COMPLETION 01/07/14 TTRI PJC MLLJPJSH CBPBTM(01/03/14) WELL 15-48C 02/23/03 JLM/tO( CTD SIDETRACK(15-48A) 11/17/15 TBDIJMD GLV C(O(11/12/15) PERMTNo;"2110300 11/26105 NORNIC 1 CTD SIDETRACK(15-488) 11/17/15 JTMYJMD SET PKWADFEiFS(11/07-08/15) AR No: 50-029-22635.03 06105/11 NORDIC 2 GTO SIDETRACK(15-48C) 06/07/16 JGUJMD GLV CIO(06/05/16) SEC 22,T11N,R14E,1309'RC&259'FIM. 12/07/13 DAX PJC TREE C10!SFTY NOTE(1213/13) 01/07/14 TlWPJC CMT SOZ(12/27/13) - BP Exploration(Alaska) J • • TREE 4-1/16'C1W FIS FETY NOTES: WELL ANGLE>70"ft 9341''"'3-1/2- WELLHEAD= FMC 15-48 Proposed P&A KRONE LNR"" PREVIOUS WE.LBORE'S NOT ACTUATOR= BAKB2 C HOWN"' BPV HGR PRORLE BAD;UNABLE TO SET KB.EiEV= 66.7' TWC 12/3113"' BF.E1EV= KOP= 6548 20"COMUCTOR H ? 2184' --14-1/2"FES HXO SSSV NP,ID=3.813' Max Angle= 94"CO 11777 um OatMD= 929(1 Datum ND= 8800 SS GAS LFT MANDRELS 7 ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40#,L-80,BTC-M D=8.835" H 3461' 1,4 1 3677 3675 1 KGB2 LS DMY INT 0 06/05/16 9-5/8"CSG,47#,L-80,NSCC, ID=8.681" H 3548' n0 2 6288 6284 5 KG82 LS 'DMY NT 0 07/20/()3 3 8237 8059 34 KG82-LS 'DMY NT 0 03/1096 ALL MANDRELS REQUIRE MODIRB3 LATCH 3.70'BOT DE'OY SLV,ID=3.000" 3901' *STA'S#2&#3=r Minimum ID =.25" @ 10152' -10165' ;■: 390T -45 KB LN2TOP PKR,D=2.450' WFD WIDEPACK PKR wIORIFICEBEHIND 6660'-6TH" -iTt161VG HOLE PIPE 7"CSG,26#,L-80 BTC-M.0383 bpf,ID=6.276" H 8139' 171.18306' H7'X 4-1/2"SKR S-3 PKR,D=3.875" F F 8329' H4-1/2"HES XNIP,D=3.813- BEHIND PIPE 8341' -14-1t2'HES OLEG,D=3.9581 4-1/7 TBG,12.6#,L-80 BTM, 8341' 8341' H7 X 4-1/2-TiVY LTPw 17.35" +4 .74: 8341' ID=5.249" .0152 bpf,ID=3.958' ''''.""''1 5352' Hrx4-lrr nuvwtHYDlao 0=3.915" 1tFl/t A IL 7 CSG,29#,L-80 BTC-M.0371 bpf,0=6.184" H 8554' 8773' H 3'SEAL STINGER w t NO-GO,D=2.375" 3-1/2 LN7,9.2#,13CR-80 STL,.0087 bpf,1)=2.992" H 8773' 8778' -13.70-DEPLOY SLV w/45 KB LTP,13=3.00" 8784' H45 KB Lift TOP FCR,ID=2.45' ESTMATE)TOP OF CEMENT -8808 8808' 3'BKR SEAL STINGER&3.70"BTT GEN 2 LNi 0G LOY SLV,ID=2.375' 3-1/2 LNC 9.3#,L-80 STL,.0087 bpf,D=2.992' H 883? 8832' H3-1/2"X 33116'XO,ID=2.786"4-1/2"VNfPSTOCK(TAGGED05/22/11) - 8850' �,ff 4-1/Z' MLLOUT WINDOW(15-48C) 8852'-8859' LNZ 12.6#,L-80 N/SCT,.0152 bpf,D=3.958" H ^8859 4. ORATONSUMMARY ''..: ...-------1 9510' -3-3/16'X2-7/8"XO,D=2.377 Fill LOG:SLB M71A ,�- GR/OCL/CN_ON 5/31/11 �►?--� 10152'-10165'1---2-7/8'VVFD YVDE'ACK PKR I� ANGLE AT TOP PERE 92'@9540' D=25'ORNFICE(11/08115) Note:Refer b Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 9540-9570 0 11/07/15 2" 6 9660-9720 0 11/07/15 2" 8 9945-9975 0 11/07/15 9510' CBP(MLL� 7 6 10220-10270 S 06101/11 12/27/13 r, &F r SI-ETJ TO 2" 6 10430-10770 S 06/01/11 12/27/13 13-3/16'LPR,6.2#,L-80 TC11, - 951 '' BTM 01/03/14) 2" 6 10810-10900 S 06/01/11 12/27/13 1.0076 bpf,ID=2.80' 2' 6 11100-11170 0 06/01/11 7 6 11210-11400 0 06/01/11 2' 6 11490-11560 0 06/01/11 PBTD 11908' 2' 611650-11790 0 06/01/11 2-7/8'LW,6.16#,L-80 STL,.0058 bpf,13=2.441' H 11946' 6 2" 6 11850-11900 0 06/01/11 DATE REV BY OOMVENTS DATE REV BY COMVE31TS PRL.DHOE BAY UNIT 01/28196 INTLAL COMPLETION '01/07/14 TTR/PJC MLUPUSH CBPBTM(01/03/14) WELL 15-48C 02/23/03 JLM/KK CTD SIDETRACK(15-48A) '11/17/15 TBDYJMDGLV Ci0(11/12/15) PERMTND:`2110300 11/26105 NORDIC 1 CTD SIDETRACK(15-488) 11/17/15 JTMJMD SET PKF#ACFERFS(11/07-08/15) AR Pb: 50-029-22635-03 08/05/11 NORDIC 2 CTPD SIDETRACK(15-48C) 06/07/16 JGUJMD GLV C/O(06/05/16) SEC 22,T11N,R14E,1309'FN.&259'PM. 12/07/13 DU/PJC TREE C/O/SFIY NOTE(12/3/13) 01/07/14 TTR/PJC OAT SQZ(12/27/13) - BP Exploration(Alaska) 4 • . • Well:15-48 4,C • --• -- -- * 200 TIO Plot 3,5— ' 3,000 150 2,500 Tbg `" Bleed 2,000 �II� 1 4 aI IA + Operable 1,500 — OA Not Oper 1. 1� I I 50 ' OOA ♦ Under Eval 500 � �`�� 11kmatiom 000A Temperature 041113 04111/15 04110/17 On Cement Design and Volumes Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc(20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Cement Volumes Volume IA cement volume 8306' MD to 4120' MD 78 bbls 3.5"x 4.5" annulus volume 6660' MD to 3920' MD 6 bbls 1 bbl of cement to lay on top of retainer 1 bbls Total Cement to Pump 85 bbls Cement Thickening Time (mix on the fly) Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 1 Safety 1 Minimum Required Thickening Time 5 Cement Ramp for Blend Time _ Temp Pressure 0:00 170 0 1:00 _ 150 1850 2:00 150 2900 3:00 150 1600 4:00 140 1600 15:00 130 1600 5 • • Slickline/Fullbore I 1. Spear-in w/ 5bbls MEOH and load tubing with 100 bbls of seawater or 1% KCL and 40 bbls of FP. IV!ax pressure 3000 psi. 2. Set 4-1/2" Standing Valve in deployment sleeve @ 3901' MD 3. MITT to 2500 psi. LLR if fails MIT-T. E Line 1. RCT cut 3-1/2" tubing @ 3917' MD (16' below top of 3-1/2" liner - reference attached liner tally dated 6/2/2011) Coil Tubing 1. Pull 3-1/2" liner packer (fish should be 16' in total length). 2. Pull WFT Widepack Packer @ 9510' MD. E Line & Fullbore 1. Spear-in w/ 5bbls MEOH and load tubing with 100 bbls of seawater or 1% KCL and 40 bbls of FP. Max pressure 3000 psi. 2. E-Line set CBP at the production packer depth to allow perforating of the 3.5" liner and 4.5" tubing ( ee Fig 1 in Appendix. Tubing caliper as seen below shows only 4% penetration in a 26 foot section of tub ng below the packer). Approximate depth to set is 8300' MD. 3. Perform MIT-T/LLR to 2500 psi to confirm CBP is holding. Due to the tubing leaks @ -6660' MD, he MITT is expected to fail with a LLR of-0.2 bpm @ 2500 psi 4. Perform CMIT-TxIA/LLR to 2500 psi. This test is expected to fail with a LLR of -0.4 bpm @ 2200 si. Confirmation of a consistent difference between the LLR of the tbg vs. TxIA should give us confidence t at the CBP is holding. 5. Perforate through 3.5" liner and 4.5" tubing above production packer at 8250' MD. 6. Pump down tubing taking returns from IA w/ diesel. Swap entire TxIA over to diesel by pumping 260 bbls diesel. Max Tubing pressure 3000 psi. Coil Tubing 1. MU WFT One-Trip cement retainer. 2. Tag top of CBP and PU -80'. Set retainer. 3. Pump down CT taking returns from the IA: ➢ 50 bbls of heated diesel (160 F) down CT taking returns from the IA (this will FP the IA after the cement job in case the diesel has swapped out with cretaceous water from the PC leak at -5300' MD) ➢ 2 bbl FW spacer ➢ 85 bbls cement per design • Unsting from retainer and lay last bbl on top of retainer. Shut in IA for remainder of the job. ➢ CT volume FW 4. POOH pumping CT displacement (hold CT x TBG backside pressure constant as per above note) and wait until cement sample at surface reaches 500 psi compressive strength. 5. MU Motor and 2.80" Mill. 6. Mill through Cement, Retainer, and CBP. Push remnants to Seal stinger @ 8773' MD & POOH. 7. MU 2-1/8" Mill and mill/push remnants of Retainer/CBP past bottom perfs @ 11,900' MD. 8. MU WFT Widepack Packer w/ 0.25" orifice and set -10,150' MD. Slick Line/Fullbore 1. Load tubing with 100 bbls of seawater or 1% KCL and 40 bbls of FP. Max pressure 3000 psi. 6 • • 2. Set 3-1/2" Evotrieve plug @ -8650' MD. 3. CMIT TxIA to 2500 psi. MITT to 2500 psi. 4. Run SCMT log from 8300' MD to - 3000' MD to find TOC. 5. Pull Retrievable plug. Integrity Engineer 1. Add Biennial CMIT TxIA and MITT to Anncomm. 7 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMIIN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well Q • Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Sus Well 0 PAlter Casing 0 Other Cement IA Q • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 3, Address: Exploratory ❑ Development Q-5. Permit to Drill Number: 211-030 P.O.Box 196612 Anchorage,AK 99519-6612 Stratigraphic ❑ 6. API Number: 50-029-22635-03-00 7. If perforating: Service 0 What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No Q PBU 15-48C Y- ... 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028306- PRUDHOE BAY,PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(it): Effective Depth MD: Effective Depth TVD: MPSP (psi): 11953 - 8956 8959 Plugs(MD): Junk(MD): 11911 Casing Length Size MD �` 9510 Structural TVD J Burst Collapse Conductor 78 20"91.5#H-40 36-114 61/k14 1490 470 Surface 3514 9-5/8"40#L-80 34-3548 4-3545 5750 Intermediate See Attachment See Attachment 3090 See Attachment ee Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): See Attachment P Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment gj�) 4-1/2" L-80 Packers and SSSV Type: See Attachment 29-8341 Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Scheme ^�►/ ti 13.Well Class after proposed work: Detailed Operations Program Q BO' �, 0 Exploratory 0 Stratigraphic 0 Development Q - Service 0 14.Estimated Date for Commencing Operations: F�1• .k81- 15. Well Status after proposed work: V Oil Q - WINJ 0 WDSPL 0 16.Verbal Approval: Suspended 0 Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure ap. o -d herein will not Contact Munk,Corey be deviated from without prior written approval. Email Corey.Munk@bp.com Printed Name Munk,Corey Title GWO Engineer // Signature � ,/ �, Phone +1 9075644162 � /� iirlc`/ /isr�,L Date/'6' ,j a'jo .4.- /1 r � / /6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: L V2 Plug Integrity ❑ BOP est 0 Mechanical Integrity Test 0 ;\`,Q^ `b V L 9 YLocation Clearance ❑ Other: Post Initial Injection MIT Req'd?' Yes 0 No Ci VANED MAR 2 0 20�13 / Spacing Exception Required? Yes 0 No El Subsequent Form Required: `0 4-0 J Approved by: APPROVED BYTHE COMMISSIONER COMMISSION Date: ORIGINAL /,,, 8 Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval./° Submit Form and W/ Attachments in Duplicate • • . • Well: 15-48C 15-48C Fullbore IA Cement Squeeze Job API #: 50-029-22635-03 Intervention Engineer Corey Munk (907) 654-4970 /Aras Worthington (907) 564-4102 Production Engineer Paulina Meixueiro (907) 546-5971 History 15-48C was drilled in 6/11 and completed with 1,010' of perforations in Z1A/B (60' in Z1 B). The well has a 5000' liner top extension 'patch' (over 2 known tubing holes). A 12/13 GSO squeeze was performed which reduced gas rates from — 28 mmscfd to 11 mmscfd. Gas rates gradually increased up to reaching 20 mmscfd. In 11/15 a packer with orifice was set to limit the gas coming from below 9510' MD and 120' of Z1A perforations were added. This resulted in a fulltime well averaging —150 IOR. The well broke MOASP on 5/27/16 and failed a TIFL two days later. After slickline dummied the GLV off, and MIT-IA failed. An LDL performed on 6/13/16 indicated a production casing leak at 5273' MD. An IA cement squeeze is proposed to cover the PC leak at 5273' MD. The proposed plan is to bring Top of Cement (TOC) to 4000' MD in the IA or a minimum of 500' MD above the Ugnu (Cretaceous) reservoir • which is located between 4500' MD and 5500' MD in the DS 15 Area. Job Economics There are 140,000 bbls of oil estimated to be recovered. This integrity repair is proposed to maintain integrity/operability of the well long term. The estimated 12 Month IOR delivery for this well 60 BOPD. Objective The objectives of this job are to repair to PC leak by bringing TOC to 4000' MD while still retaining the ability to use STA#1 GLM to kick-off the well. Post-Job Evaluation This well is a producer so an AA will not be applied for, however the following BP internal criteria will evaluate the integrity of this non-rig workover: • MITIA and MITT • SCMT to locate TOC Long-Term Integrity Monitoring • Record WHPs daily. • 4-year cycle for MITIAs and MITTs Current Wellbore: . III 1110 • 1N11- 4 1116"OW 115 V1 SAFETY NOTE: WELL ANGLE •70'gp 9341''"'"3-112"1311-1640= FAC 15-48C CHROME LNR- PREV 10141NELL BORES NOT ACTLKTOR= BAKER C SHOWN"" FOY MGR PROFILE SAO;UNABLE TO SET KB ELEV= 667' i TING 1213;13- Se 11772 BF ELEV= 7 II KOP-. Emir 1 , , 20 COMJLICIOR 1 I ? 1) I 47: 2184' IH 4-1/7 HES MO 5SSV flP.83=3.613" 1 Mx Angle- 6 1 I I 1 Datum ID= OM Datum 7Vd= 8800 SS •••-0 GAS LFT MA1CFELS ST OA) ND DEV Tr FE VLV LATCH PORT DATE 9-518MG.408 I-80,STC Al,83-,8835" H 3461' e; 1 3577,3375 1 KGB2 IS 0M NT 0 06/05/16 1 9-5,13'CSG.47#,L-eo,HSCC, 13=8.4'11" H 354W i•e I 2 628316284 5 KGB2 LS tNV NT 0 07/20/03 i 3 823/18059 34 M3137451 Tr* NI 0 03110/96 ALL MAPEIRELS PECIIRE A MOORED LATCH 1370 BOT OEFOY SLV,ID=3 000' - Y------Bov 1 •STA'S IR&JO= ' Minimum ID =25"ig 10162'-10165' 31—ilF7-145 KB L.Ffit TOF'PKR,1.)=2.450" • WFD W -. IDEPACK PKR w/ORIFICE - e 6660- 11713 TUBINGI-CLE BEHIND PIPE r CSG 261,180 BTC 1.1,..0383 bp1,13..-8278' i 8130*-1-->c x , -i &SW H' X4-ur EiKR S-31403,13=3.a/5- j I -i 8329' I .4-1/2"HES X NV,ID=lair I BEHIND PIPE 4-117 TBG,12.611,L-80 BTU, 1 4 8341'- -14-1/2'VES WLEG,ID-3_osrl 8941' -4.- 8341' 1-7"X 4-1/2"TW LIP*/7 35'TBR ID-5.24 - 0' -----‘-I 8352' H7"X 4-VT TW LPN FR DR)HGR 0-3915' 0152 bpf,ID 3 958" I 7"CSG,299,L-80 BTC-11,.0371 bpf,0=6_184" 1- 8554' A k ............„.....„.. 8773' 1---3'SFA1 STICFH•1 NO-GO,ID-2 375 1 154--17-21trt,I.-2//,1-3-CR-10 STL,70-0-871;PI,0-2ä9:2' 1-1--0773' I 8T7W I-13.7ff DEPLOY SLV w/45 KB L7P 13=3.00' I 8784" -145 KB lAR TOPFKR,D-2.4r ES TPA%TED TOP OF CEOENT -1 -88088606' 113'BKR SEAL ST1ICER&3 713,'B-n-GEN 2 . LNR DER_OY SLv,ID-2.375• 3-112 I,NR 9 ift,k-80 ST1. 00E7 bpi,13=2 9Et7 F 8832' * ' I 8832' IH 3-1P2"X 3-3/ir X0,0-2.7136' 14-1/2'IM-WSTOCK(TAGGED 06M/11) 1-1 8850' ik • 8857 14-1/2'LM. ES t, 12 L-80 MCI, 0152 bf.0,U=3.9,8. H ia_Loul WIVOW(15-48C) 8852'- -8859 ,,,,..... PERIM.14 TON SILO/ARV ,,,,..4,,, ----- 9510' H 3-3/16"X 2-7/r X0,D-2.377* I •"'•• REF LOG St.8 NEM GR i ca_i cm_ON 5131/11 -....- • ---------1 10157-101115'H2-7,8"VFE1V•CiEpAIX FKR ANGLE AT TOP R3;F 9r(§)9540' .. \ ID-25'ORIFICE(11/06/15) Mb/ Rorer lo Producton DB for hisbrical parr data SIZE $8' P4TUWAL °WSW SI-OT $07 954 7 6 0-9570 ' 0 11007/15 . . 2* 6 Beao 9720 0 11147115 , 11111111111'N. 9510' CBPAL (PLED 7 6 91945-9975 0 11/07115 2' 6 10220-10270 S 06/01)11 12/27/13 11 14., &REI 03 TO 2' 414/6 10430-10770 S 06,01111 12/27/13 3-3/16'LAIR 628..L-80 TC11, - 9510' Emi 01M3/14) 2' 6 10810 1(900 S 06/01/11 1201113 0076 bpt,E)=2.97 2' 6 11100-11170 0 06/01/11 -1111 2' 6 11710-11400 0 06,131111 2' 6 11490 11560 0 06431/1 1 PBTD 11908' -. 2' 6 11650-11790 0 09101/11 12-715"UN,0 1610.IAIO SJL,.0058 bpi,ID-2.441" 1 I 11946' i 2' 6 11a50-,-moo o croiii 1 - . DATE REV BY ' DOWSES CATE REV BY r comwimrs FRUC4-0E BAY UNIT 01128/8 INITIAL COMPLETION 0107/14 TTRi PJC 1,1A1 l/1011311 CP 81%1(01/03114) AEI l 15-48C 0223403 .JLM/00('C TD SIDETRACK(15-48A1 11/17/15.TBDAVIDIGLV 00(11112/15) pERm-rm, ' -i low, 11/26/05 NOREIC 1 CTDSICETRACK(15-488) 11/17/15 ,113AJMOISEI R0R/ACIFERFS(11/07-08/15) AR No. 50-029-22635-03 66106111 Nam 2 CTD SIDETRACK(15-480) 0&07/16 JGL/JP,AD tGLV 00(06105/113) 1 SEC 22,11-11R R14E, 1309 FM &259:FY& 1 I 12/07013 DU RIC WEE 000SFTY MOTE(12)3/13) 01/0//14 11I-EPC 101,41 SW I 1217//13I 1 BP Expioration(Alas bap Proposed IA Squeeze: 2 0 e • IRE- 4 1/16"CTAf FLS SAFETY NOTE WELL ANGLE P.TO'et 994V•"'3-112- WELLJ1EAD= FlatC 1 5-48 C Cf110118ELNR*** PREVIOUS wa.LeoRes NOT AC1LIATOR.= BAKER C SHOWN"" BPV 1404i PROFIL E RAO;UNABLE TO SET KB.ELEV= 66 7 TM 1203/13*** BF IL&= 7- I nglia 94.©1 KOP= 61548' 120"coNoutiail 9 VI 2184' -14-1/2-MS1140 qNSV141P,ILI=-3T313-71 Mix A - 1772 stun 0413= 9290 Datum 1t10= 8800'SS GAS LIT MANGOES ,.--- I 9-5/8-MG 406.1-80,urom in-8 we hi 3461* I I STI MD 1VD DEV TYPE VLV LATCH PDRT DATE i 1 367713675 1 KG82-LS MAY PIT 0 (161135116 LB' !G,4744.L-90,MCC, ID=8.6811".1-1 354W }---- 2 6288 6264 5 }(0B2 IS i 'TM INT 0 07/200031 -IOC 4 4000IID---:___ ' 3 I,tt731 8059 34 KOI324511.8AY rat 0 03/101961 , ALL MANDRELS REDA-IRE A MODIFIED LATCH 13 nr BOT CEPOY SLY,ID=3 000" f-[ 3901' I'"i •STAS 42&AM,..-- i Minimum ID =26"@ 10152'-10165'1PC Leak @ ,:, -1: 3907' -45 KB 1614 TOP PKFL 0=2.450- WFD WIDEPACK PKR w/ORIFICE 1527T MD • .-,---:- [6666W-67'99' -TUBING HOLE BEHIND FOUND BY LDL 5/1712001 PIPE r CSG.260,L.80 BTCM,.0383 bpf,ID-6.273r 1 1 8139` 0306 1-I I*X 4-1/2.'SKR S-3 PKR 0=3 8/5 I -4 6329' 1 14-V2'HES X NV,ID=3.8i 3" BEHIND PIPE 8341' _1-4-1/7 I-ES ALEC,D-1958"I 4-112"no.12.66,L-80 151141 8341' ...48 per,4 -I 8341' 1--17"X 4-1,2'TM°LTP awl 7.35'1BR,ID-5249' .0152 bpf,IQ-3 968' 8352' h 7"X 4-112'TVA'1).11111 COO I43R,U-3.915' I 7"CSC,296,L-80 SIC M.0371 bpt,ID=6.184" - 6564" 8773' 1-3'SEM STWGFP yr 1 IV-00.671-7 375- 1 --iii Lift 0:94i,13t00 vrt„.0087 bp' ID 2,aor --1. 8773" env' J-13_70"DEPLOY SLV w/45 KB LIP 13=MD" ES D - II 8784' I-45 KB LN TOPPXR,ID-2.46' TMTB TOP OF CEMENT - 8808 / 8808" -3"&KR SEAL STINGER&3.70"BIT GEN 2 Lill DEPLOY SLV,113 7-2.375' a ; 3-10 a MR,93*,1-80 SR. 0087 bpT,r),-7997 H 8837 *4 * tl 0' i 8832' -3-112"X 3-3N6'X0,D-2,786" II . 4-1/2'W4'ST00((TAGGED 0922/11) H 8850' • a *, * 141,1.1311.11 mum(15-43C) 885,7'-5830'4-UT UV, 12.0P 1-80 Also',.0152 bpt,10=3.9tir H -8859 , 4 •0.4, PATE*i 91.110A RV .. -iv. ---- 9510' -3-3/116"X 2-718"X0,ID-2.377' __ LOG SLB Nek4OIR/CCL Of&ON 5,31/11 * --...-- * -----E 10152'-10165'1-2-716'INFOWDEPA(X WR AP/CLEAT TOP FERE. 92"I§9510 U-"25'ORE10E(11/08/15) No*.Rolm tia Production DB for historical ixtrf data SIZE SFr NTERVAL Otm1Sw SHOT 501 T 6 9540-9570 0 11437/15 4 2' T 6 9660 9720 0 11/07115 41.1.11.11111P 44% 1 9510' CBP(MILLED 6 9445-9975 0 11,137/15 2' 6 10220-10270 S 126/01.111 12/27/13 N: la RIO 433 TO 2' 6 10430-10770 5 0&01111 12/27113 3,3116"LNR H,6.24,L-80 1011, 1510' I BTM 011193/14) 2' 6 10810 10000 S 06/01111 1217/113 0076 bpi,ID=2.80* i 2' 6 11100-11170 0 00301111 III 2' 6 11710-11400 0 06101111 2" 6 11490 11560 0 06411111 FWID I-- 1190W 2' 6 11650-11790 0 001/11 *Se. 1. 1.2.7kr L_NR.,43160,L.eo W1_0058 bpi,ID=2.441 1 1,--7--119---46" 2' 1 6 11850-11900 0 06111/11 — DATE REV BY T COMENTS DATE I FEV BY CON&ENTS PRUDHOE BAY UNIT 01142M8. .MIMI CORI PLETIOSi 01/07/14 4,TTRY SE hi 1) 131I COP EOM(11/03/14) . 1A44 t 15-4EIC 82123003 J1114/14K',Cm SIDETRACKosAsAl 11/17115'TOCLAI) GLV 00(11/12115) 1 PERIUIT Ns *Alamo 11/2005 ?CREW I CTD SIDETRACK(15-48E) 11/17/15•„ITINJAA)I SET IVRACFERPS(11/07-08/15) AIR No: 50-029-22635-03 i 06191411 NORDIC 2 CTDSIDETRACKI15-44C) 08/07/16 JGUJM),GLV 00(0645/10) SEC 22,Ti IN,R14E,1309 Ft/&259'PAL 12107113 Dlif RIC TREE 001 SFTI"NOTE(12)3/13) t 01i0/714 I IHYRIC Che Sal 1120/M31 t i BP Exploration;Alas Xs, Proposed P&A Plan: 3 S III TREE-., 4 1/16"OW IRS SAFETY NOTES: INNL ANGLE79.,.;;9341'""`3-1/2- 1AELLHEAD= FAC 1 5-48 C CHROME L NW"' PREVIOLS WELLSORES NOT AC11.1ATOR= BAKER C SHOWN 8I'v NOR PROFILE 6440;UNABLE TO SET KB ELEV= 55 7 TWC 1213/13-F ELEV= 7 123'CONDUCICA2 H ? 0 2164' I-14-117 HES.HX0 R.NSV HP,ID=lair Mu Angle- 94' I+ 11772 LW=ND= 9290 Datum ND= 8800'SS GAS LIFT OANICEEIS L9-5/8•mei' 409 I.-80.E1TG fit 63-8 835" j-I 3461' ST M) TVD OEV lY FE VLV LATCH FORT DATE _ k 1 3877 3675 1 1(082-LS LAW INT 0 06/05116 9-5/8'CSC,47# L-80,NSCC, Et=8 88t-l— 3548*. ,j--"Al 2 6288;6284 5 Kg:632-LS TO& NT 0 07120003 3 67316059 34 KGB2-151 "CFAY NI 0 03/10/96 pl„ ALL MANORS...5 REQUIRE A MOCIFIED LATCH 13 70-BOT DEPOY SLY,ID---r-i-Ei---10IY ---1 3901" %.,, STA'S 42&83=' ., At:. :.,:::, .• ;,;,, Minimum ID=26"02 10162 -101651 3907" --145 ALI LAIN 101. 9.)PAR =2 4.50- .: .• a w WFD WIDEPACK PKR wfORIFICE I :_:. astir-6796" BEHIND PIPE A ..,12•41:, 1 r CSG,2801,L 80 131C-1.4,.0383 bp1,13-6 27/7 I 1 8139' --4 ..... 8306' ‘I--ir X 4-1F2-LIKHZ b-3 WY.U=3 8 I'"r —H 8329' H4-12'MB X N/P.ID=311131 BEHIND PIPE 8341 H 4-112"H33 WLIV,ID=&mai 4-1/2*TDB,12.66,L-40 BTM1 8341° ....-.4 , tr- ---1 8341' Hr X4-1/2'11A.L1Pyr/7.35"TBR V=5249' .0152 hotID , .3.956" ------=-1 6352. HT'X 4-1/2'TNV LNRHY ORO 143R U"3915 1 r cso,294,L-80 BTC-M.0371 NIL ID=6.184" I- 8554* A lik 6773' F-3'SEAL STINUM al/40-00.ID*2375" 1 13-112 LNR 9.21/0,130R44 STL,70037 bpi,V-,2.992" H 3773" I ,,• 8770' F13.77 DEPLOY SLV a/45 KB LTP,()=300 1 [ 8784" H45 KB LIR TOPFKR,ID 2.45* 1 ' ig0 [ESTIMATED TOP OF CEMENT H -8806 • li 8808' I---3'SKR SEAL STPEER&3117 BIT 6042 0 LARDER-0Y 51V,D-1375' 1. $ 13-1011P,9 3#,,L-80 S11,..„ 0067 bpi,ID=2 992- H 8837 K • 1 ., i" --i 1 8837 1--13-112"X 3-yiexa,ic-2.786" , III 14-1/2"WHIPSTOCK(TAGGED 05022111) H 8850' 14.112'LNIR 12 88 L-80 Nt5CF, 0152 byt.,17=3.958" H -8859 °1 ''s MLL(X.0 WM:M(1548C) 88.52*-8856, 40' - v "•-.., PERFORATION SEANIAARY -- -----1 9510' H3-3/16"X 2-7/8"XO,ID==2.37T 1 ,... ..-..,... REF LOG &it 1434 GR./CCL/CH_ON 5/31/11 -- •Ce------I 10152' -10165"j-2-7ar WFD WEEPACK R(R ANGLEAT TOP FERE 92'(4 9540 V=25'ORME Ill/08115) Nolo Rohm to Pnaducbon DOfor historiciA porf data ,. , ,...., SIZE SPT NTEBVAL On/5u z StUT SQZ \ 2' 6 9540-9579 0 11,07/15 2' 6 9660 9720 0 11437/15 --„ 9510 -08P(MLLED , - ' 2' 6 9945-clan 0 11,07115 \ '',..„ , .. &P0SIED TO 2' 5 10220-10270 S 06101111 12127113 N.„ H 2' 6 10430-10770 S 06/01111 17/77113 3-3116"LNR,626,LAO TC11, 9510' '', 0 '-‘--,, . 81140t03/14) 2* 6 10810 10900 S C6,01/11 17/71113 0076 bp,.ID=zbo• N., N 2' 6 11100-11170 0 08101111 "N -- 2' 6 11210-11400 0 06411111 2' 6 11490 11560 0 C6931111 FIBTD 11906' ---- 2' 6 11650-11790 0 06$01,11 •11114 12-716-1_NR,a.iea,L-eo STL, aoaa bpi.ID=2.441" I 1 11946- 2' 6 11850-11900 0 08101111 DATE REV BY 1 COMIENTS CATE ' REV BY F CONNENTS FRU)-OE BAY ti-IT 010:11/94 itiTIAL COM PLETIC*I 01107114,TTFiti PS:1 MAI I flotilti CJIF BIM{01/03(14) i VW L t)-48C 02123)03 .11161/10(',C TD SIDETRACK i16-411A) ' 11/171151 TBDJAID LV 00(11)12)15) 1 PEPlar No " i 10300 11/26/06 t406D-C 1i CTDSIDETRACK115-49131 11/17/15 ,ITRIJM3 SET PKPIACFERFS(11)07-08/15) AR Na: 50-029-22635-03 46405111 NOFDC CTD SIDETRACK(15-43C) 06107/15 JOURCIGLV 01)(06/05116) SEC 22,T'114 R14E,1309 FM_&259 Reit 12/07/13 Dtlf PJC TF 01)1 00/SFTY NOTE(12/3113) 1 01101,14 ITR/PLIC ICAO SW f.17r?n13) I Exploration(Alaska; 4 • • 15-48 T 10 Plot • • Inig - 117 --M--LA —A--OA 00 000A C€1&16 T1 Ite013- 717 ror ."! 5 Cement Design and Volume • Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +1- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours Location Volume IA cement volume 8289' MD to 4000' MD 74.96 bbls 3.5"x 4.5"annulus volume 8289' MD to 6660' MD 5.41 bbls Total Cement to Pump 80.37 bbls Cement Thickening Time (mix on the fly) Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 1 Minimum Required Thickening Time 4 Cement Ramp for Blend Time Temp Pressure 0:00 170 0 1:00 150 1850 2:00 130 2900 3:00 150 200 4:00 170 200 15:00 170 200 6 • • • E Line & Fullbore 1. Rig up Eline and Fullbore to assist 2. Load and Kill well as per attached pump template. 3. E Line set CBP below packer to allow perforating of the 3.5" liner and 4.5" tubing (See Fig 1 in Appendix. Tubing caliper as seen below shows only 4% penetration in a 26 foot section of tubing below the packer). 4. Perform MIT-T to 2500 psi to confirm CBP is holding. 5. Perform CMIT-TxIA to 2500 psi to confirm LLR is .4 BPM at 2200 psi 6. If MIT-T fails consider troubleshooting CBP (CMIT-TxIA is expected to fail on IA due to known PC leak) If a passing MIT-T can't be performed RDMO. 7. If MIT-T passes and CMIT-TxIA has been completed proceed to next step. 8. Perforate through 3.5" liner and 4.5" tubing above production packer at 8306'MD. E Line can RDMO while Halliburton rigs up to pump cement. 9. Circulate an IA volume of 160°F Disel down the tubing through the liner and tubing punches to clean any fill that may be present as per attached pump template. 10. Pump Cement down tubing and take returns up the IA. 11. Drop foam wiper ball at tail of cement volume to clean tubing walls, displace behind foam ball till cement volume is spotted in the IA. 12. Hold pressure on tubing to keep cement from U tubing till it has reached its cure time. 13. Perform MIT-IA per attached FB template. 14. RDMO Coil Tubing 1. MU 2.75" OD Left Hand Junk Mill. RIH and tag TOC (expected TOC at 8290' MD). 2. Mill through cement and the CBP. 3. Mill CBP and attempt to recover CBP with burn over shoe. Slick Line f 1. Run SCMT log from tubing tail to surface to find TOC and relative bond. Integrity Engineer r:u . 1. Add Quadrennial (every four years) MITTs and MITIAs to Anncomm. Appendix Figure 1 . Depth: 8306.00 to 8326.00 Length: 20.00 Deviation: 37 Rotation: 312 Avg. Diameter: 3.00 Min. Diameter: 2.99 Max Pen.: 4% 832283244326 8320 driwrr+'I 8318 rNrarrrtliur 8316 !WI 8311 8312 i. I 831011 ` 1 ' 1I , 8308 , i l 8306 8 • • d 0.c) 000200-901C1 0 0 0 N O O O 0) O O Lf) CO LCA 00 co O d O M c co M co U 0 0 0 0 0 0 0 0 0 0 0 L CT) LC) V CO CO CO In to c,) m O co M O co M co Ln CO cr CO LC) CO O CT) CO I- N c- N- LC) cr O N- LC) Nzt Ln CA M CC) LC) LC) CO CA CO O CD CA M I� co co Cb co co co co co co co CO H co CA CO V O 00 n t` O N- (O N N- V LC) C)) V O N- o) CO CO CO C) CO LC) LC) LI) LC) CO CA CA N N- CO 00 CO CIO CO CO 00 00 CO G) 00 CAv C) (NI M N N (NI O N- M LC) LO r CO y- O V LO LC) CO CO CO Ln Cr) CO LD DI CO CO CO CO CO CO CO CO CA CO O CO V — Q CO C) N- CO O N O N O O CO V N CO O 'Cr CO C)) r Cs) L co co co C) co N- CO 00 CO CT) CO Ll) N COILO M CO CO M CO CO CID C)) O) r co O CD C>o O O O O a00 O 00 M Ccp b \ 1- CO L CIO 00 CK) cc CID i J 00 00 co 'J J J J J J J J = tV 44 J J N �# N N N CCD SO N N *k4,kN N M Cfl CO CO O O • 0) - (O CO fA 0, aO N C (� - M - CID _ - - - U - Imo - NN N 0\00\DN N CA M `— M C) V N t N N 0 CID O LC) C` 00 1--- M to co J Moos— V Ln M N CO — V M N N co W fx F— C)O — — c H W 0 0 •- oOWw La � Q22 U w ct c c z zwWWwwwWWWWwm O D H H z z z z z z z z z D J J J J J J J J J I- • a) u, LC) Ln O M O) V" CO M t CO CO M Ln • O) Cb Ln M M M M o M O m O O O .- N LC) I- CO N- CO LC) p 0) O) O) 0) O) O) O) O) O) O) O) CO CO CO CO CO CO CO CO CO CO CO I- a O I- r CO CO CO V' I- Ln o CO CIO N N CO CA CIO CO V O) Ln o CO r cNi O O .- N N CO N- CO N- CD UW 0 0 O) CA CA CA 6) O) O) CA O) O) CA > 0 o 0 0 0 0 0 0 0 0 0 0 o 0 � o 0 0 w O w a CL ggY 00 > 0 m 0 0 0 Ln O O w U u ~ c �+ d I_ O N O O O O O O O) O J J J a s (W Z cc 0 O O O O U U _0 J W W O J J J 0 aa, Q Q < = 0 0 0 W 2 2 2 2 0 U U U U W L w W W a Z O z V 2 2 2 O t) ) u) cn COCO < LO C r w 0001nooOO000C O -nd , om , Nv = o , mLnLn Ln CO O O O O O N V M o +� MM Wo CA (T O O cc c_o 000) 2 2 2 0 c) a) va) a 0)) C CL a, 0 0 LL_ LL L. L_ U) (I) (I) (1) U) (1) U) U) is dCLa. dYYYYYYYY a < < < < U U U U U U U U 0 t a, a a, F- oa n Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln 0 0 c o 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 Z w Q w I,- CO CO CO CO CO CO CO CO CO CO O LLl 0 W N w (] = = = = = = c- '- '- c- < 0 J H J J J D w W m 0 D w J J Q 0 W w < < d co LL LL w (n CL CC a) E 2000000000000 cooc000cococ00000 N CL (n O w N a' LL. LO Ln Ln Ln Ln L[) LO Ln Ln LO LO Ln CO d CL CL U 'J 0 O W Cl Q Q m LT) w W N Ln 0_ C_ • • 0 Packers and SSV's Attachment PBU15-48C SW Name Type MD TVD Depscription 15-48C PACKER 3906.97 3904.45 3-1/2" Baker 45 KB Packer 15-48C TBG PACKER 8305.86 8116.97 4-1/2" Baker S-3 Perm Packer 15-48C PACKER 8348.03 8152.06 4-1/2"TIW Packer 15-48C PACKER 8784.12 8518.3 3-1/2" Baker 45 KB Packer 15-48C PACKER 8884.73 8601.53 3-1/2" Baker S Hydroset Packer 15-48C PACKER 10152 8922.37 2-7/8"WFD Widepack Packer • • Carlisle, Samantha J (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, March 08, 2018 2:11 PM To: Carlisle, Samantha J (DOA) Subject: FW: Please withdraw 3 sundries Sam, Please handle. I have placed these 3 unapproved sundries in your confidential box. Thanx, Victoria From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Thursday, March 08, 2018 1:32 PM To: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Cc: Worthington, Aras J <Aras.Worthington@bp.com> Subject: Please withdraw 3 sundries Victoria, Please withdraw the following unapproved IA Squeeze sundries: G-11B (PTD#208-027) 15-48C(PTD#211-030) Y-24(PTD#186-113) If you have any questions or need additional information please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 Subsurface&Wells 1 � rtC! iic Air^I=temo BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK 1 TRANSMITTAL 2.� 3s 9 WELL LOG PROACTIVE DIACINOSTIC SERVICES, INC. r DATA LOGGED I :A VI J .m M.. A'B✓NDE K.BENDER JUL, 0 6 2016 To: AOGCC Makana Bender AG ;C 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdcObp.com SCANNED rv0 . 8 201E and ProActive Diagnostic Services, Inc. Attn: Diane F.Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 13-Jun-16 15-48C BL/CD 50-029-23265-00 2) / Signed : P ✓st, �°r'froO Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(p.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP Transmit.docx • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday,June 17, 2016 2:18 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Meixueiro, Paulina; Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey,Adrienne; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington,Aras J Subject: NOT OPERABLE: Producer 15-48C (PTD#2110300) Production Casing Leak All, Producer 15-48C(PTD#2110300)was reported to have sustained inner annulus casing pressure over MOASP on 05/27/16.Subsequent diagnostics culminated with a Leak Detect Log performed on 06/13/16,which indicated a Production Casing Leak at 5273'.The well is reclassified as Not Operable.As repair options are being actively progressed, the well will not be secured at this time. Work Completed: 1. Downhole Diagnostics:TIFL—FAILED 05/29/16 2. Slickline: Set DGLV—DONE 06/05/16 3. Fullbore Pumping: MIT-IA—FAILED 06/05/16 4. E-Line: Leak Detect Log—DONE 06/13/16; Production Casing Leak at 5273' Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296AN( 4 { _Y H:2376 Email: AKDCWellIntegrityCoordinator@BP.com rom: AK, D&C Well Integrity Coordinator Se . nday, May 29, 2016 12:54 PM To: AK, OP •SM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Sup- ' ••-nt; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, • -•: East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C We - -•rity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whi • 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Dickerman, Eric; Morrison, Spencer; Igbokwe, Chidiebere Subject: UNDER EVALUATION: Producer 15-48C(PTD #2110300) Inner Anna Repressurization All, 1 STATE OF ALASKA 0LASKA OIL AND GAS CONSERVATION COMM( ' REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Orifice Packer WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 211-030 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22635-03-00 7. Property Designation(Lease Number): ADL 0028306 8. Well Name and Number: PBU 15-48C 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: _ V E D Total Depth: measured 11953 feet Plugs measured feet true vertical 8956 feet Junk measured 9510 feet DEC 10 2015 Effective Depth: measured 11908 feet Packer measured 8306 feet true vertical 8959 feet Packer true vertical 8117.09 feet ADGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 35-114 35-114 1490 470 Surface 3514 9-5/8"40#L-80 34-3548 34-3546 5750 3090 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet { r.5 5 8 „. tU True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-8341 32-8146 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 169 20014 6 820 337 Subsequent to operation: Shut-In 50 905 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283( 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 114CtotetAt6/)..7(---%, Phone +1 907 564 4424 Date 12/9/15 Form 10-404 Revised 5/2015 ITL /2123/t s RBDMS DEC 15 2015 � Submit Original Only / 1 • • m .0 0 0 0 o C) cameo tC) c coo G � ) LON � � � � U N o 0 0 0 0 Lo 0 0 CO �i N CO coo M co (00ovOM r,- CO O M in O) 6Y Cr) OOCO0000COCO 0 1 1 1 1 1 1 1 1 1 H 000O (o0 — LC CO 0) • N CO CO CO a7 CO L() O) CO CO CO CO CO G> Oo O) 0 0 0 LO N- t() f"- CO LO CO CO CO CO CO CO (3) CO V U2 Qrn v o M M C▪O CO M O M N- LO CO') L() 00 CO CO 00 O _• r • co La-rt O00 CO 00 CO L5) JcocoMJJJJ CO CO •N Co N (fl (p CU O) 00N CN 0) - CO - - V o N N 0o M6 O M ti r w Ca �C N. Lo _ co 0 O CO 0 d O CO CO 'Cr ' O N CO Z Z a)O 00 y 0 0 0 0 DD C) 0 u a a C Q a Z Z r O O W W W W 0 p w ctZ Z Z Z_ D U C/) 0 0 J J J J I- • d N • LYJ• Cn CC) V r- O M O � � CO M L O O M LO ' Q CD O O) M M M M CX) O O) y 0 0 0 v— N m CC) I- O I- CO Ln p CA CA CA CA CA O 0) CA 6) CA CA O) CO CX) M CO M CO CO CO a0 M O I- a 0 C)) N Ln CA — — CO — CO t I's I's .c CO CO CO Nr N- LO CO CO CO N N CO a O CO 4 6 6 aO Cfl N d O O '- N N V CO N- CX) N- CO W p C) CA CT 0) O) CA O) CA 0) CA 6) CA > p CO CX) OO OO OD 00 OD CO OD CO CO OD 0 Lu W p O• 0 w Z LU w p W 0 I H JW 5 5 Y 00 > m O O W . J U U . 0 0 0 L 0 0 0 0 0 0 0 0 Q Q w w ++ d I� C)) N I� O O O C)) O J J J CL L1 (n Z tY CA� 0 CD 0 0 0 c- = = = _U U_ U_ J W W W = = . . . . . . Z Z Z O J -1 _, p J m Q Q Q = p a w U U U II W Q py QQ p Z H p W LU LU CL H Q Q C.) 2 2 O (n U) Cn cn (n RI CO •I . �i a QLO O F C L 00 0 Cn 0 0 0 0 0 0 0 0 O mv CO O op N CO O— N �t CO CO m a 0 O) 0) CO CA O O O a- v- r O (A CA L a ai O 2 - c- J00aJa a) 0 0 c O LLLLLLti. 0) CD (I) CnU) (1) (1) CI) m d ELd M Y Y Y Y Y Y Y 41 < < < < 00000000 a 0 t m a I- R to LO Ln CC) LU to CO UD UD tO UD UD 0 v— r . a- r r 0 0 . . . . . 0 0 0 0 0 0 0 0 0 0 0 11.1 w z O N N N N N N N N N N N N Z Q W m CC\ co co 00 0O CO CO CO 00 a d OI w 0 LI a W LL a Q p J I- J J J D CY CL O CO LLJ Q < (wi) LL LL LL cn d m E 2000000000000 OD CO CO CO 00 CX) O CO OD CO O OD � v v v 1 1 1 1 1 1 1 1 1 co n LL M Cn O LL N LL CC) t1) Cf) Ln tf) CC) t1) O lO CC) tf) tC) 030- 0- 0- 0 -100W . • Packers and SSV's Attachment PBU 15-48C SW Name Type MD TVD Depscription 15-48C PACKER 3907 3904.48 3-1/2" Baker 45 KB Packer 15-48C TBG PACKER 8306 8117.09 4-1/2" Baker S-3 Perm Packer 15-48C PACKER 8341 8146.21 4-1/2"TIW Top Packer 15-48C PACKER 8784 8518.2 3-1/2" Baker 45 KB Packer , 0 • �# E § f 0 t o_ E / o » c 0 \ / o \ \ E -o -o / \ G 8 2 2 o m r c 0 £ 5 15 ® ƒ o_ 0 $ R c / 2 + o 2 £ / � � / 2 Ok 6x / A ° _ � 0 0 7 2 I - C Qa) .00 fa. § I II I 0 k / / / / / 0 P. / (/) / PE /O _m / � C\ 2 \ kk C k / / \ / \ a.) 0) to » C . = 2 � Ec eo .g � ° o0 o \ / / 6 di al \ C & � 3 6 E ® � ° o o / \ ƒ ƒ / / 0' » M 0- @ 2 = c = a c m o _ E iN c m > \ ° / e E / m » © / cn ® 0 U / f y E % G o e d \ © 2 - �� 2 t c - ii m � � 000E \bx a__c Edi io = # mo ooh mf = p - o 3 70 2 0 0 CD I b a o R o - E _ = E m % - 0 o m e_ $ - e o m R _ = I / e n .&c) _ / - r ca - co2 2 \ 0 ° 2 c t n L7-; 0 - G 0 / f / 4 / \/ f _ C _ . / - \ / \ f $ _ ii E 'CIL "E _ / ƒ % D 2 CD b a _ ® 2 Ce U) $ \ &- ' \ C \ " / / \ 4 2 m F $ c Cr)2 w -' S o R / o _$ c 2 \ 2 # o = 03 / / k $ & $ � � ƒ $ � \ \20Ca. 112 / / cm « f c - ƒ% 2 / Cl) = \ § 0\ ° - ° : E E 5 = 0 e e \ ± § 0 _ - = 0 k- o ® ® e # SG e O & e2U Oc § / ® © 2 5 � R = ° b c G 8 b f 0 o- 2 a 7 * f a - 3 Q c _1 ) % k _v f _» / E 0_\ ± v D �R c c » , E / U � _ ƒ \ S / 2 � ® � � \ 0)— 3/ \ � p/ 5 ° � r o I I 0 ? -0 # -§ r I = * O _ % o .g / m 5 / - / / / \ m \ / / \ \ § \ / / / / / t f / / - I $ O 2 : 00O CC ± : U U 2 : O m as : 2 U 2 ,- n L H r r r to n \ \ N N d N / f CO \ N- o 2 7 / 9 b CO E ( r ® CO R O < ita_L= 4-1/16'(3W FLS • SAFISVOTES: WELL ANGLE>70°@ 9341'''''3-112" VIAELLHEAD=, ROC 1 5-48C CHROME LNR"'" PREVIOUS WEL L BORES NOT AcTUATOR= BAKER C SHOWN-"" BPV HGR PROFILE BAD;UNABLE TO SET KB.EiEV= 66.T TWC 12/3/13 BF.Ei.EV= ? KOP= 6548; 21M' -14-1/7 NES HX0 SSSV NIP,13=3.813" iAngie= 94.,., 11772,' 20"CONDUCTOR --1 ? ) 0 Dtum IV= 929(i ( tum TVD= 880(Y SS X GAS LFT MANDRELS ST kV TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,40/1,L-80,BTC-M ID=8.835" I- 3461' i 1 3677 3675 1 KGB2-LS DONE NT 16 11/12/15 2 6288 6284 5 KGB2-LS 'DAY NT 0 07/20/03 9-5/8"CSG,47#,L-80,NSCC, ID=8.681" - 3548' LI 3 8237 8059 34 KGB2-LS "DMY NT 0 03/10/96 ALL MANDRELS REQUIRE A MODIFIED LATCH 3.70'BOT DEADY SLV,13=3.000" - 3901' •STA'S#2&#3=PAY GLVS BB-IPI)PIPE Minimum ID = .25" @ 10152' - 10165' g g 390T -145 KB L.1%Ft TOP PKR,13 2.450' WFD WIDEPACK PKR w/ORIFICE [ g 6660" -6795' ---i TUBING HOLE BEHIND PIPE 7"CSG,26#,L-80 BTC-M.0383 bpf,ID=6276" H 8139' X X Z X. 8306' H7"X 4-1/2"BKR S-3 PKR,0=3.875" I , 8329' I-4-1/2"I-ES X NP,0=31113- BEHIND PIPE 8341' -14-1/7'FES WLEG,D=3.958" 4-1/2'TBG, 12.6#,L-80 BTM H 8341' 8341' -7"X 4-1/2"TNN LTPw/7.35"TBR,ID=5149' .0152 bpf,ID=3.958' --------- 8352 -7"X 4-1/2"TIVV L/42 HY ORO HGR 13=3.915' 7"CSG,29#,L-80 BTC-k .0371 bpf,ID=6.184" - 8554' I k ..........„.„.....„..- 8773' I-3'SEAL STINGER w/NO-GO,ID=2.375" 3-1/2 LW 92#,13CR-80 STL,.0087 bpf,ID=2.992" - 8773' 8778' H 3.70-DEPLOY SLV w/45 KB LTP,ID=3.00" I: 8784" -145 KB LM TOP FKR,ID=2.45' :4 .1-, ESTSAA TF33 TOP OF Cf3AENT H -8808 ' 8808' -3'BKR SEAL STINGER&3.70"EITT GEN 2 I : LNR DER_OY SLV,ID=2.375" P 4 4 3-1/2 LW 9.3#,L-80 STL,.0087 bpf,ID=2.992" - 8832' 4 .4 P 8832' -3-1/2'X 3-3/16'XO,0=2.786' 4-1/2"WHIPSTOCK(TAGGED 05/22/11) - 8850' 4. : t # • •, MLLOUT WINDOW(15-48C) 8852'-8859' 4-1/2"LW, 12.6#,L-80 NSCT,.0152 bpf,ID=3.958" H •,,., V r. PERFORATION SUMVARY ‘4,‘ ----- 9510' -13-3/16"X 2-7/8"XO,ID=2.377" REF LOG:SLB MBA GR/CCL/CNL ON 5/31/11 --.....-- 10152'- 10165' -2-7/8" WD VV1DEPACK PKR -........ ANGLE AT TOP PERF: 92'(.. 9540' Note:Refer to Production[13 for historical perf data SIZE SFF NTERVAL Opn/Sqz SI-OT SQZ 7 6 9660-9720 0 11/07/15 13..25"ORFICE(11/08/15) 2' 6 9540-9570 0 11/07/15 Nb 7 6 9945-9975 0 11/07/15 9510' -CBP(MLLa) 2" 6 10220-10270 S 06/01/11 12/27/13 ..411% &PUSHED TO 2' 6 10430-10770 S 06/01/11 12/27(13 3-3/16'LW,62#,L-80 TC11, --I 9510' 111144141p BTM 01/03/14) 2' 6 10810-10900 S 06/01/11 12/27/13 0076 bpf,ID=2.80" 7 6 11100-11170 0 06/01/11 41414' 2" 6 11210-11400 0 06/01/11 2' 6 11490-11560 0 06/01/11 PBTD - 11908' Ailk• 2' 6 11650-11790 0 06/01/11 :lir 2' 6 11850-11900 0 06/01/11 2-7/8"Lt*,6.16#,L-80 SU,.0058 bpf,ID=2.441" - 11946' DATE REV BY COM&ENTS DATE REV BY COMMENTS PRUDHOE BAY [NT 1 . 01/28/96 IMTIAL COMPLETION 01/07/14 I IR/PJC PA_L/PUSH 03P BIM(01/03/14) WELL 15-48C 02/23/03 JLMIKK CTD SIDETRACK(15-481) 11/17/15 TBD/JMD GLV C/O(11/12/15) FERMI No: 110300 11/26/05 NORDIC 1 CTD SIDETRACK(15-48B) 11/17/15 JTIV/JMD SET FKR/ADF'ERFS(11/07-08/15) AR No: 50-029-22635-03 06/05/11 NORGIC 2.CTD SIDETRACK(15-48C) SEC 22,T11N,R14E, 1309'FM &259'FIM_ 12/07/13 DU/PJC TREE C/0/SFTY NG I h.(12/3/13) 01/07/14 TTR/PJC CMT S07(12/27/13) BP Exploration(Alaska) _ , Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a-I 1_ - 030 Well History File Identifier Organizing(done) ❑ Two-sided III 111111 I III 11111 ❑ Rescan Needed III 11111111 U Hull RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: m, reyscale Items: Other, No/Type: C, No her Items Scannable by Ir •1 v1 + a Large Scanner 1iS ❑ Poor Quality Originals: �J OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: 411Elb Date: (tO1 b `J /s/ viF Project Proofing 111111111 11111 II III BY: � Date: i(Q1 I is/ U • Scanning Preparation A x 30 = /9i1 + = TOTAL PAGES 10'T (Count does not include cover sheet) BY: C_...M.21....1a.. Date: (01 I k)// /s/ ,/ Production Scanning I Ill II VIII II III Stage 1 Page Count from Scanned File: Ivy' (Count does include cove heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: 497/61 114- /s/ fop Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I 1111111111111111 ReScanned III IllIlIllUl 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III 1111 III a E o 9ea r1 c o 2 ° - ° 1° Cu in rn 0' c v LL co Z �'� 0 a o >, - 0a N 'l f0 = CL o) U r r l'I d z Ce c a) >, a) 9 �I ' d c, nce Qcc co (I) 22 d (°n n E • m a Cu E a (o0 o Cu E g E 2 E m O -1-C.) ° U E 0 E Z .6 0co as 0 0 2 Ft N E 20 �0 2 2 0Q0 I a o -0 a) 0 0 0 d oo N NNN y'N N N NO co U o O cc to (O 0) Q) 0) 0) 1 J 0) a) 0) Z r� w rn rn rn rn pJ E � c Vf O d 7 C c c C C C C E a a) a) 0.. a) Y a) a) a) y (wu, c = = la a a a a a E I H g �, Y oo10000 000 o IX Q w U Cu a (Mn (Mn ((0 O v v i- O Z m ca i rn 0) cc co cn rn o) te, Z O 0 N I w 0) a. p I E N E W ga Z �v O c t I'.FO CO 0 0 0 v v (A Z II LL J a� co co )n nt (n )n (n a (n v W W a) U m o d Z I U o Q • Z o y u_) o d «° (° 2 E O o 0,:13 0 0 0 0 T E 0. N cp ZI J2 U U U U u) O u_ 2g ON a a) W 0 (n (n 00 E J CO N )n N )n ✓ 00 al E CO U J 0 Q 00 J O p 2 Zr J (/) 5� O O 0 Cu G �' N U y CO a —` CO (p Ir ,,=A 0 m In 2V/ o p N ICIC Ce a a) Ci0 I—Q p a ZI w w z o 0 > > .5 .> .> Q a) Up , 0 Z Z Ti_r v_) )n J Z SII 0 U _ W CC Cu f0 I' To' Cu Q' Q ma)I O o .o o Cu E .o • co C Lc) Cu ` E 7 O E E 7 c Z v v Cu m -O ° W - r CO 0 0 c 5 0 0 m N Z oOrnJ O > I « Hco H • F - ` dm ' v c 3t 1 k0 2 }a z r woz w N O O .,C m o cs a ° E = E E E z v p.0 °) 0 Ce w. 0 ++ 5 01;� S ; Z Q 1 8 , co o \ zO n °cc li Z gn J 0 p aid U . E E n of T�a 6a d lEti O F- o. J O H �' W J J J J W 3 < > 0 <CC 0 O 9 M 9 N M co z N N U / 9 D O to O .1 z E. a poI o z r N w co I— Q il D Ce Q- N O z O. ° � U I� LL 0 J a X W w U m o Z 8 s Q d J o w a- C N C C r. o G O ) O N Q, Co E • o J U Q q toH F— '_ 2/� E 1 N W m• (o o m Q c Q O E z o CI d U E A z d In• coo) co o p m M I- 11 O 41 c d N Z cc 0• Lo a) V C . G. 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Q E W CO CO Q �. m Q Q up Q CO U CO U m O h m m a p N O 0) OD = a 2 in in O N O . in co 00 r M It) r N. in ti N Y c In a) C E W E 0T0 v < O r N r N N r M r r N O N 0 0 r M N aJ co 03 .0 co = Z m co in W r in U m .0 2 J 0 `p O z 2 z W r 2 7 0114":"110 r O r N V a; O w o O. co O In tGI Pl..........• ra o O _C W v) o h N Q x a Cl. oDi Q Letter of Transmittal BAKER Date: July 1, 2011 HUGHES To: � From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson I � i Please find enclosed the directional survey data for the following well(s): C-42A E-23CPB1 E-23CPB2 E-23C E-19C 02-21B 15-48C 21k-D3O 15-05BPB 1 15-05B Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: I 0 , State of Alaska AOGCC DATE: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class: 20AAC 25.105 2OAAC 25.110 ® Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 6/5/2011 211-030 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 5/23/2011 50-029-22635-03-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 5/29/2011 PBU 15-48C 3971'FSL,5021'FEL,SEC.22,T11N, R14E, UM 8. KB(ft above MSL): 66.7' 15.Field/Pool(s): Top of Productive Horizon: 3536'FSL, 1020'FEL, SEC.21,T11N, R14E, UM GL(ft above MSL): 32.9' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 2047'FSL,3209'FEL, SEC.21,T11N, R14E, UM 11911' 8959' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 676193 y- 5960178 Zone- ASP4 11953' 8956' ADL 028306 TPI: x- 674926 y- 5959714 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 672775 y- 5958175 Zone- ASP4 None 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) L N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR/CCL/MCNL 8850' 8573' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE ToP BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 114' Surface 114' 30" 260 sx Arcticset(Approx.) 9-5/8" 40# _ L-80 34' 3548' 34' 3546' 12-1/4" 995 sx Coldset III.305 sx'G'. 187 sx CS II 7" 26#/29# _ L-80 32' 8554' 32' 8324' 8-1/2" 235 sx Class'G' 4-1/2" 12.6# L-80 8341' 8850' 8146' 8573' 6" 316 sx Class'G' 3-3/16"x 2-7/8"6.2#/6.16# L-80 8774' 11946' 8510' 8957' 4-1/8" 121 sx Class'G' 3-1/2" 9.2# , 13Cr 3901' 8774' 3898' 11510' N/A Uncemented Scab Liner ✓ 24. Open to production or injection? IS Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 2"Gun Diameter,6 spf 4-1/2", 12.6#, L-80 8341' 8306'/8117' MD ND MD ND 10220'-10270' 8925'-8925' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10430' 10770' 8930' 8943' COMP r: 10810'-10900' 8946'-8953' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11100'-11170' 8969' 8974' 4 2500' Freeze Protect w/38 Bbls of Diesel 11210'-11400' 8977'-8984' ' 11490' 11560' 8981'-8978' I;, 11650'-11790' 8974'-8966' 11850'-11900' 8963'-8960' 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): June 13,2011 Flowing Date of Test: Hours Tested: Production For OIL-BEL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 6/21/2011 8 Test Period ♦ 799 4,047 .375 68 5,067 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 381 580 24-Hour Rate .4 2,396 12,141 3 27° 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 MC 250.071. None E E N RBDMS JUN 3 0 2011 .'-i in 1 1iUN ,. Form 10-407 Revised 12/2009 CONTINUED ON REVERS Naga Gil &Get Com f Jfr101f$sio fubmit Original Only -5-n Anrrrime 41°7/;34 6 29.`GEOLOGIC MARKERS(List all formations and m�...ers encountered): 30. r"ORMATION TESTS NAME MD ND Well Tested? 0 Yes 0 No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Base of CGL 8876' 8594' None 23SB/Zone 2B 8948' 8652' 22TS 9034' 8716' 21TS/Zone 2A 9090' 8755' Zone 1B 9180' 8812' TDF/Zone 1A 9275' 8860' Formation at Total Depth(Name): TDF/Zone 1A 9275' 8860' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. O/ /30 Signed: Terrie Hubble � (,� Title: Drilling Technologist Date: /� PBU 15-48C 211-030 Prepared ByName/Number: TerrieHubble,564-4628 Well Number Permit No./Approval No. Drilling Engineer: Mark Staudinger, 564-5733 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only North America-ALASKA- BP Page 1 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 ' Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA IUWI:500292263500 Active Datum: 66: 48 5/30/1996 17:14©66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/17/2011 120:00 - 23:00 3.00 MOB P PRE HOLD PJSM AND MOVE RIG OFF OF WELL 02-21. STAGE RIG ON PAD. RIG CREW MOVE RIG MATS AWAY FROM I WELLHEAD AND CLEAN AREA AROUND WELL. TOURPUSHER AND DRILLER MAKE ROUTE I INSPECTION. Ii SAND TRUCK BEGINS SANDING ROUTE OF TRAVEL TO DS 15. PAD OPERATOR SIGN OFF ON WELLWORK I TRANSFER PERMIT AND POST RIG SITE INSPECTION. 23:00 - 00:00 1.00 MOB P PRE HOLD PJSM WITH RIG CREW AND SECURITY ON VING RIG TO DS 15. I BEGIN OMOVE FROM AROUND DS 2 TO WEST DOCK RD. 5/18/2011 00:00 - 00:30 0.50 MOB P 1 PRE CONTINUE TO MOVE RIG AROUND DS 2 TO WEST DOCK RD. 100:30 - 05:00 t 4.50 MOB P i,. PRE MOVE RIG DOWN WEST DOCK RD AND THEN OXBOW RD EN ROUTE TO DS 15. --f" TURN ONTO OXBOW RD AT 0200-HRS AND ! ! ONTO DS 15 ACCESS RD AT 0330-HRS. j ,—.., 0400-HRS-MOVE SATELLITE CAMP FROM DS 2TODS15. 0500-SATELLITE CAMP AND RIG ON BACK I , __ 3AD OF DS 15. 05:00 - 06:00 1.00 MOB P •' PRE COMPLETE WELL WORK TRANSFER PERMIT FOR 15-48 WITH PAD OPERATOR. ' F ' DISCUSS RIG CAMP SITING AND LOCATION CONTROL. UNLOAD ALL EQUIPMENT AND RIG MATS i � NEEDED TO BE PLACED AROUND WELL. 06:00 - 07:30 1.50 ; MOB P , PRE PREP AREA AROUND WELLHEAD-SET RIG MATS AND PLYWOOD AROUND CELLAR 07:30 - 09:00 1.50 MOB P PRE PJSM AND BACK RIG OVER WELL 09:00 - 09:30 j 0.50 MOB P PRE SECURE CELLAR AND SPOT EQUIPMENT 09:30 - 10:00 0.50 MOB P ' PRE SET STAIRWAYS AND RIG EQUIPMENT- ' ACCEPT RIG AT 10:00 HRS ON 5/18/11 10:00 - 12:00 2.00 BOPSUR P PRE PJSM TO N/D TREE CAP AND N/U BOPE 12:00 15:00 3.00 BOPSUR P PRE NU BOP EQUIPMENT-AOGCC WITNESS WAS WAIVED BY INSPECTOR:MATT HERRERA 15:00 - 15:30 0.50 BOPSUR P PRE PJSM TO SHELL TEST-LUBRICATOR EXTENSION TO FLOOR FAILED 15:30 - 16:30 1.00 BOPSUR P PRE RIG DOWN EXTENSIONS AND REPLACE —� O-RING-RE-TEST-PASSED 16:30 - 23:30 7.00 BOPSUR P PRE PERFORM INITIAL BOPE TEST. ALL TESTS TO 250-PSI LOW AND 3500-PSI HIGH. HOLD AND CHART EACH TEST FOR 5-MINUTES. 60. ALL TESTS WITNESSED BY NORDIC TOOLPUSHER. AOGCC REP,MATT HERRERA,WAIVED STATE'S RIGHT TO WITNESS THE BOPE TEST. Printed 6/23/2011 1:18:19PM North America-ALASKA- BP Page 2 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) - 7 PRE HOLD RIG EVACUATION DRILL. 23:30 00:00 0.50 � BOPSUR P �I CREW AND CH2MHILL TRUCK DRIVER ON LOCATION ALL RESPONDED TO PRIMARY • MUSTER AREA AT SATELLITE CAMP. AN AAR WAS HELD AND THE MAIN POINT OF DISCUSSION WAS THE NECESSITY OF SOUNDING THE"AIR RAID"ALARM TO ALERT PERSONNEL WORKING OUTSIDE THE CONFINES OF THE RIG AND ALSO THAT ANNOUNCEMENT NEEDS TO BE MADE OVER • • THE RIG RADIO, HARMONY RADIO AND THE GAITRONICS, EVEN IN THE EVENT OF A DRILL. THE SIGN IN SHEET WAS BROUGHT FROM THE SIGN IN TRAILER TO THE MUSTER AREA AND DISCUSSION FOLLOWED BECAUSE THERE IS NOT A PERSON ASSIGNED TO RETRIEVE THE SHEET DURING THE NIGHT • SHIFT(SPOC'S RESPONSIBILITY DURING DAY TOUR). 5/19/2011 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUE WITH INITIAL BOPE TEST. ALL TESTS TO 250-PSI LOW AND 3500-PSI HIGH. HOLD AND CHART EACH TEST FOR 5-MINUTES. ALL TESTS WITNESSED BY NORDIC TOOLPUSHER AND BP WSL. AOGCC REP, MATT HERRERA,WAIVED STATE'S RIGHT TO WITNESS TEST. PERFORM ACCUMULATOR DRAWDOWN TEST. 01:00 - 01:30 0.50 BOPSUR P PRE RD BOP TEST EQUIPMENT. FLOW WATER THROUGH GAS BUSTER U-TUBE TO ENSURE IT IS FREE OF • OBSTRUCTIONS. 01:30 - 02:00 ' 0.50 RIGU P PRE HOLD PRE-SPUD MEETING WITH RIG CREW. DISCUSS WELL OBJECTIVES AND KNOWN CHALLENGES. 02:00 - 02:30 0.50 RIGU P PRE HOLD PJSM ON RU INJECTOR AND PULL COIL ACROSS. 02:30 - 04:30 2.00 RIGU P PRE MU PACKOFF TO INJECTOR HEAD. SPOOL CABLE ONTO TUGGER TO PULL COIL • THROUGH INJECTOR HEAD. PULL TEST GRAPPLE-GOOD. REMOVE WOOD, BANDING, CLAMP AND SHIPPING BAR FROM REEL. 04:30 - 05:15 0.75 RIGU P PRE PULL COIL ACROSS ROOF AND STAB INTO INJECTOR HEAD. CUT GRAPPLE OFF AND INSTALL NEW BOOT ON ELINE. 05:15 - 07:00 1.75 RIGU P PRE SET INJECTOR BACK OVER CIRCULATION HOLE AND FILL COIL, PUMPING AT 1-BPM. 07:00 - 07:30 0.50 BOPSUR P PRE COIL FULL-PJSM FOR TESTING INNER REEL VALVE, BULKHEAD,AND STRIPPER 07:30 - 08:15 0.75 BOPSUR P PRE TEST TO 250 LOW AND 3500 HIGH-GOOD- PJSM FOR PUMPING SLACK OUT OF COIL 08:15 - 08:35 0.33 RIGU P PRE PUMP OUT 368'OF CABLE FROM COIL-24% SLACK OR 38'OF EXCESS WIRE 08:35 - 08:50 0.25 RIGU P PRE PJSM FOR MU BTT CTC AND BRING UP BAKER FISHING TOOLS Printed 6/23/2011 1:18:19PM • North America -ALASKA- BP t Page 3 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date:5/29/2011 X3-OOYPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTAUWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft)_- 'i 08:50 - 09:15 0.42 RIGU P PRE INSTALL AND TEST BAKER CTC AND TEST: PULL 34k#-PSI 4000 09:15 - 10:05 0.83 RIGU P PRE PJSM FOR PUMPING 3/4"BALL TO DRIFT COIL -PUMP BALL 10:05 - 11:30 1.42 RIGU P PRE RECOVER BALL W/64 BBLS PUMPED- CONDUCT RIG EVACUATION DRILL/AAR- ALL PERSONNELL RESPONDED TO MUSTER AREA, INCLUDING ON SITE TRUCK DRIVERS 1 IN 2 MINUTES-AAR DISCUSSION BROUGHT TO LIGHT THAT WE ARE STILL WAITING ON DELIVERY AND INSTALLATION OF THE ADDITIONAL RIG EVAC SIREN FOR THE LOWER LEVEL-TP WILL CHECK ON ETA 11:30 - 12:00 0.50 WHSUR !I P DECOMP PJSM W/BPV CREW FOR PULLING TWC AND t BRING UP THEIR TOOLS 112:00 - 14:45 , 2.75 WHSUR P DECOMP RU LUBRICATOR AND TEST TO 250 LOW AND 3500 HIGH-OK-PULL TWC AND NOTE 180 • PSI BELOW-LOAD OUT BPV TEST EQUIPMENT 14:45 - 15:00 0.25 KILLW P DECOMP PJSM FOR BULLHEAD KILL OF WELL 15:00 - 16:00 1.00 KILLW P DECOMP BULLHEAD 5 BBLS MEOH FOLLOWED BY 180 BBLS KCL @ 4.5 BPM AND AVG PSI 2600#-IA PSI'D UP @ 80 BBLS PUMPED AND THEN TRACKED PUMPING PRESSURE THE REST OF JOB 16:00 - 16:30 1 0.50 KILLW P DECOMP TP 0#-IA90#-REMOVE NIGHT CAP AND FILL HOLE W/4.5 BBLS FLUID 16:30 - 19:00 2.50 KILLW P DECOMP MONITOR WELL TO ESTABLISH LOSS RATE- +/-8 BPH-GAS BUBBLING UP BUT HOLE STILL TAKING NORMAL FILL-IA HOLDING @90# 19:00 - 19:30 0.50 KILLW P DECOMP HOLD RIG EVAC DRILL AND AAR. WELL WAS SECURED AND ALL PERSONNEL ON LOCATION RESPONDED CORRECTLY TO I THE SECONDARY MUSTER AREA(SPOC TRAILER)DUE TO PREVAILING WIND DIRECTION. ALL APPROPRIATE ALARMS AND ANNOUNCEMENTS WERE MADE. IT WAS NOTED THAT THERE WERE NO WIND DIRECTION INDICATORS ON THE ODS OF THE RIG,SO THE SPILL SHACK WAS MOVED TO THE ODS OF THE RIG UNTIL MORE WINDSOCKS COULD BE INSTALLED. , ALSO, NO RIG CREW ROSTER WAS AVAILABLE IN THE SPOC TRAILER-WILL DISCUSS AT SLT MEETING. 19:30 - 21:00 1.50 PULL P DECOMP HOLD PJSM WITH RIG CREW ON TESTING DBPV. , MU DBPV TO COIL CONNECTOR AND PRESSURE TEST. TEST TO 250-PSI LOW AND 2500-PSI HIGH. HOLD AND CHART EACH TEST FOR 5-MINUTES.-GOOD TESTS. MAINTAIN CONTINUOUS HOLE FILL DURING ' TEST WITH 12-BPH LOSS RATE. Printed 6/23/2011 1:18:19PM North America-ALASKA-BP r Page 4 of 16 I Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 21:30 0.50 PULL P DECOMP PU ON INJECTOR HEAD TO SEE HOW HIGH ABOVE RIG FLOOR IT COULD BE PICKED UP. AT MAX HEIGHT, BOTTOM OF PACKOFF TO RIG FLOOR=10.5'. MU 3'LUBRICATOR EXTENSION TO BOTTOM OF PACKOFF. - 21:30 - 22:45 1.25 PULL P DECOMP HOLD PJSM ON MU FISHING BHA. MU FISHING BHA CQNS1$IING OF_:4"GS SPEAR,3/4"DISCONNECT,OIL JAR,XO,2-EA 3-1/8"DCS,XO,ACCELERATOR, DBPV,XO, 3-JTS OF 2-3/8"PH6 TBG,XO, LOCKABLE SWIVEL,XO,CTC. OAL= 180.46'. 22:45 - 00:00 1.25 PULL P DECOMP MU BHA TO CTC AND STAB INJECTOR ON TO WELL. TOOK 8-BBLS TO GET RETURNS. RIH WITH FISHING BHA AT 50-FPM TO 2900'. CIRCULATE AT.8-BPM WITH 300-PSI. 5/20/2011 00:00 - 00:30 0.50 PULL P DECOMP HOLD KICK WHILE TRIPPING DRILL WITH RIG CREW. ALL CREW MEMBERS RESPONDED CORRECTLY. REVIEW NORDIC KICK WHILE TRIPPING •CREW ROLES AND RESPONSIBILITIES AND COMPARE TO ADW"WELL CONTROL OPERATIONS STATION BILL". 00:30 - 00:50 0.33 PULL P DECOMP CONTINUE TO RIH WITH FISHING BHA FROM 2900'TO 3900' WT CHECK AT 3900': PU WT=25K-LBS,SO WT=10K-LBS. 00:50 - 01:15 0.42 PULL P DECOMP HOLD PJSM ON FISHING LINER AND CIRCULATING WELL. DISCUSS POSITIONS OF PEOPLE, • POTENTIAL FOR VENTING GAS AND IMPORTANCE OF COMMUNICATION DURING FISHING/CIRCULATING OPERATIONS. RIG CREW INSPECT TIGER TANK,TAKE STRAP AND BLOW DOWN LINE TO TIGER TANK TO ENSURE CLEAR. 01:15 - 03:00 1.75 PULL P DECOMP CONTINUE TO RIH SLOWLY FRQM.3904'TO TAG LINER TOP AT 4036'(19'DEEP). SET DOWN 5K-LBS TO ENGAGE GS SPEAR. BEGIN WORKING PIPE,STAGING UP PULLS UNTIL JARS BEGIN HITTING WITH 20K-LB OVERPULLS. FOLLOW EACH JAR HIT WITH A STRAIGHT PULLS FROM 40K-LBS OVER TO 55K-LBS OVER. REPEAT SEQUENCE 15 TIMES,STAGING UP JAR HITS TO 30K-LBS OVER. LINER PULLS FREE AND BEGINS TO MOVE UP HOLE AT 78K-LBS. POH TO 4000'. Printed 6/23/2011 1:18:19PM North America-ALASKA-BP Page 5 of 16 . r Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C:(1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:45 1.75 PULL P DECOMP ESTABLISH CIRCULATION AT 1-BPM WITH 700-PSI. LOSS RATE=12-BPH. STAGE PUMP UP TO 1.5-BPM WITH 1500-PSI AND CBU X 1.5. WHILE CIRCULATING,MOBILIZE EQUIPMENT FOR LD 3-1/2"LINER TO RIG FLOOR. WITH 37-BBLS AWAY,DIVERT FLUID TO TIGER TANK TO AVOID ANY GAS RETURNS INSIDE RIG. TAKE 42-BBLS OF FLUID TO TIGER TANK. WHEN DENSITY RETURNS TO 8.4-PPG,TAKE RETURNS BACK INTO PITS. LOSS RATE CONTINUES TO BE 12-BPH. 04:45 - 05:00 0.25 PULL P DECOMP TAKE ON 8.4-PPG 2%KCL FROM VAC TRUCK. TO BRING PIT VOLUME UP TO 300-BBLS. 160-BBLS REMAINS ON VAC TRUCK. CONTINUE TO CIRCULATE AT 1.5-BPM WITH 1560-PSI. 05:00 - 07:00 2.00 PULL P DECOMP POH FROM 4000'WITH FISHINLGBHAAND 3-1/2"SCAB LINER AT 50-FPM. PULLING SLIGHTLY HEAVY WHILE POH. CIRCULATE AT 1.3-BPM WITH 1000-PSI. LOSS RATE=12-BPH. IA PRESSURE=500-PSI. HOLD 200-PSI BACK PRESSURE TO LIMIT SWABBING POTENTIAL. FLOW CHECK WELL BEFORE UNSTABBING INJECTOR-NO FLUID MOVEMENT. 07:00 - 08:00 1.00 PULL P DECOMP HOLD PJSM ON LD FISHING BHA&LINER. STAND INJECTOR HEAD BACK ON LEGS. RU FALSE TABLE AND EQUIPMENT FOR LD 3-1/2"SCAB LINER. LOSS RATE=6 TO 10-BPH. 08:00 - 09:00 1.00 PULL P DECOMP PULL&LD FISHING BHA. 09:00 - 10:30 1.50 PULL P DECOMP RU RIG FLOOR AND HANDLING EQUIPMENT FOR LD 3-1/2" 13CR80 STL SCAB LINER. DISCUSS FLUID MANAGEMENT PLAN AND DECIDE TO FILL THE WELL BY FILLING LINER AND DOWN LNR X TBG ANNULUS EVERY 20-MINUTES OR 5-JTS PULLED TO MAINTAIN 300-PSI OVERBALANCE. 10:30 - 11:00 0.50 PULL P DECOMP HOLD AAR ON MORNING'S ACTIVITIES AND PJSM ON LD 3-1/2"SCAB LINER. 11:00 - 12:00 1.00 PULL P DECOMP POH AND LD 10-JTS OF 3-1/2"9.2#13CR80 STL LINER. FILL LINER AND DOWN LNR X TBG ANNULUS EVERY 20-MINUTES OR 5-JTS PULLED. SLB INSTALLS CTPID ON HORSE'S HEAD TO CONTINUOUSLY MONITOR CT INTEGRITY. 12:00 - 13:00 1.00 PULL P DECOMP BRING ON MORE 8.4-PPG 2%KCL TO PITS AND MONITOR WELL. LOSS RATE=8 TO 10-BPH. 13:00 - 16:30 3.50 PULL P DECOMP CONTINUE TO POH AND LD 40-JTS OF 3-1/2" 9.2#13CR80 STL LINER. FILL LINER AND LNR X TBG ANNULUS EVERY 5 JTS OR 20-MINUTES. LOSS RATE FLUCTUATING BETWEEN 8 AND 12-BPH. NO TIGHT SPOTS NOTED. NO SCALE OR BUILDUP ON EXTERIOR OF LINER. 16:30 - 17:00 0.50 PULL P DECOMP UNLOAD PIPE SHED AND MONITOR WELL. LOSS RATE=4 TO 10-BPH. Printed 6/23/2011 1:18:19PM North America-ALASKA- BP Page 6 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 18:00 1.00 PULL P DECOMP HOLD KICK WHILE TRIPPING DRILL WITH WSLS,WELL CONTROL AUDITOR AND RIG CREW. HOLD AAR TO DISCUSS DRILL. SOME CHALLENGES WERE NOTED WITH REGARD TO CROSSOVER HANDLING AND PICKING UP THE SAFETY JT. 18:00 - 19:30 1.50 PULL P DECOMP PERFORM CREW CHANGE. DURING HOLE FILL OPERATIONS, EXCESSIVE FOAMING OF THE KCL DUE TO SAFE-LUBE WAS SEEN. ADD DEFOAMER TO PITS AND FLUID IN LINER. LOSS RATE IS 10 TO 12-BPH. 19:30 - 20:00 0.50 PULL P DECOMP HOLD PJSM ON CONTINUE TO POH AND LD 3-1/2"LINER. DISCUSS PROPER HOLE FILL AND PIPE HANDLING TECHNIQUES. 20:00 - 21:30 1.50 PULL P DECOMP DURING INSPECTION OF 3-1/2"HANDLING EQUIPMENT, DISCOVER THAT DOG COLLAR NEEDED TO BE RE-DRESSED AND THAT SLIP-TYPE ELEVATORS HAD SUSTAINED DAMAGE TO THE SETTING PLATES AND RETENTION WIRES(MOST LIKELY WHEN HANDLING SAFETY JOINT). REDRESS DOG COLLAR. DISCUSS PIPE HANDLING OPTIONS WITH CTD SUPT AND TOOLPUSHER. RECIEVE APPROVAL TO PROCEED USING FLAT-TOP ELEVATORS AND BP OWNED LIFTING EYES. CHANGE OUT ELEVATORS AND VERIFY INSPECTION CERTIFICATION OF BP-OWNED LIFTING EYES. LOSS RATE= 10 TO 12-BPH. 21:30 - 00:00 2.50 PULL P DECOMP CONTINUE TO POH AND LD 25-JTS 3-1/2"9.2-# 13CR80 STL LINER(75-JTS TOTAL LD AT 0000-HRS) FILL LINER AND LNR X TBG ANNULUS EVERY 5-JTS OR 20-MINUTES. LOSS RATE=10 TO 12-BPH. TREAT WITH DEFOAMER AS NEEDED. NO TIGHT SPOTS NOTED WHILE PULLING LINER. NO SCALE OR FILL SEEN ON EXTERIOR OF LINER. 5/21/2011 00:00 - 02:45 2.75 PULL P DECOMP CONTINUE TO POH AND LD 25-JTS 3-1/2"9.24 13CR80 STL LINER(100-JTS TOTAL LD) FILL LINER AND LNR X TBG ANNULUS EVERY 5-JTS OR 20-MINUTES. LOSS RATE= 10 TO 12-BPH. TREAT WITH DEFOAMER AS NEEDED. NO TIGHT SPOTS NOTED WHILE PULLING LINER. VERY LIGHT SCALE SEEN STARTING ON JT #95 LAID DOWN. 02:45 - 03:15 0.50 PULL P DECOMP REMOVE 50-JTS OF 3-1/2"LINER FROM PIPE SHED. FILL WELL-LOSS RATE=10-BPH. 03:15 - 06:00 2.75 PULL P DECOMP CONTINUE TO POH AND LD 25-JTS 3-1/2"9.2-# 13CR80 STL LINER(125-JTS TOTAL LD) FILL LINER AND LNR X TBG ANNULUS EVERY 5-JTS OR 20-MINUTES. LOSS RATE=10 TO 12-BPH. Printed 6/23/2011 1:18:19PM North America-ALASKA-BP Page 7 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date:5/29/2011 X3-00YPQ-C:(1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 10:00 4.00 PULL P DECOMP CREW CHANGE-PJSM AND CONTINUE TO POOH AND LD TOTAL OF 165 JTS OF 3 1/2"9.2#13CR80 STL LINER-PIPE IN EXCELLENT SHAPE WITH VERY LITTLE LIGHT SCALE(PICTURES ATTACHED)-LOSS RATE STABLEAT10-12BPH 10:00 - 11:00 1.00 PULL P DECOMP PJSM-LOAD OUT LINER,TOOL SERVICE CHECKED PIPE FOR NORM:NONE DETECTED-CLEAN RIG FLOOR-CHECK TORQUE OF BOLTS ON TREE:OK 11:00 - 12:00 1.00 CLEAN P • WEXIT PJSM-PU DUMMY WHIPSTOCK /NC)77LE BHA W/3.70"DRIFT RING ON BTM-TOTAL LENGTH OF 103.13' 12:00 - 15:45 3.75 CLEAN P WEXIT PU AND STAB INJECTOR-START RIH @ 85 FPM-100 PSI, IN.38,OUT.78, IA 319#,OA 2#- TAG TOL @ 8905 UNCORRECTED- • CIRCULATE 130 BBLS AT 3 BPM 15:45 - 18:00 2.25 CLEAN P WEXIT POOH W/DUMMY WHIPSTOCK BHA PUMPING 3 BPM-IA=337, OA=5-TAG UP AT SURFACE AND FLOW CHECK WELL 18:00 - 19:45 1.75 CLEAN P WEXIT HOLD PJSM ON LD DUMMY WHIPSTOCK BHA. • LD DUMMY WHIPSTOCK BHA 19:45 - 20:15 0.50 CLEAN P WEXIT •CLEAR RIG FLOOR OF UNNECESSARY TOOLS. BRING ON MORE 8.4-PPG 2%KCL. BRING WHIPSTOCK INTO PIPE SHED. 20:15 - 20:30 0.25 WHIP P WEXIT HOLD PJSM ON SLACK MANAGEMENT OPERATIONS. DISCUSS ORDER OF OPERATIONS, POSITIONS OF PEOPLE, HANDLING CUT COIL AND MANAGING LOSSES TO FORMATION WHILE PUMPING SLACK. 20:30 - 00:00 3.50 WHIP P WEXIT REBOOT COIL. STAB ON INJECTOR,CLOSE SWAB VALVE AND REVERSE CIRCULATE E-LINE INTO COIL AT 3-BPM. OPEN SWAB VALVE AND CHECK FOR PRESSURE=ON VAC. UNSTAB INJECTOR AND CUT OFF BTT CTC. RU CT CUTTER TO LUBRICATOR AND CUT 240'OF COIL(LEAVES 1.74%E-LINE SLACK). RD CUTTER. SET INJECTOR OVER CIRCULATION HOLE AND PUMP SLACK FORWARD. BHI PERFORM MEG TEST ON WIRE- 53-OHMS=GOOD TEST. MAINTAIN CONTINUOUS HOLE FILL WHENEVER POSSIBLE. LOSS RATE= 8.5-BPH. 5/22/2011 00:00 - 01:00 1.00 WHIP P WEXIT INSTALL SLB DIMPLE STYLE CTC. PULL TEST TO 40K-LBS-GOOD TEST. 01:00 - 02:00 1.00 WHIP P WEXIT HEAD UP BHI TOOLS. TEST CONDUCTIVITY OF E-LINE-GOOD TEST. 02:00 - 03:30 1.50 WHIP P WEXIT PRESSURE TEST SLB CTC TO 3500-PSI. GOOD TEST. PRESSURE TEST BHI DBPV TO 250-PSI LOW/ 3500-PSI HIGH. HOLD AND CHART EACH TEST FOR 5-MINUTES. GOOD TESTS. RD TEST EQUIPMENT. Printed 6/23/2011 1:18:19PM North America-ALASKA- BP Page 8 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C:(1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:00 0.50 WHIP P WEXIT HOLD PJSM ON MU WHIPSTOCK BHA. DISCUSS ORDER OF COMPONENTS, HANDLING CONSIDERATIONS AND THE ABILITY TO REMOVE THE ENTIRE BHA FROM THE WELL IN A WELL CONTROL SITUATION. MU WHIPSTOCK SETTING BHA. SCRIBE WHIPSTOCK TO HOT. 'BHA CONSISTS OF 3-5/8"KB PACKER WHIPSTOCK,HYD SETTING TOOL,XO,HOT, DGS, DPS,EXC, POWERCOMMS,WEAR SUB, LQC, UQC,XO AND SLB CTC. OAL=79.20'. 04:00 - 06:10 2.17 WHIP P WEXIT MU COIL TO BHA AND STAB ON INJECTOR. OPEN EDC. RIH WITH WHIPSTOCK,CIRCULATING ACROSS THE TOP OF THE WELL TO MAINTAIN RETURNS. 06:10 - 07:00 0.83 WHIP P WEXIT PAR @ 8615 FOR TIE-IN 07:00 - 08:00 1.00 WHIP P WEXIT CORRECTED DEPTH TO 8678.003/-30'CORR -PULL UP HOLE TO 8398 TO CCL LOG 08:00 - 08:30 0.50 WHIP P WEXIT PARKED @ 8866 CORRECTED DEPTH=BTM OF WHIPSTOCK/8850'=TnP(IF WHIPPsTOCX / 0 DEGREE HS-SHUT EDC-PSI TO 570# AND SLIPS SET-PSI TO 1600#AND SEE •SHEAR-SET 7000#ON PACKER/HOLDING- STRAIGHT PULL UP TO GET BOTTOM OF ROD 10'ABOVE TRAY-CLEAN PICK UP-CT WT 43000# 08:30 08:50 0.33 WHIP P WEXIT RU TO TEST TBG/IA/WS PACKER-PSI TO 1000#AND HOLD FOR 10 MINUTES-SOLID TEST/IA UP TO 1140 AND HOLDING STEADY ALSO 08:50 - 10:00 1.17 WHIP P WEXIT POOH W/WHIPSTOCK SETTING ASSEMBLY 10:00 - 10:15 0.25 WHIP P WEXIT TAG AT SURFACE-PJSM FOR HANDLING BHA 10:15 - 11:30 1.25 WHIP P WEXIT FLOW CHECK WELL AND LAY DOWN BHA 11:30 - 12:30 1.00 STWHIP P WEXIT PJSM-WORK ON TOOLS AND MAKE UP MILLING BHA 12:30 - 14:15 1.75 STWHIP P WEXIT RIH W/MILLING BHA CONSISTING OF:3.8" WINDOW MILL,3.8"DSM,2-7/8"EXTREME MTR,XO, 2-JTS 2-3/8"PH6 TBG,XO BLIND SUB, DGS, DPS, EDC, POWER&COMMS, WEAR SUB, LQC, UQC,XO,CTC. OAL= 118.57' 14:15 - 14:40 0.42 STWHIP P WEXIT TIE IN @ 8715'/-25.5'CORRECTION- CONTINUE TO BOTTOM 14:40 - 18:00 3.33 STWHIP P WEXIT TAG TOP OF WHIPSTOCK AT 8850'-BEGIN TIME MILLING WINDOW @ 1'/HR @ 3025PSI/ 310#DHWOB/2.56IN/2.6 OUT WHILE DISPLACING KCL WITH USED POWER PRO/ IA 811#-OA4# 18:00 - 19:45 1.75 STWHIP P WEXIT CONTINUE TO MILL WINDOW AT 1'/HR WITH 8.8-PPG POWERPRO TO 8852.9'. RUNNING 2500-LBS WOB AND 300-PSI MOTOR WORK. a1-4 SLIGHT GAIN NOTICED IN SURFACE MUD VOLUME-MUD APPEARS TO BE AIRED UP AND AGITATORS MAY BE CAUSING FLUCTUATION IN TOTCO READINGS. Printed 6/23/2011 1:18:19PM North America -ALASKA- BP411 Page 9 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site:PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release: 6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14©66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — — — • (ft)19:45 - 20:15 0.50 STWHIP P WEXIT PU TO 8840'AND FLOW CHECK WELL-NO FLOW SEEN. ADD DEFOAMER TO PITS AND RUN AGITATORS. 21:45 - 00:00 ', 2.25 STWHIP P WEXIT OBTAIN SPRS WITH PUMP#2 AND 8.8-PPG POWER PRO. 1-BPM=1710 PSI. 2.5-BPM= 2860-PSI(FREE SPIN) RIH TO 8852'AND RESUME CONTROL MILLING AHEAD TO 8855.5'PUMPING AT 2.5-BPM. MOTOR WORK RESUMES AT 8852.5'WITH 40-PSI AND WOB AT 1K-LBS. CONTINUE TO CONTROL MILL WINDOW AT 1'/HR. 2054-HRS-8853'WITH 2400-LBS WOB/ 200-PSI MOTOR WORK. 2156-HRS-8853.5'WITH 2600-LBS WOB/ 180-PSI MOTOR WORK. AT 8853.9'MILLED SEE DECREASE TO 2000-LBS WOB/70-PSI MOTOR WORK. TREND CONTINUES. 2359-HRS-8855.5'WITH 1000-LBS WOB/ 40-PSI MOTOR WORK. 5/23/2011 00:00 - 05:30 5.50 STWHIP P WEXIT CONTINUECONTROLMILLING WINDOW AT 1-FPH/2.5-BPM FROM 8855.5'TO 8861'. FREE SPIN WITH 8.8-PPG POWER PRO AT • 2.5-BPM=2860-PSI. I VERY FINE METAL SEEN ON DITCH MAGNETS 1THROUGHOUT MILLING WITH INCREASING • VOLUME STARTING AT 0300-HRS. 0037-HRS-AT 8856'WITH 1330-LBS WOB/ 50-PSI MOTOR WORK. 0110-HRS-AT 8856.5'WITH 1440-LBS WOB/ 60-PSI MOTOR WORK. 0157-HRS-AT 8857.3'WITH 2100-LBS WOB/ 60-PSI MOTOR WORK. 0240-HRS-AT 8858'WITH 2700-LBS WOB/ 1110-PSI MOTOR WORK 0309-HRS-AT 8858.5'WITH 2400-LBS WOB/ 240-PSI MOTOR WORK. WEIGHT DRILLING OFF BUT MOTOR WORK STAYING FAIRLY CONSISTENT. 0344-HRS-AT 8859'WITH 2400-LBS WOB/ 140-PSI MOTOR WORK. AT 8859.5'STRING MILL APPEARS TO BE AT WINDOW. 0430-HRS-AT 8859.7'WITH 2300-LBS WOB/ 240-PSI MOTOR WORK. 0500-HRS-AT 8860.2'WITH 2080-LBS WOB/ 240-PSI MOTOR WORK. SAMPLE FROM 8859'SHOWS 55% FORMATION. 05:30 - 11:00 5.50 STWHIP P WEXIT MILL 10'OF RATHOLE TO 8869'. MAKE MULTIPLE REAMING PASSES THROUGH WINDOW AND DRY DRIFT WITHOUT ISSUE. ON LAST PASS,TAG BOTTOM AT 8869.4'. PULL ABOVE WINDOW AND FLOW CHECK WELL-STATIC. Printed 6/23/2011 1:18:19PM North America -ALASKA- BP Page 10 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 13:45 2.75 STWHIP P WEXIT BLEED IA PRESSURE FROM 830-PSI TO 50-PSI. POH WITH WINDOW MILLING BHA. FLOW CHECK BEFORE UNSTAB FROM WELL -STATIC 13:45 - 15:00 1.25 DRILL P PROD1 MU BHA TQQR31l.L..B.UILD..S.ECTION_ BHA CONSISTS OF:3-3/4"X 4-1/4"HYCALOG SRR3611 M-B4-Z BICENTER BIT,1.2-DEG 2. -7/8"ULTRA MTR, HOT,MPR, DGS, DPS, EDC, P&C,WEAR SUB,LQC, UQC,DO,CTC. OAL= 80.11'. 15:00 - 16:50 1.83 DRILL P PROD1 STAB INJECTOR HEAD AND RIH WITH BUILD DRILLING BHA. 1630-HRS-SPILL DRILL&AAR WITH ENTIRE RIG CREW. 16:50 - 17:20 0.50 DRILL P PROD1 TIE IN FROM 8660'. APPLY-29.5' CORRECTION CONTINUE TO RIH TO TAG BOTTOM AT 8669'. 17:20 - 00:00 6.67 DRILL P PROD1 OBTAIN SPRS WITH MP#2-1-BPM=1700-PSI, 2.5-BPM=2840-PSI. BEGIN DRILLING AHEAD FROM 8869'TO 8960'. PUMP RATE=2.5-BPM WITH 100-200 PSI MOTOR WORK. SEE MULTIPLE STALLS 8950'THRU 8960' (GEOSURVEY INDICATES POSSIBLE SHALE) 5/24/2011 00:00 - 02:45 2.75 DRILL P PROD1 CONTINUE TO DRILL AHEAD IN BUILD SECTION FROM 8960'TO 9000'. FREE SPIN=2.5-BPM/2840-PSI. DRILL AHEAD WITH MULTIPLE STALLS AT 8960',8966',8971',8976',8983',8987',8989', 8996',8999'(GEOSURVEY INDICATES SHALE THROUGH THIS SECTION AND MWD SHOWS SHALE IN 8960'SECTION). AFTER STALL,PU AND PERIODICALLY SEE —10K-LB OVERPULLS. INTERVALS OF DRILLING AHEAD WOB= 4000-LBS TO 1500-LBS AND MOTOR WORK AT 100-150-PSI DIFFERENTIAL. 02:45 - 03:00 0.25 DRILL P PROD1 WIPER TRIP FROM 9000'BACK TO WINDOW AT 30-FPM WHILE PUMPING AT 2.5-BPM/ 2780-PSI. ORIENT TO 0-HS, PUMP MIN RATE AND PULL THROUGH WINDOWN AT 5-FPM. NO ISSUES CONTINUE TO POH TO 8800'AND MAKE JOG BACK TO WINDOW. OPEN EDC AND CIRC AT 3.1-BPM/2880-PSI POH TO 8630' 03:00 - 04:30 1.50 DRILL P PROD1 LOG TIE IN PASS AT 3-FPM FROM 8630'TO 8900'. CIRC THRU OPEN EDC AT 3.1-BPM/2880-PSI WHILE LOGGING. APPLY+1/2'CORRECTION. RA TAG AT 8859'. TOW=8850',BOW=8859'. Printed 6/23/2011 1:18:19PM North America-ALASKA- BP Page 11 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release: 6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 10:40 6.17 DRILL P PROD1 CLOSE EDC&RIH TO 9000'. FREE SPIN=2.6-BPM WITH 2850-PSI. CONTINUE DRILLING AT AHEAD IN BUILD SECTION FROM 9000'TO 9150'MD. SEE STALLS AT 9011'BUT ABLE TO DRILL AHEAD MORE CONTINUOUSLY THAN PRIOR TO TIE IN. RUN BETWEEN 900 AND 1900-LBS WOB AND SEE CONSISTENT MOTOR WORK AT 150-PSI DIFFERENTIAL. 10:40 - 11:00 0.33 DRILL P PROD1 WIPER TRIP FROM 9150'BACK TO WINDOW. NO ISSUES NOTED. RIH TO9150' 11:00 - 16:40 5.67 DRILL P PROD1 CONTINUE TO DRILL AHEAD IN BUILD SECTION FROM 9150'TO 9301'. 16:40 - 17:15 0.58 DRILL P PROD1 WIPER TRIP FROM 9301'BACK TO WINDOW. NO ISSUES NOTED. RIH TO 9301'. 17:15 - 23:15 6.00 DRILL P PROD1 CONTINUE TO DRILL AHEAD IN BUILD SECTION FROM 9301'TO 9450'. RUN 2-5-KLBS WOB AND SEE MOTOR WORK 150-400-PSI DIFFERENTIAL. CONTINUE TO SEE PERIODIC STALLING. ECD= 10.25-PPG. 2150-HRS MAKE BHA LENGTH WIPER FROM 9425'TO 9318'. 23:15 23:50 0.58 DRILL P PROD1 WIPER TRIP FROM 9450'TO 8880'AT 20-FPM. CIRCULATE AT 2.6-BPM WITH 2870-PSI. NO ISSUES NOTED. 23:50 00:00 0.17 DRILL P PROD1 MAKE TIE IN PASS ACROSS RA TAG AT 8859'. LOG AT 2-FPM WITH.9-BPM/1600-PSI. • NO DEPTH CORRECTION. RIH TO 9450'. 5/25/2011 00:00 - 05:15 5.25 DRILL P PROD1 CONTINUE TO DRILL AHEAD IN BUILD SECTION FROM 9450'TO 9480'. LANDED BUILD(-90-DEG)AT 9480'PER DD. CONTINUE TO DRILL AHEAD IN LATERAL FROM 9480'TO 9523'. FREE SPIN=2.6-BPM WITH 2870-PSI. RUN 1500-5000-LBS WOB. SEE 200-400-PSI DIFFERENTIAL MOTOR WORK. MAKE 40'WIPER TRIPS AT 9478'AND 9516'. PERIODIC STALLING ISSUES HAVE CEASED BUT ROP IS DROPPING. 0445-HRS-HOLD KICK WHILE DRILLING DRILL AND AAR WITH RIG CREW. HIGHLIGHTED THAT NEW ROUSTABOUT RESPONDED CORRECTLY. DISCUSSED "WHAT IF"THE INJECTOR PACKOFF FAILED. 05:15 - 06:00 0.75 DRILL P PROD1 MAKE WIPER TRIP AT 30-FPM FROM 9523'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2820-PSI. NO HOLE ISSUES NOTED. 06:00 - 07:10 1.17 DRILL P PROD1 DRILL TO 9533 FT. ROP IS AROUND 15 FT/HR, STACKING ABOUT 6K DWOB TO ACHIVE THAT. 07:10 - 09:20 2.17 DRILL P PROD1 POOH FOR RSM BIT AND MOTOR. PULL THROUGH WINDOW AND OPEN EDC,10 MIN FLOW CHECK SHOWS NO FLOW. POOH PUMP 3 BPM THROUGH OPEN EDC. Printed 6/23/2011 1:18:19PM North America-ALASKA- BP Page 12 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date:5/29/2011 X3-00YPQ-C: (1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:20 - 10:00 0.67 DRILL P PROD1 TAG STRIPPER. 10 MIN FLOW CHECK THEN L/D BHA#5. BIT IS 1-1, SLIGHT RINGING AROUND THE NOSE. 10:00 - 10:30 0.50 BOPSUR P PROD1 FUNCTION TEST BOPS. 10:30 - 12:30 2.00 DRILL P PROD1 M/U BHA#6-3"COILTRAK WITH RES,RSM MOTOR. BHA OAL=73.6' 12:30 - 12:50 0.33 DRILL P PROD1 M/U INJECTOR RISER. RIH TO 170 FT AND STOP. 12:50 - 13:10 0.33 DRILL P PROD1 PJSM FOR INSPECTING TRACTION MOTOR BRUSHES AND CONNECTIONS. PERFORM LO/TO OF SCR WITH NORDIC ELECTRICIAN AND HAYDEN ELEC TECH. 13:10 - 14:00 0.83 DRILL P PROD1 INSPECT TRACTION MOTOR. NO DEFECTS FOUND. 14:00 - 17:00 3.00 DRILL P PROD1 CONTINUE RIH TIE-IN DEPTH,CORRECT-29 FT. PASS THROUGH WINDOW AND RIH TO BOTTOM. START MUD SWAP. 17:00 - 19:00 2.00 DRILL P PROD1 DRILL FROM 9530-9700 FT. VERY SLOW ROP GETTING STARTED,<10 FT/HR BUT INCREASED TO-30 FPH BY 9560 THEN TO -50 FPH. 1.5-3.5K WOB. 3300 PSI ON BOTTOM,3050 PSI OFF BOTTOM. 22:00 - 22:30 0.50 DRILL P PROD1 WIPER TRIP FROM 9,700'TO 8,880'CTMD AT 30 FPM. 2.6 BPM IN 3040 PSI. CT WEIGHT 38.5K ON TRIP OUT. 22:30 - 23:00 0.50 DRILL P PROD1 TRIP BACK IN HOLE FROM 8,880'CTMD TO 9,700'CTMD AT 30 FPM. 2.6 BPM IN AT 3065 PSI. CT WEIGHT ON RIH-23K. 23:00 - 00:00 1.00 DRILL P PROD1 DRILL AHEAD FROM 9700'-9785'CTMD. FREE SPIN 3050 PSI. ON BOTTOM 3200-3400 PSI. DWOB 2.0-2.5K. ROP-85 FPH. 5/26/2011 00:00 - 00:45 0.75 DRILL P PROD1 DRILL AHEAD IN 3.75"PRODUCTION LATERAL FROM 9785'-9850'CTMD. FREE SPIN 3050 PSI. ON BOTTOM 3200-3400 PSI. DWOB 2.0-2.5K. ROP-85 FPH. 00:45 - 01:30 0.75 DRILL P PROD1 WIPER TRIP FROM 9,850'TO 8,750'CTMD AT 30 FPM. 2.6 BPM IN 3040 PSI. CT WEIGHT 39.5K ON TRIP OUT. 01:30 - 02:00 0.50 DRILL P PROD1 D1 KICK WHILE TRIPPING DRILL. AAR AFTER. DISCUSSED COMMUNICATIONS AND INVOLVING THE SPOC IN WELL CONTROL DRILL ACTIVITIES. 02:00 - 02:30 0.50 DRILL P PROD1 RIH BACK TO 9,850'. 02:30 - 04:35 2.08 DRILL P PROD1 DRILL AHEAD IN 3.75"PRODUCTION LATERAL FROM 9850'- 10000'CTMD. FREE SPIN 3100 PSI. ON BOTTOM 3200-3400 PSI. DWOB 2.0-2.5K. ROP-95 FPH. 04:35 05:25 0.83 DRILL P PROD1 WIPER TRIP FROM 10,000'TO 8,900'CTMD AT 30 FPM. 2.6 BPM IN 3100 PSI. Printed 6/23/2011 1:18:19PM North America -ALASKA- BP Page 13 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date:5/29/2011 X3-00YPQ-C: (1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:25 - 08:20 2.92 DRILL P PROD1 DRILL FROM 10000 FT TO 10150 FT. ROP IS AROUND 100 FT/HR WITH 2-3K DWOB. CONTINUE HOLDING 89 DEG INC TO FOLLOW PLAN. 08:20 - 10:10 1.83 DRILL P PROD1 WIPER TRIP FROM 10150 FT TO WINDOW. CLEAN PASS UP AND DOWN. 10:10 - 14:00 3.83 DRILL P PROD1 DRILL FROM 10150 FT WITH INTIAL ROP AROUND 100 FT/HR WITH 3.6K DWOB. HOLD 88.5 DEG INC FOR NOW AS PER PLAN. 2.53/2.54 BPM @ 2900 PSI FS. SOME WT STACKING IN THE SHALE ZONES. DRILL TO 10300 FT. 14:00 - 15:30 1.50 DRILL P PROD1 WIPER TRIP FROM 10300 FT TO WINDOW. CLEAN PASS UP AND DOWN. 15:30 - 18:30 3.00 DRILL P PROD1 DRILL FROM 10300 FT.TO 10421 FT. CONTINUE HOLDING 88 DEG INC FOR NOW. STACKING WEIGHT BUT LITTLE FORWARD PROGRESS,DECIDE TO WIPER TRIP EARLY AND DISPLACE TO NEW MUD SYSTEM WHEN BACK ON BOTTOM. 18:30 - 20:30 2.00 DRILL P PROD1 WIPER TRIP AT 20-FPM FROM 10421'TO WINDOW. CIRCULATE AT 2.5-BPM WITH 3050-PSI. PULL THRU WINDOW SLOWLY,PUMPING AT .5-BPM WITH 1580-PSI LOG TIE IN PASS ACROSS RA TAG. +3' CORRECTION NO ISSUES NOTED ON TRIP. 20:30 - 21:15 0.75 DRILL P PROD1 RIH AT 20'FPM FROM WINDOW TO 10400' DISPLACE WELL TO NEW 8.6-PPG POWERPRO SYSTEM AT 2.5-BPM WITH 2270-PSI. 21:15 - 23:45 2.50 DRILL P PROD1 RESUME DRILLING AHEAD FROM 10421'TO 10600'. ECD REDUCED TO 9.77-PPG WITH NEW MUD IN WELL. OBTAIN NEW SPRS WITH PUMP#2-1-BPM= 1320-PSI,2.5-BPM=2315-PSI(ALSO FREE SPIN). ROP GREATLY IMPROVES. DRILL AHEAD WITH 2000-LBS WOB AND 500-PSI MOTOR WORK. 23:45 - 00:00 0.25 DRILL P PROD1 WIPER TRIP AT 25-FPM FROM 10600'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2320-PSI. NO ISSUES NOTED ON TRIP. 5/27/2011 00:00 - 01:50 1.83 DRILL P PROD1 CONTINUE WIPER TRIP AT 25-FPM FROM 10600'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2320-PSI. 01:50 - 03:15 1.42 DRILL P PROD1 DRILL AHEAD FROM 10600'to 10751'. ABLE TO ATTAIN 100-FPH ROP WITH 500-PSI DIFFERENTIAL MOTOR WORK AND 2-3000-LBS WOB. 03:15 - 05:20 2.08 DRILL P PROD1 WIPER TRIP FROM 10751'BACK TO THE WINDOW AT 30-FPM. CIRCULATE AT 2.6-BPM WITH 2285-PSI. NO ISSUES NOTED ON WIPER TRIP. IA PRESSURE=660-PSI. OA PRESSURE= 60-PSI. 05:20 - 07:00 1.67 DRILL P PROD1 DRILL AHEAD FROM 10751'. Printed 6/23/2011 1:18:19PM • North America-ALASKA- BP Page 14 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date: 5/29/2011 X3-00YPQ-C: (1,967,359.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 07:20 0.33 DRILL P PROD1 CONDUCT UNANNOUNCED KICK WHILE DRILLING EXERCISE. CT SUPERVISOR TELLS DRILLER HE HAS SEEN A 10 BBLS PIT GAIN. CT SUPERVISOR PICKS UP OFF BOTTOM AND FLOW CHECKS WELL,PREPARES TO SHUT IN IF NECESSARY. DRILLER LOOKS FOR FLOW AT SHAKER,ALL OTHER PERSONNEL REPORT TO DESIGNATED AREAS. 'WSL AND TOOLPUSHER ARE NOTIFIED. EXERCISE ENDED AT THIS POINT,AAR CONDUCTED. 07:20 - 07:40 0.33 DRILL P PROD1 DRILL TO 10900 FT. 07:40 - 10:15 2.58 DRILL P PROD1 WIPER FROM 10900 FT. TIE-IN DEPTH,CORRECT-2 FT. CLEAN PASS UP AND DOWN. 10:15 - 13:20 3.08 DRILL P PROD1 QN BOTTOM DRII I INC-I F.R,QMJOSOO..ET__... CONTINUE HOLDING 85 DEG INC AND AIM FOR CENTER OF POLYGON. ROP IS 60-80 FT/HR WITH 2.4K DWOB. PERIODIC WT STACKING,PICK UP 100 FT EACH TIME. DRILLING THROUGH THIN SHALE/CLAY LAYERS THAT GIVE ERRATIC DRILLING AND SLOW ROP. PUMP 10 BBLS HI-VIS SWEEP AROUND. DRILL TO 11050 FT. 13:20 - 16:00 2.67 DRILL P PROD1 WIPER TRIP FROM 11050 FT TO WINDOW. CLEAN PASS UP AND DOWN. 16:00 - 18:30 2.50 DRILL P PROD1 DRILL FROM 11050 FT.TO 11182 FT. 18:30 - 20:30 2.00 DRILL P PROD1 PUMP 20-BBL HI VIS SWEEP AND WIPER FROM 11182'TO WINDOW. POH AT 25-FPM WHILE CIRCULATING AT 2.66-BPM WITH 2400-PSI PUMP PRESSURE. 20:30 - 23:10 2.67 DRILL P PROD1 DRILL AHEAD FROM 11182'TO 11352'. BEGIN TO BUILD ANGLE AT 11,300'TO TOE UP INTO Z1B. GETTING 10-DEG/100'FROM RIBSTEER DRILL AHEAD WITH 400-600-PSI DIFFERENTIAL MOTOR WORK AND RUNNING 1500-4000-LBS WOB WITH GOOD ROP. MAKE BHA WIPER TRIP FROM 11331'TO 11101'WITHOUT ISSUE. 23:10 - 00:00 0.83 DRILL P PROD1 MAKE WIPER TRIP AT 25-FPM FROM 11352' TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2500-PSI. 5/28/2011 00:00 - 02:20 2.33 DRILL P PROD1 CONTINUE WIPER TRIP AT 25-FPM FROM 11,350'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2500-PSI. ORIENT AND PASS THROUGH WINDOW WITH PUMPS AT MIN RATE WITHOUT ISSUE. LOG TIE IN ACROSS RA TAG-+3' CORRECTION. RIH AT 27-FPM,CIRCULATING AT 2.6-BPM/ 2600-PSI,WITHOUT ISSUE. Printed 6/23/2011 1:18:19PM • North America-ALASKA- BP Page 15 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:5/17/2011 End Date: 5/29/2011 X3-00YPQ-C:(1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:20 - 03:30 1.17 DRILL P PROD1 DRILL AHEAD IN LATERAL FROM 11,352'to 11501'. ECD INITIALLY=10.11-PPG AT 2.6-BPM WITH 2610-PSI. DRILL AHEAD WITH 400-600-PSI DIFFERENTIAL MOTOR WORK AND 2-5-KLBS WOB. FINAL ECD WITH SAME CIRC RATE= 10.29-PPG. 03:30 - 07:00 3.50 DRILL P PROD1 WIPER TRIP AT 25-FPM FROM 11501'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2630-PSI. IA PRESSURE=770-PSI,OA PRESSURE= 275-PSI. 07:00 - 09:30 2.50 DRILL P PROD1 DRILL AHEAD IN LATERAL FROM 11501'TO 11,650'. DISPLACE WELL TO NEW 8.6-PPG POWERPRO MUD SYSTEM. 09:30 - 14:30 5.00 DRILL P PROD1 WIPER TRIP FROM 11,650'TO WINDOW. RECIPROCATE PIPE SLOWLY UNTIL PIT 3 IS FULL ENOUGH TO USE FOR THE TRIP BACK TO BOTTOM(COMPLY WITH FLUID MANAGEMENT POLICY). NO ISSUES NOTED ON TRIP. 14:30 - 16:30 2.00 DRILL P PROD1 OBTAIN NEW SPR-PUMP#2-1-BPM= 1538-PSI,2.5-BPM=2570-PSI. DRILL AHEAD FROM 11,650'TO 11,795'. 16:30 - 21:00 4.50 DRILL P PROD1 WIPER TRIP FROM 11,795'TO WINDOW. PULL THROUGH WINDOW SLOWLY WITH LOW PUMP RATE-NO ISSUES. LOG TIE IN PASS ACROSS RA TAG-0' CORRECTION. NO ISSUES NOTED ON TRIP. 21:00 - 00:00 3.00 DRILL P PROD1 DRILL AHEAD IN LATERAL FROM 11 795 TO 11880'. STALLING AND PERIODICALLY HAVING TROUBLE GETTING WOB FROM 11795'TO 11,830'. MAKE BHA WIPER FROM 11,830'TO 11,730' AND ABLE TO GET WOB AGAIN. DRILL AHEAD WITH 4.5-7K-LBS WOB AND 600-1000-PSI MOTOR WORK ROP STEADILY INCREASES BEYOND 11,830' WITH 2-3-KLBS WOB AND 400-800-PSI MOTOR WORK. 5/29/2011 00:00 - 00:40 0.67 DRILL P PROD1 CONTINUE TO DRILL AHEAD IN LATERAL SECTION FROM 11880'TO 11954'. HIGH ROP WITH 2-4K-LBS WOB AND 400-800-PSI MOTOR WORK. MAKE BHA WIPER AT 11917'WITHOUT ISSUE AND RESUME DRILLING AHEAD. Printed 6/23/2011 1:18:19PM North America -ALASKA- BP Page 16 of 16 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 5/17/2011 End Date: 5/29/2011 X3-00YPQ-C:(1,967,359.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14©66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:40 - 05:00 4.33 DRILL P PROD1 WIPER TRIP AT 23-FPM FROM 11,954'TO WINDOW. CIRCULATE AT 2.6-BPM WITH 2430-PSI. AFTER DISCUSSION WITH ASSET GEO,SITE GEOLOGIST CALLS TD WITH SUFFICIENT Z1 B EXPOSURE. ON TRIP TO WINDOW,SEE SLIGHT •PRESSURE INCREASE AT 11630'AND 10492', l SLACK OFF AND PULL PAST SLOWLY AT 8-FPM WITHOUT ISSUES. PULL THROUGH WINDOW SLOWLY WITH PUMP AT.5-BPM/970-PSI-NO ISSUES. TIE-IN TO RA TAG.+2'CORRECTION. RIH WITHOUT ISSUE AND TAG BOTTOM AT 11953'CORRECTED MD. 05:00 - 06:40 1.67 DRILL P PROD1 .POH FROM 11,953'AT 35-FPM, LAYING IN LINER RUNNING PILL AT.6-BPM/1035-PSI. 06:40 - 07:00 0.33 DRILL P PROD1 PULL ABOVE WINDOW AND OPEN EDC. RUN BACK TO 8930 FT AND LOG CCL ACROSS LTP SETTING AREA. 07:00 - 09:10 2.17 DRILL P PROD1 POOH. PAINT FLAGS AT 8600 AND 5500 FT EOP ON THE WAY OUT. 09:10 - 09:30 0.33 DRILL P PROD1 TAG STRIPPER AND FLOW CHECK WELL. PJSM FOR UD BHA. 09:30 - 11:00 1.50 DRILL P PROD1 SHORT CHAIN BHA AND LIFT IT OUT TO CHECK BIT. BIT IS 3.75 NO-GO,GRADED 2-1 WITH 1 CHIPPED CUTTER. LAY DOWN BHA IN 3 PIECES. ALL FURTHER INFORMATION ON CON REPORT. Printed 6/23/2011 1:18:18PM North America-ALASKA-BP Page 1 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/29/2011 11:00 - 12:50 1.83 CASING P RUNPRD LOAD SELRT INTO PIPE SHED. REMOVE BHI CABLE HEAD. INSTALL CABLE BOOT. MOVE INJECTOR OVER CIRC HOLE AND PUMP 172 FT OF CABLE OUT AT 4.6 BPM, LEAVES 100 FT UNACCOUNTED FOR ACCORDING TO SLB RECORDS. 12:50 - 13:40 0.83 CASING P RUNPRD PREP TO PUMP DRIFT BALL THROUGH REEL.. PUMP 3/4 DRIFT BALL THROUGH REEL, LANDS 10 BBLS EARLY. 13:40 - 16:00 2.33 CASING P RUNPRD CUT OFF SLB CONNECTOR, INSTALL BTT CONNECTOR. PULL TEST TO 40K,GOOD. PRESSURE TEST TO 3500 PSI, GOOD. SET INJECTOR ON LEGS. 16:00 - 16:30 0.50 CASING P RUNPRD PJSM FOR RUNNING PRODUCTION LINFR - 16:30 - 19:00 2.50 CASING P RUNPRD RUN 2-7/8"6.2#L80 STL PRODUCTION LINER PER RUNNING ORDER(20-JTS AT 1830-HRS). FILL LINER EVERY 10-JTS.-SEEPAGE LOSSES. 19:00 - 21:00 2.00 CASING P RUNPRD HOLD H2S RIG EVACUATION DRILL AND AAR WITH INCOMING CREW. DURING THE PROCESS OF EVACUATING THE RIG AND SECURING THE WELL,THE ESD WAS FUNCTION TESTED FROM THE SLB OPS CAB. THE ESD FUNCTIONED CORRECTLY. THE RIG WAS EVACUATED AND THE GENERATORS RESTARTED. THE SLB SLICKLINE CREW WORKING ON 15-05 ALSO EVACUATED TO THE SPOC TRAILER AND THANKED US FOR KEEPING THEM IN THE LOOP. ONCE THE RIG GENERATORS WERE RESTARTED,THE CREW GATHERED IN THE DOGHOUSE AND HELD AN AAR. DISCUSSION CENTERED ON EMERGENCY SITUATIONS WHEN THE RIG IS WITHOUT POWER AND HOW THE WELL WOULD BE SECURED. IT WAS ALSO IDENTIFIED THAT THE ESD IN THE SLB OPS CAB NEEDS TO HAVE A PROTECTOR SIMILAR TO THE ONE ON THE REMOTE BOP PANELS FOR THE BLIND SHEARS. 21:00 - 00:00 3.00 CASING P RUNPRD CONTINUE TO RUN 2-7/8"6.2#L80 STL PRODUCTION LINER PER RUNNING ORDER. (Jt 21 -76) 5/30/2011 00:00 - 01:30 1.50 CASING P RUNPRD CONTINUE TO RUN 3-3/16"TCII X 2-7/8"STL LINER PER RUNNING ORDER. 01:30 - 03:00 1.50 CASING P RUNPRD MU LINER RUNNING BHA. BHA CONSISTS OF:XO,3/4"DISCONNECT, XO,4-JTS 2-3/8"PH6 TBG,XO, LOCKABLE SWIVEL,XO,BTT CTC. OAL= 137.17'. Printed 6/23/2011 1:18:44PM North America-ALASKA- BP Page 2 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 06:10 3.17 CASING P RUNPRD STAB ON INJECTOR. BREAK CIRCULATION AT.3-BPM WITH 1000-PSI. TOOK 4.8-BBLS TO GET RETURNS. RIH AT 95-FPM. YELLOW FLAG AT 5500'EOP/8773.31' W/LINER. CTDS DEPTH=8805'. CORRECT CTDS DEPTH WITH-31.7' CORRECTION. WT CHECK BEFORE GOING THROUGH WINDOW: PU WT=45K-LBS. SO WT= 26-KLBS. PASS GUIDE SHOE THROUGH WINDOW AT 20-FPM. NO ISSUES NOTED UPON INITIAL OPEN HOLE ENTRY. CONTINUE TO RIH AT 45-FPM. 06:10 - 06:30 0.33 CASING P RUNPRD LAND LINER ON BOTTOM AT 11942 FT. DEPTH IS-11 FT FROM RECORDED TD YESTERDAY AS PER INJECTOR ENCODER,-6 FT AS PER REEL ENCODER. DISCUSS WITH ODE DEPTH DISCREPANCY. FLAGS WERE PAINTED WHILE POOH AND USED FOR A CORRECTION WHILE RIH, ACCOUNTING FOR AROUND 5 FT OF DIFFERENCE. UP WT WITH LINER IS 48K. SET WT DOWN TO REACH BALL DROP SPOT, DEPTH IS 11943 FT. 06:30 - 07:10 0.67 CASING P RUNPRD DROP 5/8 BALL AND LAUNCH WITH 1200 PSI, BALL IS HEARD ROLLING. GO TO MIN RATE AFTER BALL LEAVES THE REEL HOUSE. BALL LANDS AT 37 BBLS,SHEARS SEAT OUT AT 4510 PSI!?! PICK UP TO NEW BREAKOVER WT OF 38K AND PICK UP ANOTHER 2 FT TO VERIFY. REPEAT WITH SAME RESULTS TO CONFIRM LINER IS RELEASED. 07:10 - 10:40 3.50 CASING P RUNPRD SWAP WELL TO 2%KCL WATER. 10:40 - 11:00 0.33 CEMT P RUNPRD PJSM FOR PUMPING CEMENT WITH SLB CMT CREW AND NORDIC RIG CREW. DISCUSS MUSTER AREA,GOOD COMMUNICATIONS. 11:00 - 11:20 0.33 CEMT P RUNPRD PREP TO PT CEMENT LINE. CEMENT UNIT TAKES ON KCL WATER FROM THE RIG AND PT THE CEMENT LINE TO 4800 PSI,GOOD. 11:20 - 11:40 0.33 CEMT P RUNPRD START BATCHING UP CEMENT TO 15.8 PPG. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 3 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: COM-ONSHORE(CON) Start Date:5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project: Prudhoe Bay Site:PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:40 - 12:30 0.83 CEMT P RUNPRD CEMENT IS UP TO 15.8 PPG. START CEMENT DOWN CT. j AFTER 24.9 BBLS SHUT DOWN CEMENT UNIT. �/ CLEAN UP LINE TO CEMENT UNIT AND STAY RIGGED UP. SWITCH TO RIG PUMP AND DISPLACE WITH h1 BIOZAN. DISPLACE AT 2 BPM. SLOW DOWN PUMP TO 1 BPM WHEN LEADING EDGE OF CEMENT IS AT THE LWP. 'AT 78.4 BBLS THE CEMENT IS AT THE GUIDE SHOE,ZERO OUT MM LEAVE IN MM RUNNING. 12:30 - 13:00 0.50 CEMT P RUNPRD WITH 2 BBLS CEMENT LEFT ABOVE THE SELRT STOP PUMP. PICK UP CT WT+ 13 FT MORE THEN SET BACK TO 10K DOWN. NEW DEPTH IS 10 FT HIGHER. TRY TO PUSH PEE WEE DART INTO LWP, DOESN'T SEAT AFTER 1 BBL. 'PICK UP AND STACK DOWN 2 MORE TIMES, EACH TIME PUMP 0.5 BBLS. STILL GETTING RETURNS EACH TIME,NO SIGN OF PEE WEE DART SEATING IN THE LWP. 13:00 - 13:30 0.50 CEMT P RUNPRD DISCUSS WITH BTT SUPERVISOR IN DEADHORSE,CTD SUPT AND MARK JOHNSON. DECIDE TO CONTINUE WITH SIDE EXHAUST AND DISPLACE CEMENT WITH 1 • LINER VOLUME OF BIOZAN IF THE LWP WON'T LAUNCH. SIDE EXHAUST 5 BBLS THEN STACK BACK DOWN. INCREASE RATE SLOWLY FROM 0.5, 1.0, 1.5 BPM TO TRY AND GET PEE WEE DART TO SEAT. EACH TIME IT PRESSURES UP THEN BLEEDS OFF. AT 1.8 BPM IT SEATS WITHOUT RETURN FLOW. PRESSURE UP LWP AND LAUNCH AT 3500 PSI. 13:30 - 14:00 0.50 CEMT P RUNPRD BUMP PLUG 1 BBL OVER CALCULATED DISPLACEMENT. TOTAL OF 22.2 BBLS BEHIND PIPE. BUMP PLUG WITH 3000 PSI AND HOLDS PRESSURE. BLEED OFF PRESSURE AND OPEN BAKER CHOKE,NO RETURN FLOW. PRESSURE UP TO 500 PSI AND UNSTING, CIRC 1 BBL AND POOH. 14:00 - 15:35 1.58 CASING P RUNPRD POOH, REPLACE CT VOIDAGE+0.5 BPM. 15:35 - 17:00 1.42 CASING P RUNPRD HOLD PJSM,FLOW CHECK WELL-STATIC, AND LD LINER RUNNING TOOLS. ALL TOOLS AND 5/8"BALL RECOVERED. NO ISSUES NOTED. 17:00 - 19:00 2.00 EVAL P OTHCMP REMOVE BTT TOOLS FROM PIPE SHED. BRING MEMORY LOGGING TOOLS AND CNL SOURCE TO RIG FLOOR. 19:00 - 19:30 0.50 EVAL P OTHCMP HOLD PJSM ON MU CLEANOUT/MEM CNUCCUGR LOGGING BHA. DISCUSS HAZARDS ASSOCIATED WITH CNL SOURCE AND PROPER HANDLING OF 1-1/4" CSH FROM DERRICK. Printed 6/23/2011 1:18:44PM North America-ALASKA- BP Page 4 of 12 • Operation Summary Report Common Well Name: 15-48 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 23:00 3.50 EVAL P OTHCMP MU CLEANOUTLMEM CNUCCUG.R__LOCzGLNG _ BHA. BHA CONSISTS OF 2.30"DSM,2-1/8"XTREME MOTOR,XO,2-JTS 1-1/4"CSH,XO, MEM GR/CNUCCL IN CIRC CARRIER,1/2"CIRC SUB,5/8"DISCONNECT,XO,54-STDS 1-1/4" CSH,XO,3/4"HI LOAD DISCONNECT, DBPV, •XO,2-JTS OF 2-3/8"PH6,XO, LOCKABLE SWIVEL,XO,BTT CTC. OAL=3541.76' TEST DBPV TO 250-PSI LOW/3500-PSI HIGH FOR 5-CHARTED MINUTES EACH TEST WHILE RIH WITH 1-1/4"CSH. GOOD TESTS. 23:00 - 00:00 1.00 EVAL P OTHCMP PU CT INJECTOR HEAD. MU CT TO BHA. STAB INJECTOR ONTO WELL. RIH WITH CLEANOUT/LOGGING BHA AT 80-FPM. CIRCULATE AT.46-BPM WITH 400-PSI. MONITOR DENSITY AND PH-DUMPING RETURNS AS NEEDED. 5/31/2011 00:00 - 02:00 2.00 EVAL P OTHCMP CONTINUE RIH WITH CLEANOUT/LOGGING BHA AT 90-FPM TO 8200'. CIRCULATE AT.45-BPM WITH 430-PSI. SOME STRUNG OUT CEMENT CONTAMINANT RETURNS. TAKE ALL RETURNS WITH DENSITY>8.7-PPG OUTSIDE. MAX DENSITY SEEN=8.82-PPG. RIH TO 9000'WHILE DUMPING CEMENT CONTAMINANT RETURNS. NO ISSUES ENTERING LINER TOP. POH TO 8200'. 02:00 - 04:00 2.00 EVAL P OTHCMP MEMORY LOG GR/CCUCNL FROM 8200'TO PBTD AT 11926' AT 30-FPM. CIRCULATE 1.2-BPM WITH 1170-PSI. NO ISSUES ENTERING LINER TOP OR PASSING THRU 3-3/16"X 2-7/8"XO. SEE 120-PSI MOTOR WORK AT 9421'. IMMEDIATELY DROPS OFF AND NO OTHER ISSUES NOTED. FILL COIL WITH PERF PILL. SET DOWN 3K-LBS 11926'UNCORRECTED. (MECHANICAL COUNTER READS 8377'+BHA = 11919') 04:00 - 05:40 1.67 EVAL P OTHCMP POH LOGGING AT 60-FPM FROM 11926'TO 8200'. CIRCULATE AT .7-BPM/1100-PSI, LAYING IN PERF PILL. PAINT FLAG 8841'UNCORRECTED(5300' UNCORRECTED EOP) NO ISSUES NOTED WHILE POH. 05:40 - 07:00 1.33 EVAL P OTHCMP POH WITH CLEANOUT/LOGGING BHA AT 1000-FPM FROM 8200'TO 3541'. CIRCULATE AT 1.07-BPM WITH 980-PSI. IA PRESSURE=300-PSI. OA PRESSURE= 1-PSI 07:00 - 08:50 1.83 EVAL P OTHCMP TAG STRIPPER,10 MIN FLOW CHECK. START UD PH6 AND CSH. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 5 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C:(1,342,278.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:50 - 12:20 3.50 EVAL P OTHCMP CONTINUE PULLING CSH. FILL WELL EVERY 15 STDS AS PER FLUID MANAGEMENT POLICY AND VERIFY CORRECT HOLE FILL. STOP AT LAST STAND AND HOLD PJSM WITH SLB MEM LOGGER FOR HANDLING THE SOURCE. REMOVE LOGGING TOOLS AND VERIFY GOOD DATA. CORRECTED PBTD @ 11904 FT. CORRECTED EOP FLAG @ 5287.43 FT. 12:20 - 13:00 0.67 EVAL P OTHCMP PJSM FOR SWIZZLING STACK. JET STACK OUT WITH SWIZZLE STICK. 13:00 - 14:00 1.00 EVAL P OTHCMP PJSM THEN PT BOTH SWAB AND MASTER INDEPENDENTLY. GOOD TESTS, LOW AND HIGH,ON EACH VALVE. 14:00 - 18:30 4.50 BOPSUR P OTHCMP OPEN BOP DOORS AND INSPECT RAMS AND CAVITES. WHILE DOING THAT PERFORM REPAIR WELD ON DERRICK FINGER. 18:30 - 19:00 0.50 BOPSUR P OTHCMP CREW C/O. DISCUSS CURRENT OPS. 19:00 - 20:00 1.00 BOPSUR P OTHCMP C/O TOP SEAL AND INSERTS ON LOWER COMBI'S. C/O TOP SEAL ON VBR'S. SECURE BOP DOORS AND GREASE MUD CROSS. 20:00 - 21:00 1.00 BOPSUR P OTHCMP FILL STACK. PJSM FOR PERFORMING BOP TEST. SHELL TEST STACK TO 250 PSI LOW/3500 PSI HIGH-PASSED. 21:00 - 00:00 3.00 BOPSUR P OTHCMP BEGIN BI-WEEKLY BOP TEST. r ALL TESTS TO 250 PSI LOW/3500 PSI HIGH. I)C� CHART AND HOLD EACH TEST FOR 5 MINS. TEST WITNESS WAIVED BY JOHN CRISP W/ AOGCC. 6/1/2011 00:00 - 01:15 1.25 BOPSUR P OTHCMP CONTINUE W/BI-WEEKLY BOP TEST. TEST WITNESS WAIVED BY JOHN CRISP W/ AOGCC. 01:30 - 01:45 0.25 BOPSUR P OTHCMP PJSM FOR P/U INJ.AND TESTING INNER REEL VALVE AND CT PACK-OFF. 01:45 - 02:30 0.75 BOPSUR P OTHCMP P/U INJ.AND STAB ON. PT INNER REEL VALVE AND CT PACK-OFF TO 250 PSI LOW/3500 PSI HIGH-PASSED. BLEED OFF PSI. 02:30 - 03:45 1.25 ZONISO P OTHCMP OPEN UP MASTER AND SWAB. FILL HOLE-TAKES 1 BBL. LINE UP TO PT LINER LAP. PT LINER LAP TO 300 PSI LOW-PASSED. BEGIN HIGH PT TO 2400 PSI: AT 2370 PSI, PRESSURE STOPS CLIMBING AND BREAKS OVER. SHUT DOWN PUMPS AND MONITOR. PSI BLEEDS OFF 900 PSI IN FOUR MINUTES. 03:45 - 04:00 0.25 PERFOB P OTHCMP POP OFF INJ.AND INSTALL KNIGHT CAP. FILL HOLE CONTINUOUSLY ACROSS THE TOP. Printed 6/23/2011 1:18:44PM North America-ALASKA- BP Page 6 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI: 500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 07:30 3.50 PERFOB P OTHCMP PJSM FOR LOADING PERF GUNS INTO PIPE SHED. LOAD PERF GUNS IN PIPE SHED AND BRING HANDLING EQUIPMENT UP TO RIG FLOOR. PREP RIG FLOOR FOR RUNNING PERF GUNS. PJSM WITH SLB TCP AND NORDIC CREW FOR M/U PERF GUNS. 07:30 - 09:00 1.50 PERFOB P OTHCMP STAaLM/11 PFRF GUNS 09:00 - 09:15 0.25 PERFOB P OTHCMP AT GUN#29 OUT OF 80 CONDUCT UNANNOUNCED KICK WHILE TRIPPING DRILL. DRILLER SIGNALS WELL FLOW BY HITTING AIR HORN ON THE RIG FLOOR. SAFETY JT WITH OPEN TIW IS LATCHED AND PICKED UP. XO FOR SLB GUNS IS MADE UP TO PERF GUN STRING,AND SAFETY JT IS MADE UP TO STRING AND TIGHTENED. END DRILL AT THIS POINT. CONDUCT AAR .ON THE RIG FLOOR AND DISCUSS SCENARIOS AND FURTHER STEPS DRILLER WOULD HAVE TO TAKE TO SECURE THE WELL. 09:15 - 13:00 3.75 PERFOB P OTHCMP •CONTINUE M/U PERF GUNS. M/U 25 STDS OF CSH,3/4"DISCONNECT, DBPV AND 2 JTS PH6 13:00 - 16:00 3.00 PERFOB P OTHCMP M/U SWIVEL AND CT RISER. PUMP 5 BBLS AROUND TO CLEAR PIPE THEN RIH. STOP AT FIRST FLAG AND CORRECT-16 FT. • CONTINUE RIH. 16:00 - 16:20 0.33 PERFOB • P OTHCMP TAG AT 11906 FT, UNCORRECTED. UP WT IS 45K. REPEAT WITH SAME RESULTS. GET UP WT AND CORRECT TO 11911 FT. PULL UP TO JUST BELOW SHOT DEPTH AND START PUMP PROCEDURE TO ACTIVATE FIRING HEAD. LEAVE PUMP RUNNING AFTER THE FINAL STEP. 16:20 - 18:00 1.67 PERFOB P OTHCMP START TO PICK UP SLOWLY AT+/-10 SEC FROM END OF PUMP SEQUENCE. GOOD INDICATION OF SHOTS FROM ACOUSTIC SENSOR AND FLUID LOSS. PICK UP SLOWLY, INCREASE PUMP RATE TO 1.5 BPM,USE HAND CHOKE TO HOLD 150-200 PSI WHP. POOH 40 FT/MIN, KEEP 180 PSI WHP WITH CHOKE WHILE GUNS ARE INSIDE LINER. PERFORATED INTERVALS: 10220-10270 10430-10770 10810-10900 11100-11170 11210-11400 11490-11560 11650-11790 ---- 11850-11900 11850-11900 Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 7 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C:(1,342,278.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 18:45 0.75 PERFOB P OTHCMP PUH ABOVE LINER TOP AND BLEED OFF WH PSI. PERFORM 30 MIN. FLOW CHECK-NO FLOW. FILL HOLE-TAKES 1 BBL TO CATCH RETURNS. 18:45 - 20:00 1.25 PERFOB P OTHCMP CONT. POOH W/PERF GUNS. 1.1 BPM/0.53 BPM IN/OUT @ 100 FPM. LOSSES ARE—1-2 BPM. 20:00 - 20:30 0.50 PERFOB P OTHCMP TAG UP AT SURFACE AND FLOW CHECK WELL-NO FLOW. LOST TOTAL OF 7 BBLS ON TOH. 20:30 - 22:15 1.75 PERFOB P OTHCMP PJSM FOR POPPING OFF INJ.AND STANDING BACK 1-1/4". UNSTAB INJ.AND STAND BACK ON LEGS. UD 2 JTS OF 2-3/8"PH6. • STAND BACK 24 STANDS OF 1-1/4"CSH AND LEAVE LAST STAND IN HOLE TO KEEP PERF • GUNS BELOW TABLE. HOLE TAKING-2 BPH. PREP FLOOR FOR UD GUNS AND R/U FARR TONGS. 22:15 - 22:45 0.50 PERFOB P OTHCMP PJSM W/SLB TCP HANDS AND RIG CREW FOR UD GUNS. DISCUSS HAZARDS,WELL CONTROL,AND GOOD COMMUNICATION. 22:45 - 00:00 1.25 PERFOB P OTHCMP UD LAST STAND OF 1-1/4"CSH. R/U PERF HANDLING EQUIP.AND BEGIN UD SPENT GUNS. 6/2/2011 00:00 - 00:15 0.25 PERFOB P OTHCMP CONT. UD SPENT PERF GUNS. 00:15 - 00:40 0.42 PERFOB P OTHCMP AFTER UD 15 GUNS HOLD KWT DRILL FOLLOWED BY AAR. CREW RESPONDS BY UD PERF GUN, LATCHING AND P/U SAFETY JT.W/OPEN TIW VALVE. SLB XO TO GUNS IS MADE UP AND THE SAFETY JT. LOWERED AND M/U TO THE STRING. 00:40 - 04:30 3.83 PERFOB P OTHCMP CONTINUE UD SPENT GUNS._FILL HOLE EVERY 10 GUNS PULLED. LOSSES ARE—1-2 BPH. LOST TOTAL OF 11 BBLS UD GUNS. 04:30 - 07:30 3.00 PERFOB P OTHCMP CLEAN AND CLEAR RIG FLOOR. PJSM-OFFLOAD PERF HANDLING EQUIP. AND BRING LTP TOOLS UP BEAVER SLIDE. OFFLOAD PERF GUNS FROM THE PIPE SHED. 07:30 - 09:00 1.50 ZONISO P RUNPRD M/11i TP aElA_. 09:00 - 09:40 0.67 ZONISO P RUNPRD RIH WITH BHA#9. 09:40 - 09:50 0.17 ZONISO P RUNPRD STOP AT 2220 FT AND FLOWCHECK, GETTING 7.9 PPG RETURNS. TRIP SHEET IS EVEN, LEL AT SHAKER IS ZERO. 09:50 - 12:00 2.17 ZONISO P RUNPRD NO FLOW FROM WELL,CONTINUE RIH. PUMP 0.5 BPM. MINUS 6 FT CORRECTION AT FLAG,STILL VISIBLE FROM PREVIOUS RUN. Printed 6/23/2011 1:18:44PM North America-ALASKA- BP Page 8 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C:(1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 12:30 0.50 ZONISO P RUNPRD WT CHECK AT 8750 FT IS 40K. STOP AT 8775 FT AND CIRC TO CLEAN UP RETURNS,RETURNS ARE CLEAN AFTER 10 BBLS. REDUCE RATE TO 0.25 BPM, RIH TO ENGAGE SEALS IN DEPLOYMENT SLEEVE. PRESSURE UP AND FIND SLEEVE AT 8835 FT UNCORRECTED. SHUT OFF PUMP,OPEN BAKER CHOKE, TRAVEL 7 FT DOWN SLEEVE AND SET 10K DOWN. PICK UP TO BREAKOVER WT+1 FT AND RECORD DEPTH. 12:30 - 13:20 0.83 ZONISO P RUNPRD PICK UP OUT OF SLEEVE TO A GOOD BALL DROP SPOT. DROP 5/8 BALL, LAUNCH WITH 700 PSI. BALL IS HEARD ROLLING,CHASE IT AT 2 BPM. AFTER BALL LEAVES REEL HOUSE SLOW RATE TO 0.5 BPM, LET IT FALL TO SEAT. SEATS AT 48.0 BBLS. BLEED OFF PRESSURE AT BAKER CHOKE. 13:20 - 15:00 1.67 ZONISO P RUNPRD RIH TO END OF SLEEVE THEN PICK UP TO BREAKOVER+1 FT. PUMP CT UP TO 1800 PSI TO INFLATE THE PACKER ELEMENT. SET 10K BACK DOWN,NOW 2 FT HIGHER. PICK UP TO NEUTRAL WT AND PREP TO PT TBG X CT ANNULUS. • PT TBG X CT ANNULUS. MINUTES PSI 0 297 3 293 5 293 0 2644 -Ve'' 5 2622 10 2611 15 2604 16- 20 2600 1 25 2596 30 2589 TEST SATISFIES ALL 3 CRITERIA FOR PASS: 1. DP OVERALL LESS THAN 10% 2. DP IN 2ND 15 MIN LESS THAN 1/2 OF DP IN 1ST 15 MIN 3. DP IN FINAL 15 MIN LESS THAN 5 PSVMIN DISCUSS RESULTS WITH WTL AND GET AUTHORIZATION TO PROCEED TO THE NEXT STEP. 15:00 - 17:00 2.00 ZONISO P RUNPRD PRESSURE UP CT TO 3000 PSI TO SHEAR OFF RUNNING TOOL AND BLEED OFF SLOWLY. PICK UP AND LEAVE PACKER BEHIND, UP WT 38K. POOH. 17:00 - 18:00 1.00 ZONISO P RUNPRD PJSM. L/D LTP RUNNING TOOLS FOLLOWED BY AAR. 18:00 - 19:45 1.75 CASING P RUNPRD CREW CHANGE-OUT. CLEAN AND CLEAR RIG FLOOR. R/U LINER RUNNING EQUIP.AND FALSE TABLE FOR RUNNING 3-1/2"SCAB LINER. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 9 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:45 - 20:00 0.25 CASING P RUNPRD PJSM FOR M/U 3-1/2"13CR SCAB LINER._ DISCUSS WELL CONTROL, PROCEDURES, DROPPED OBJECTS,AND PINCH POINTS. 20:00 - 00:00 4.00 CASING P RUNPRD BEGIN M/U AND TIH W1 3-1/2"SCAB LINER CONSISTING OF 3"SEAL STINGER W/NO-GO, 160 JTS OF 3-1/2"9.2#STL 13CR,(1)3-1/2" STL 13CR PUP JT,4-1/2"CHROMED KB LTP, 'AND 3.70"CHROMED BKR DEPLOYMENT SLEEVE W/4"GS PROFILE. 11:45-HOLD KWT DRILL AFTER M/U JT.#36 FOLLOWED BY AAR. 6/3/2011 00:00 - 07:00 7.00 CASING P RUNPRD CONTINUE M/U 3-1/2"SCAB LINER. HOLE TAKING—1 BPH. 05:00-TIH W/JT.#120. 07:00 - 10:00 3.00 CASING P RUNPRD CONTINUE M/U 3-1/2 STL 13CR LINER. M/U 3/4 DISCONNECT AND 4 JTS OF PH6. BHA OAL=5016.37 FT. 10:00 11:30 1.50 CASING P RUNPRD PULL TEST CT CONNECTOR TO 50K PRIOR TO M/U INJECTOR. M/U CT RISER. 11:30 - 12:40 1.17 CASING P RUNPRD PUMP 1.6 BELS TO GET RETURNS THEN RIH. PUMP 0.34/290 PSI WHILE RIH. EMERGENCY EXERCISE WHILE RIH, FIRE IS ANNOUNCED IN PUMP RM#1. CREW RESPONDS WITH EXTINGUISHERS IN 2 MIN. CONDUCT AAR. 12:40 - 13:00 0.33 CASING P RUNPRD UP WT AT 8700 FT IS 64K. RIH SLOWLY AT 0.35 BPM TO FIND DEPLOYMENT SLEEVE. PRESSURE UP AT 8798 FT, UNCORRECTED. STOP PUMP AND BLEED OFF PRESSURE, OPEN BAKER CHOKE. RIH A FURTHER 4 FT TO THE NO-GO AND PUT 5K DOWN TO 8802.9 FT. PICK UP TO BREAKOVER+1.5 FT AND PARK, 8797.3 FT. 13:00 - 14:10 1.17 CASING P RUNPRD ,LINE UP TO PT SEALS DOWN THE TBG XCT____ ANNULUS. PT AS FOLLOWS: MINUTES PSI 0 304 3 297 5 293 0 2802 5 2750 10 2732 15 2717 20 2706 25 2699 30 2692 TEST SATISFIES ALL 3 CRITERIA FOR PASS: 1. DP OVERALL LESS THAN 10% 2. DP IN 2ND 15 MIN LESS THAN 1/2 OF DP IN 1ST 15 MIN 3. DP IN FINAL 15 MIN LESS THAN 5 PSVMIN DISCUSS RESULTS WITH WTL,PROCEED WITH OPS. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 10 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C:(1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor:NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:10 - 15:20 1.17 CASING P RUNPRD PICK UP SLOWLY 30 FT TO GET TO BALL DROP POSITION. PUMP 20 BBLS INHIBITED KCL DOWN THE CT FOLLOWED BY 7 BBLS FROM PITS. •SHUT DOWN TO LAUNCH BALL. LAUNCH BALL WITH 1000 PSI. BALL IS HEARD ROLLING,CHASE IT AT 1.80 BPM. AFTER BALL LEAVES REEL HOUSE SLOW TO 0.5 BPM. 15:20 - 16:30 1.17 CASING P RUNPRD BALL LANDS AT 55.5 BBLS. OPEN CHOKE AND RIH TO SET 5K ON NO-GO TO 8802.6 FT. PICK UP TO BREAKOVER WT+ 1.5 FT AND PARK,8796.3 FT. PRESSURE UP TO 1800 PSI ON CT TO COMPRESS ELEMENT AND SET SLIPS. SET 5K BACK DOWN TO 8799.4 FT. BLEED OFF CT PRESSURE AND SET DOWN TO '8799.7 FT. PICK UP TO 55K AND PT KB PACKER DOWN THE TBG X CT ANNULUS. MINUTE PSI 0 359 3 344 5 344 0 2992 5 2959 10 2944 • 15 2937 20 2926 25 2919 30 2911 TEST SATISFIES ALL 3 CRITERIA FOR PASS: 1. DP OVERALL LESS THAN 10% 2. DP IN 2ND 15 MIN LESS THAN 1/2 OF DP IN 1ST 15 MIN 3. DP IN FINAL 15 MIN LESS THAN 5 PSVMIN DISCUSS RESULTS WITH WTL,PROCEED WITH OPS. 16:30 - 17:15 0.75 CASING P RUNPRD PRESSURE UP TO 3000 PSI DOWN CT TO SHEAR OFF RUNNING TOOL. BLEED OFF TO 500 PSI AND TRY TO PULL OFF,UP WT 55K. TRY AGAIN, PRESSURE TO 3500 PSI THIS TIME. NO LUCK. STACK DOWN TO 24K AND PRESSURE UP, NO LUCK. CONTINUE PRESSURE CYCLES TO FATIGUE SHEAR PINS. CONTINUE SETTING DOWN PROGRESSIVELY MORE WT. FINALLY RELEASE FROM KB. 17:15 - 18:15 1.00 CASING P RUNPRD POOH W/BHA#10. 18:15 - 18:30 0.25 CASING P RUNPRD TAG UP AT SURFACE AND FLOW CHECK. 18:30 - 19:30 1.00 CASING P RUNPRD PJSM FOR LID BHA. L/D BHA#10 AND RECOVER 5/8"BALL. SETTING TOOL HAS FUNCTIONED NORMALLY. OFFLOAD BOT TOOLS. 19:30 - 20:00 0.50 CASING P RUNPRD PJSM. M/U NOZZLE BHA AND STAB ON WELL. 20:00 - 20:20 0.33 CASING P RUNPRD PJSM W/LRS FOR PT IA. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 11 of 12 Operation Summary Report Common Well Name: 15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project:Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:20 21:10 0.83 CASING P RUNPRD R/U LRS TO IA AND PT LINES TO 4000 PSI. BLEED OFF PSI. 21:10 - 22:45 1.58 CASING P RUNPRD BEGIN PT IA W/LRS. MINUTES PSI '0 317 3 310 5 306 *LOW PT GOOD-PROCEED TO HIGH PT. 0 3074 .5 3043 10 3027 15 3019 20 3013 25 3008 30 3003 *PT SATISFIES ALL 3 CRITERIA AS PER CRT-AK-10-45: 1. DP OVERALL LESS THAN 10% 2. DP IN 2ND 15 MIN LESS THAN 1/2 OF DP IN 1ST 15 MIN 3. DP IN FINAL 15 MIN LESS THAN 5 PSVMIN DISCUSS RESULTS WITH WTL,PROCEED WITH OPS. PUMPED TOTAL OF 2.8 BBLS TO PSI UP AND BLED BACK TOTAL OF 3 BBLS. (BLED IA DOWN TO 120 PSI-WAS AT 200 PSI PRIOR TO PT). 22:45 - 23:45 1.00 WHSUR P POST RIH W/NOZZLE TO 2500 FT. SPOT LRS FOR PUMPING DIESEL FP. 23:45 - 00:00 0.25 WHSUR P POST PJSM W/LRS FOR FP. 6/4/2011 00:00 - 00:25 0.42 WHSUR P POST R/U LRS AND PT LINES TO 4000 PSI. 00:25 - 02:00 1.58 WHSUR P POST PUMP 38 BBLS OF DIESEL. DISPLACE W/ FRESH WATER. SPOT AND R/U N2 UNIT TO BLOW DOWN COIL. 02:00 - 02:25 0.42 RIGD P POST TAG UP AND CLOSE MASTER AND SWAB. PUMP CORROSION INHIBITOR FOLLOWED BY 10 BBLS OF MEOH INTO COIL. PJSM W/N2 FOR BLOWING DOWN REEL. 02:25 - 02:45 0.33 RIGD P POST PT N2 LINES AND LINE UP TO TT. COME ON LINE W/N2 AT 1500 SCF/MIN AND BLOW DOWN REEL. 02:45 - 03:30 0.75 RIGD P POST RID N2 UNIT AND BLEED OFF PSI. 03:30 - 04:00 0.50 RIGD P POST POP OFF INJ.AND CUT OFF CTC. SET INJ.OVER BUNGHOLE. GREASE CREW AND BPV CREW ON LOCATION. 04:00 - 05:00 1.00' WHSUR P POST PJSM W/BPV CREW AND GREASE CREW. GREASE TREE AND BRING LUBRICATOR UP TO RIG FLOOR. 05:00 - 08:00 3.00 WHSUR P POST R/U DSM LUBRICATOR. PRESSURE TEST LUBRICATOR. SET BPV. 08:00 - 10:00 2.00 WHSUR P POST PJSM THEN PULL CT ACROSS PIPE SHED ROOF. SECURE IT TO THE SHIPPING SPOOL. REMOVE 1502 LINE FROM INSIDE REEL. Printed 6/23/2011 1:18:44PM North America-ALASKA-BP Page 12 of 12 Operation Summary Report Common Well Name:15-48 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/29/2011 End Date:6/5/2011 X3-00YPQ-C: (1,342,278.00) Project: Prudhoe Bay Site: PB DS 15 Rig Name/No.: NORDIC 2 Spud Date/Time: 11/14/2005 12:00:00AM Rig Release:6/5/2011 Rig Contractor: NORDIC CALISTA UWI:500292263500 Active Datum:66:48 5/30/1996 17:14 @66.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 14:00 4.00 WHSUR P POST PJSM THEN LOWER 2-3/8"REEL ONTO TRUCK. PRESSURE TEST SWAB AND MASTER VALVE INDEPENDENTLY. PASSING TEST ON BOTH MASTER AND SWAB VALVE. START CHUGGER FLUID OUT OF BOP STACK. OPEN DOORS AND REPLACE BOP RAM BLOCKS WITH 2". 14:00 - 15:00 1.00 WHSUR P POST CALL AOGCC OFFICE IN DEADHORSE, NOTIFY OF UPCOMING BOP TEST ON 15-05C. CONTINUE CHANGING OUT RAM BLOCKS. 15:00 - 18:00 3.00 WHSUR P POST PJSM THEN P/U 2"REEL. FINISH C/O RAM BLOCKS TO 2". 18:00 20:00 2.00 WHSUR P I POST CREW C/O. I CONTINUE R/U 2"REEL. INSPECT PITS AND KOOMEY BOTTLE. 20:00 - 22:15 2.25 WHSUR P POST C/O GRIPPER BLOCKS AND STRIPPER BRASS FOR 2"COIL. OFFLOAD REMAINING 3-1/2"LINER. 22:15 - 00:00 1.75 WHSUR P POST PJSM FOR PULLING COIL ACROSS. STAB STRIPPER ONTO LUBRICATOR AND M/U INJ. PREP REEL TO PULL COIL ACROSS INTO INJ. 6/5/2011 00:00 01:00 1.00 WHSUR P POST PULL COIL ACROSS INTO INJ. REMOVE GRAPPLE. 01:00 - 01:45 0.75 WHSUR P POST PJSM-UNSTAB INJ.AND SET BACK ON LEGS. 01:45 - 03:30 1.75 WHSUR P POST PJSM FOR N/D BOP'S. ND BOP STACK. NU TREE CAP. 03:30 - 05:00 1.50 WHSUR P POST TEST TREE CAP TO 250-PSI LOW/3500-PSI HIGH. PRESSURE HELD FOR 5 CHARTED MINUTES PER TEST AFTER PRESSURE STABILIZED. NO VISIBLE LEAKS. SECURE WELL. T/IA/OA=0(BPV)/0/0. WELL SECURE AT 0500-HRS ***ALL SUBSEQUENT REPORTS ON 15-05B*** Printed 6/23/2011 1:18:44PM NM BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 15 15-48 500292263500 15-48C Survey: MWD Survey Report - Geographic 31 May, 2011 ram bp MYON " IS Survey Report-Geographic V INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 15-48 Project: Prudhoe Bay TVD Reference: 66:48 5/30/1996 17:14 @ 66.70ft(generic drillinc Site: PB DS 15 MD Reference: 66:48 5/30/1996 17:14 @ 66.70ft(generic drillinc Well: 15-48 North Reference: True Wellbore: 15-48C Survey Calculation Method: Minimum Curvature Design: 15-48C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 15,TR-11-14 Site Position: Northing: 5,958,837.36ft Latitude: 70°17'35.236 N From: Map Easting: 676,296.98ft Longitude: 148°34'21.213 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.34° Well 15-48 API No 500292263500 Well Position +N/-S 0.00 ft Northing: 5,960,178.18 ft Latitude: 70°17'48.445 N +E/-W 0.00 ft Easting: 676,192.85 ft Longitude: 148°34'23.331 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 32.90 ft Wellbore 15-48C API No 500292263503 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 5/20/2011 21.63 81.00 57,658 Design 15-48C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 8,778.21 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 33.80 0.00 0.00 240.95 Survey Program Date: 5/31/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 181.65 8,778.21 1 :MWD-Standard(15-48) MWD MWD-Standard 8,850.00 11,953.00 MWD(15-48C) MWD MWD-Standard 5/31/2011 2:23:26PM Page 2 COMPASS 2003.16 Build 73 f b SAKIR p HUMUS Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 15-48 Project: Prudhoe Bay TVD Reference: 66:48 5/30/1996 17:14©66.70ft(generic drillinc Site: PB DS 15 MD Reference: 66:48 5/30/1996 17:14©66.70ft(generic drillinc Well: 15-48 North Reference: True Wellbore: 15-48C Survey Calculation Method: Minimum Curvature Design: 15-48C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (') (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 8,778.21 33.55 257.70 8,513.37 -260.33 -984.32 5,959,894.86 675,214.97 70°17'45.884 N 148°34'52.022 W TIP 8,850.00 34.11 256.95 8,573.01 -269.10 -1,023.31 5,959,885.18 675,176.20 70°17'45.797 N 148°34'53.158 W KOP 8,874.60 35.00 256.50 8,593.27 -272.31 -1,036.89 5,959,881.66 675,162.70 70°17'45.766 N 148°34'53.554 W 8,900.32 36.66 252.50 8,614.12 -276.34 -1,051.39 5,959,877.29 675,148.30 70°17'45.726 N 148°34'53.976 W 8,925.36 37.59 248.00 8,634.09 -281.45 -1,065.60 5,959,871.85 675,134.21 70°17'45.676 N 148°34'54.391 W 8,953.24 39.59 244.50 8,655.89 -288.46 -1,081.51 5,959,864.46 675,118.47 70°17'45.607 N 148°34'54.854 W 8,982.85 41.39 240.00 8,678.41 -297.42 -1,098.50 5,959,855.11 675,101.69 70°17'45.519 N 148°34'55.350 W 9,010.90 43.24 236.50 8,699.15 -307.36 -1,114.55 5,959,844.80 675,085.88 70°17'45.421 N 148°34'55.817 W 9,034.60 44.60 233.07 8,716.23 -316.84 -1,127.97 5,959,835.00 675,072.69 70°17'45.328 N 148°34'56.209 W 9,060.08 46.16 228.43 8,734.13 -328.32 -1,142.00 5,959,823.20 675,058.93 70° 17'45.215 N 148°34'56.618 W 9,080.26 46.61 225.10 8,748.05 -338.32 -1,152.64 5,959,812.95 675,048.53 70° 17'45.116 N 148°34'56.928 W 9,100.08 48.33 224.19 8,761.45 -348.72 -1,162.91 5,959,802.32 675,038.51 70° 17'45.014 N 148°34'57.227 W 9,130.97 50.42 226.85 8,781.56 -365.13 -1,179.64 5,959,785.52 675,022.17 70° 17'44.853 N 148°34'57.714 W 9,160.09 51.44 232.42 8,799.92 -379.76 -1,196.86 5,959,770.49 675,005.30 70° 17'44.709 N 148°34'58.216 W 9,190.19 54.65 235.61 8,818.02 -393.88 -1,216.32 5,959,755.92 674,986.18 70°17'44.570 N 148°34'58.783 W 9,220.46 59.19 239.26 8,834.54 -407.50 -1,237.70 5,959,741.80 674,965.13 70°17'44.436 N 148°34'59.406 W 9,250.40 62.04 236.20 8,849.23 -421.44 -1,259.74 5,959,727.36 674,943.41 70°17'44.299 N 148°35'0.049 W 9,280.58 65.28 231.64 8,862.63 -437.37 -1,281.58 5,959,710.92 674,921.96 70°17'44.142 N 148°35'0.685 W 9,306.00 66.35 227.72 8,873.05 -452.37 -1,299.25 5,959,695.50 674,904.64 70°17'43.994 N 148°35 1.200 W 9,340.95 70.97 225.83 8,885.76 -474.67 -1,322.96 5,959,672.66 674,881.46 70°17'43.775 N 148°35 1.891 W 9,370.77 74.12 229.74 8,894.71 -493.77 -1,344.03 5,959,653.07 674,860.85 70°17'43.587 N 148°35'2.505 W 9,401.85 77.88 234.43 8,902.23 -512.28 -1,367.81 5,959,634.01 674,837.51 70°17'43.405 N 148°35'3.198 W 9,427.20 81.54 236.64 8,906.76 -526.39 -1,388.38 5,959,619.42 674,817.29 70°17'43.266 N 148°35'3.797 W 9,459.74 87.02 238.48 8,910.00 -543.75 -1,415.69 5.959,601.43 674,790.39 70°17'43.096 N 148°35'4.594 W 9,489.81 89.39 241.33 8,910.94 -558.82 -1,441.69 5,959,585.76 674,764.75 70°17'42.947 N 148°35'5.351 W 9,520,73 90.37 237.68 8,911.01 -574.50 -1,468.33 5,959,569.45 674,738.49 70°17'42.793 N 148°35'6.128 W 9,554.41 92.39 235.42 8,910.20 -593.06 -1,496.42 5,959,550.24 674,710.84 70°17'42.610 N 148°35'6.946 W 9,584.72 90.86 232.32 8,909.34 -610.92 -1,520.89 5,959,531.81 674,686.80 70°17'42.435 N 148°35'7.659 W 9,615.08 90.49 229.90 8,908.98 -629.98 -1,544.51 5,959,512.21 674,663.63 70°17'42.247 N 148°35'8.348 W 9,647.10 90.49 227.21 8,908.70 -651.17 -1,568.51 5,959,490.46 674,640.14 70°17'42.039 N 148°35'9.047 W 9,677.99 89.97 225.44 8,908.58 -672.50 -1,590.85 5,959,468.61 674,618.30 70°17'41.829 N 148°35'9.698 W 9,711.15 88.31 223.70 8,909.08 -696.12 -1,614.12 5,959,444.46 674,595.60 70°17'41.597 N 148°35'10.376 W 9,740.67 88.03 221.47 8,910.02 -717.84 -1,634.08 5,959,422.27 674,576.15 70°17'41.383 N 148°35'10.958 W 9,775.98 87.79 219.21 8,911.31 -744.74 -1,656.92 5,959,394.85 674,553.95 70°17'41.118 N 148°35'11.623 W 9,805.80 88.43 217.30 8,912.29 -768.14 -1,675.38 5,959,371.03 674,536.05 70°17'40.888 N 148°35'12.161 W 9,835.36 88.25 216.82 8,913.15 -791.72 -1,693.18 5,959,347.04 674,518.80 70° 17'40.656 N 148°35'12.680 W 9,864.70 88.10 218.46 8,914.08 -814.94 -1,711.09 5,959,323.40 674,501.44 70° 17'40.428 N 148°35'13.202 W 9,895.49 88.34 220.86 8,915.04 -838.63 -1,730.73 5,959,299.26 674,482.37 70°17'40.195 N 148°35'13.774 W 9,925.47 88.37 223.66 8,915.90 -860.81 -1,750.88 5,959,276.62 674,462.74 70° 17'39.977 N 148°35'14.361 W 9,960.65 87.98 224.11 8,917.02 -886.15 -1,775.26 5,959,250.72 674,438.97 70° 17'39.727 N 148°35'15.071 W 9,990.35 88.19 224.52 8,918.01 -907.39 -1,795.99 5,959,229.00 674,418.74 70°17'39.518 N 148°35'15.675 W 10,022.00 88.62 225.37 8,918.89 -929.78 -1,818.34 5,959,206.09 674,396.92 70° 17'39.298 N 148°35'16.327 W 10,050.46 88.71 226.01 8,919.56 -949.66 -1,838.70 5,959,185.74 674,377.03 70°17'39.103 N 148°35'16.920 W 10,080.72 88.56 226.09 8,920.28 -970.65 -1,860.48 5,959,164.24 674,355.75 70°17'38.896 N 148°35'17.554 W 10,110.59 88.13 227.13 8,921.14 -991.16 -1,882.18 5,959,143.23 674,334.55 70°17'38.694 N 148°35'18.187 W 10,140.89 88.44 229.16 8,922.05 -1,011.37 -1,904.74 5,959,122.50 674,312.47 70°17'38.495 N 148°35'18.844 W 10,170.31 87.88 230.09 8,922.99 -1,030.42 -1,927.14 5,959,102.94 674,290.52 70°17'38.308 N 148°35'19.497 W 10,200.05 87.76 230.79 8,924.12 -1,049.34 -1,950.05 5,959,083.48 674,268.06 70°17'38.122 N 148°35'20.164 W 10,233.00 89.60 232.18 8,924.88 -1,069.86 -1,975.82 5,959,062.37 674,242.78 70°17'37.920 N 148°35'20.915 W 10,260.50 89.57 232.02 8,925.08 -1,086.75 -1,997.52 5,959,044.97 674,221.48 70°17'37.754 N 148°35'21.548 W 10,291.82 87.85 232.94 8,925.79 -1,105.82 -2,022.35 5,959,025.33 674,197.10 70°17'37.566 N 148°35'22.271 W 10,320.47 88.49 234.23 8,926.70 -1,122.82 -2,045.40 5,959,007.80 674,174.47 70°17'37.399 N 148°35'22.943 W 10,353.79 88.25 234.46 8,927.65 -1,142.23 -2,072.46 5,958,987.75 674,147.87 70° 17'37.208 N 148°35'23.731 W 5/31/2011 2:23:26PM Page 3 COMPASS 2003.16 Build 73 WPAI b BAKER HUGHts Survey Report-Geographic0 INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 15-48 Project: Prudhoe Bay TVD Reference: 66:48 5/30/1996 17:14©66.70ft(generic drillinc Site: PB DS 15 MD Reference: 66:48 5/30/1996 17:14©66.70ft(generic drillinc Well: 15-48 North Reference: True Wellbore: 15-48C Survey Calculation Method: Minimum Curvature Design: 15-48C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (^) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,382.93 88.65 236.91 8,928.44 -1,158.65 -2,096.52 5,958,970.78 674,124.20 70°17'37.046 N 148°35'24.432 W 10,426.96 88.74 236.89 8,929.44 -1,182.69 -2,133.39 5,958,945.88 674,087.91 70°17'36.810 N 148°35'25.507 W 10,467.98 88.43 237.41 8,930.45 -1,204.93 -2,167.84 5,958,922.84 674,053.99 70°17'36.591 N 148°35'26.510 W 10,500.88 88.00 236.93 8,931.48 -1,222.76 -2,195.48 5,958,904.37 674,026.78 70°17'36.416 N 148°35'27.316 W 10,529.95 87.88 237.88 8,932.52 -1,238.41 -2,219.95 5,958,888.15 674,002.68 70°17'36.262 N 148°35'28.029 W 10,559.97 87.30 238.81 8,933.79 -1,254.15 -2,245.48 5,958,871.82 673,977.53 70° 17'36.107 N 148°35'28.773 W 10,589.19 86.78 237.87 8,935.29 -1,269.47 -2,270.32 5,958,855.92 673,953.06 70°17'35.956 N 148°35'29.496 W 10,631.50 86.93 239.01 8,937.62 -1,291.58 -2,306.32 5,958,832.97 673,917.59 70°17'35.738 N 148°35'30.545 W 10,661.86 88.07 239.15 8,938.94 -1,307.16 -2,332.34 5,958,816.78 673,891.95 70°17'35.585 N 148°35'31.303 W 10,693.66 88.31 238.40 8,939.94 -1,323.64 -2,359.52 5,958,799.68 673,865.16 70°17'35.423 N 148°35'32.095 W 10,724.85 86.71 236.47 8,941.30 -1,340.41 -2,385.78 5,958,782.30 673,839.31 70°17'35.258 N 148°35'32.861 W 10,753.59 87.79 236.03 8,942.68 -1,356.36 -2,409.64 5,958,765.79 673,815.82 70° 17'35.101 N 148°35'33.556 W 10,782.85 86.62 237.71 8,944.11 -1,372.33 -2,434.12 5,958,749.25 673,791.73 70°17'34.944 N 148°35'34.269 W 10,811.68 85.91 236.42 8,945.98 -1,387.97 -2,458.26 5,958,733.05 673,767.96 70°17'34.790 N 148°35'34.973 W 10,843.08 85.08 236.71 8,948.45 -1,405.22 -2,484.38 5,958,715.20 673,742.25 70°17'34.620 N 148°35'35.734 W 10,871.04 84.93 238.10 8,950.88 -1,420.22 -2,507.85 5,958,699.65 673,719.14 70°17'34.473 N 148°35'36.417 W 10,899.06 86.13 238.63 8,953.07 -1,434.88 -2,531.63 5,958,684.44 673,695.71 70°17'34.328 N 148°35'37.110 W 10,930.91 85.49 239.79 8,955.40 -1,451.14 -2,558.92 5,958,667.55 673,668.82 70°17'34.168 N 148°35'37.905 W 10,958.55 85.69 239.35 8,957.52 -1,465.09 -2,582.68 5,958,653.04 673,645.39 70°17'34.031 N 148°35'38.598 W 10,988.81 85.70 240.67 8,959.79 -1,480.18 -2,608.82 5,958,637.35 673,619.62 70'17'33.883 N 148°35'39.359 W 11,018.48 85.18 239.86 8,962.15 -1,494.84 -2,634.50 5,958,622.08 673,594.29 70°17'33.738 N 148°35'40.108 W 11,050.06 85.47 241.12 8,964.73 -1,510.35 -2,661.89 5,958,605.94 673,567.27 70°17'33.586 N 148°35'40.906 W 11,081.12 85.55 241.18 8,967.16 -1,525.29 -2,689.01 5,958,590.37 673,540.51 70°17'33.439 N 148°35'41.696 W 11,113.25 85.66 240.97 8,969.62 -1,540.78 -2,717.05 5,958,574.23 673,512.84 70°17'33.286 N 148°35'42.513 W 11,141.55 85.82 241.35 8,971.72 -1,554.40 -2,741.77 5,958,560.04 673,488.45 70°17'33.152 N 148°35'43.233 W 11,170.97 85.82 242.82 8,973.87 -1,568.13 -2,767.70 5,958,545.70 673,462.85 70°17'33.017 N 148°35'43.989 W 11,200.57 85.42 242.63 8 976.13 -1,581.66 -2,793.93 5,958,531.56 673,436.95 70°17'32.884 N 148°35'44.753 W 11,231.02 85.45 244.13 8,978.55 -1,595.26 -2,821.07 5,958,517.33 673,410.14 70°17'32.750 N 148°35'45.544 W 11,259.04 85.21 244.30 8,980.83 -1,607.41 -2,846.21 5,958,504.60 673,385.29 70°17'32.630 N 148°35'46.276 W 11,282.04 86.25 244.53 8,982.54 -1,617.31 -2,866.90 5,958,494.21 673,364.84 70°17'32.533 N 148°35'46.879 W 11,312.61 87.70 244.50 8,984.16 -1,630.45 -2,894.46 5,958,480.43 673,337.60 70°17'32.404 N 148°35'47.682 W 11,346.45 91.29 244.61 8,984.46 -1,644.98 -2,925.01 5,958,465.19 673,307.40 70°17'32.261 N 148°35'48.572 W 11,380.91 90.55 245.51 8,983.90 -1,659.51 -2,956.25 5,958,449.93 673,276.51 70°17'32.118 N 148°35'49.482 W 11,412.22 90.58 244.27 8,983.59 -1,672.80 -2,984.60 5,958,435.99 673,248.48 70°17'31.987 N 148°35'50.308 W 11,444.90 91.69 243.85 8,982.95 -1,687.09 -3,013.98 5,958,421.01 673,219.44 70°17'31.846 N 148°35'51.164 W 11,470.86 92.40 242.74 8,982.02 -1,698.75 -3,037.15 5,958,408.81 673,196.55 70°17'31.731 N 148°35'51.840 W 11,500.54 92.18 242.44 8,980.83 -1,712.40 -3,063.48 5,958,394.55 673,170.55 70°17'31.597 N 148°35'52.607 W 11,533.01 92.39 241.99 8,979.54 -1,727.52 -3,092.18 5,958,378.75 673,142.21 70°17'31.448 N 148°35'53.443 W 11,560.29 92.70 241.86 8,978.33 -1,740.35 -3,116.23 5,958,365.37 673,118.48 70°17'31.322 N 148°35'54.144 W 11,591.55 92.64 241.94 8,976.87 -1,755.06 -3,143.78 5,958,350.02 673,091.28 70°17'31.177 N 148°35'54.946 W 11,620.34 92.46 241.52 8,975.59 -1,768.68 -3,169.11 5,958,335.81 673,066.28 70°17'31.043 N 148°35'55.684 W 11,651.40 92.64 241.76 8,974.21 -1,783.42 -3,196.41 5,958,320.44 673,039.33 70°17'30.898 N 148°35'56.480 W 11,679.16 93.47 241.25 8,972.73 -1,796.64 -3,220.77 5,958,306.64 673,015.29 70°17'30.768 N 148°35'57.189 W 11,711.21 93.19 240.93 8,970.87 -1,812.11 -3,248.78 5,958,290.52 672,987.65 70°17'30.616 N 148°35'58.005 W 11,743.33 93.26 240.78 8,969.06 -1,827.73 -3,276.79 5,958,274.25 672,960.02 70° 17'30.462 N 148°35'58.821 W 11,771.65 93.78 242.50 8,967.32 -1,841.16 -3,301.67 5,958,260.25 672,935.47 70°17'30.330 N 148°35'59.546 W 11,809.02 93.20 241.91 8,965.05 -1,858.55 -3,334.66 5,958,242.09 672,902.89 70°17'30.159 N 148°36'0.507 W 11,840.30 93.41 242.40 8,963.24 -1,873.14 -3,362.27 5,958,226.86 672,875.63 70°17'30.015 N 148°36'1.312 W 11,872.40 93.17 242.96 8,961.40 -1,887.84 -3,390.75 5,958,211.49 672,847.51 70°17'29.870 N 148°36'2.141 W 11,907.38 93.93 244.19 8,959.24 -1,903.38 -3,422.01 5,958,195.23 672,816.62 70°17'29.717 N 148°36'3.052 W 11,953.00 93.93 244.19 8,956.11 -1,923.20 -3,462.98 5,958,174.46 672,776.13 70°17'29.522 N 148°36'4.246 W TD 5/31/2011 2:23:26PM Page 4 COMPASS 2003.16 Build 73 TREE= 4-1/16"CIW 5 48 C SAFE1 1ES: WELL ANGLE>70'@ 9341'***3-1/2" WELLHEAD= FMC 1 CHROME LNR*** ORIGINAL,"A"&"B"WELLBORE'S ACTUATOR= BAKER C NOT SHOWN BELOW WS @ 8850'*** KB. ELEV 66.7' PJC DRAFT BF.ELEV= _? KOP= 6548' 20"CONDUCTOR H ? 1) 2184' -14-1/2"HES HXO SSSV NIP, ID=3.813" Max Angle= 94'@ 11772' I 1 Datum MD= 9290' Datum TVD= 8800'SS X X GAS LIFT MANDRELS 9-5/8"CSG,40#, L-80,BTC-M, ID=8.835" H 3461' K ® ST MD WD DEV TYPE VLV LATCH PORT DATE 9-5/8"CSG,47#,L-80,NSCC, ID=8.681" H 3548' 1 3677 3675 1 KGB2-LS DOME INT 16 06/12/11 2 6288 6284 5 KGB2-LS *DMY INT 0 07/20/03 .4-1 3.70"BOT DEPOY SLV,ID=3.000" - 3901' 3 8237 8059 34 KGB2-LS *DMY INT 0 03/10/96 ALL MANDRELS REQUIRE A MODIFIED LATCH 45 KB LNR TOP PKR,10_7 2.450" H 3907' *STA'S#2&#3=DMY GLVS BEHIND PIPE Minimum ID = 2.375" @ 8774' z-___-- 6660' -TUBING HOLE BEHIND 3" SEAL STINGER wI NO-GO [ r 6795' -I TUBING HOLE PIPE 8306' -7"X 4-1/2"BKR S-3 PKR,ID=3.875" 7"CSG, 26#,L-80 BTC-M, .0383 bpf, ID=6.276" H 8139' I-x X Z 8329' H4-1/2"HES X NIP, ID=3.813" BEHIND PIPE lin 8341' -4-1/2"HES WLEG, ID=3.958" iiii 4-1/2"TBG, 12.6#,L-80 BTM, -I 8341' 8341' H 7"X 4-1/2"TIW LTP w/7.35"TBR, ID=5.249" .0152 bpf, ID=3.958" ,` 8352' H 7"X 4-1/2"TIW LNR HYDRO HGR, ID=3.915" 7"CSG,29#,L-80 BTC-M, .0371 bpf, ID=6.184" - 8554' 4 8774' -{3'SEAL STINGER w/NO-GO, ID=2.375" 3-1/2 LNR,9.2#, 13CR-80 STL, .0087 bpf, ID=2.992" -- 8773' 8774' H 3.70"DEPLOY SLV v.'/4.5"KB LTP, ID=3.00" 8810'n H 3.70"BTT GEN 2 DEPLOY SLV,ID=3.00" �,e 8806' -ESTIMATED TOC 3-1/2 LNR,9.3#,L-80 STL, .0087 bpf, ID=2.992' 1H 8832' I- I 8832' H 3-1/2"X 3-3/16"XO,ID=2.786" MILLOUT WINDOW(15-48C) 8852'-8859' 4-1/2"WHIPSTOCK(TAGGED 05/22/11)1- 8850' 4-1/2"LNR, 12.64, L-80 NSCT, .0152 bpf, ID=3.958" 1-i -8859 9510' 737-6772-7/3"2-718"XO, ID=2.377" PERFORATION SUMMARY ` REF LOG:MWD/GR/ ON 5/29/11 ` ANGLE AT TOP PERF: 89'@ 10220' Note: Refer to Production DB for historical perf data l ` SIZE SPF INTERVAL Opn/Sqz DATE I ` 2" 6 10220-10270 0 06/01/11 2" 6 10430-10770 0 06/01/114116. 2" 6 10810-10900 0 06/01'11 3-3/16"LNR,6.24,L-80 TC11. 9510' 2" 6 11100-11170 0 06/01/11 0076 bpf, ID=2.80" 2" 6 11210-11400 0 06/01/11 2" 6 11490-11560 0 06/01/11 PBTD -I 11908' 2" 6 11650-11790 0 06/01/11 �r 2" 6 11850-11900 0 06/01/11 2-718"LNR,6.164. L-80 STL. .0058 bpf. ID=2.441" H 11946' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION i WELL: 15-48C 02/23103 JLM/KK CTD SIDETRACK(15-48A) PERMIT No: 2110300 11/26/05 NORDIC 1 CTD SIDETRACK(15-48B) API No: 50-029-22635-03 06/05/11 NORDIC 2 CTD SIDETRACK(15-48C) SEC 22. T11 N,R14E-, 1309'FNL&259'FWL 06/15/11 ALH/PJC GLV CIO(6/12/11) 06/27/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) OPfRABLE: Producer 15-48C (PTD #1110300) Sustained Casing Pressure on IA Page 1 of 2 • Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator@bp.com] ' Il C.l I( Sent: Tuesday, July 19, 2011 7:51 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan Cc: Walker, Greg (D&C); Clingingsmith, Mike J (Swift); Grey, Leighton (CH2M Hill); Lee, Timothy; Reynolds, Charles (ALASKA) Subject: OPERABLE: Producer 15-48C (PTD#2110300) Sustained Casing Pressure on the IA All, Producer 15-48C (PTD#2110300) passed an MIT-IA to 3000 psi on 07/18/2011 after dummy gas lift valves were set. The passing test verifies two competent barrieris and the well is being reclassified as Operable. Please be cautious of annular fluid expansion as the IA is liquid packed. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday,July 17,2011 11:55 AM To: 'Maunder,Thomas E(DOA)'; 'Regg,James B(DOA)';'Schwartz,Guy L(DOA)';AK,OPS FS3 OSM;AK,OPS FS3 DS Ops Lead;AK, OPS FS3 DS Operators;AK,OPS PCC EOC TL;AK,RES GPB East Wells Opt Engr;Cismoski, Doug A;AK,D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Daniel,Ryan Cc: Walker,Greg(D&C);Clingingsmith,Mike J(Swift);Grey,Leighton(CH2M Hill); Lee,Timothy; Reynolds,Charles(ALASKA) Subject: UNDER EVALUATION: Producer 15-48C(PTD#2110300)Sustained Casing Pressure on the IA All, Producer 15-48C (PTD#2110300) has confirmed sustained casing pressure above MOASP on the IA. The wellhead pressures were tubing/IA/OA equal to 2120/2120/20 on 07/14/2011. A TIFL failed on 07/16/2011 confirming TxIA communication. The well has been reclassified as Under Evaluation and may be produced while work is conducted to restore integrity. The plan forward is: 1. DHD: TIFL - FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi A wellbore schematic and TIO plot have been included for reference. « File: 15-48C.pdf» « File: 15-48C TIO Plot 07-17-11.doc» Thank you, 7/19/2011 OPiERABLE: Producer 15-48C (PTD #'''110300) Sustained Casing Pressure on*'-Q IA Page 2 of 2 Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator@BP.com 7/19/2011 ALDER EVALUATION: Producer 15- "SC (PTD#2110300) Sustained Casing pressure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIlntegrityCoordinator@bp.com] ` 45( 4 Sent: Sunday, July 17, 2011 11:55 AM 1 Z To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, OPS PCC EOC TL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan Cc: Walker, Greg (D&C); Clingingsmith, Mike J (Swift); Grey, Leighton (CH2M Hill); Lee, Timothy; Reynolds, Charles (ALASKA) Subject: UNDER EVALUATION: Producer 15-48C (PTD#2110300) Sustained Casing Pressure on the IA Attachments: 15-48C.pdf; 15-48C TIO Plot 07-17-11.doc All, Producer 15-48C (PTD#2110300) has confirmed sustained casing pressure above MOASP on the IA. The wellhead pressures were tubing/IA/OA equal to 2120/2120/20 on 07/14/2011. A TIFL failed on 07/16/2011 confirming TxIA communication. The well has been reclassified as Under Evaluation and may be produced while work is conducted to restore integrity. The plan forward is: 1. DHD: TIFL - FAILED 2. Slickline: Set dummy gas lift valves, MITIA to 3000 psi z ci /1/4- (Q A wellbore schematic and TIO plot have been included for reference. ,vc-fice OIL_ per «15-48C.pdf» «15-48C TIO Plot 07-17-11.doc» Thank you, (-04,1 Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator@BP.com 7/18/2011 a o, ao n <o o C ig0000 ill 11111 4: I f o - :!: o 1 ui 0.1 QC C 7. C 8 W e C T 3 0 InN O C N 11Ci 0 dilliPO :O G tM O O ^1 M a a 6) li IU oM 1" + 00 0 y + .^1 `—1 ,-4 Q) 0 0 0 0 `r I (y Q 6 C M fV r, `• It N a 4 .. FREE= 4-1/16"CIW SAFETY SWELL ANGLE 70 : N ° WELLHEAD= FMC 'I 5-48C 4 Q CHROMELNR*** @ 9341'***3E'S ORIGINAL,"A"&"B"WELLBORFS ACTUATOR= BAKER C /`a DRAFT/� FT NOT SHOWN BELOW WS @ 8850'*** KB.EL EV = 66.7' F'JG BF.ELEV =. KOP= 6548' 20"CONDUCTOR -) ? 2184' -4-1/2"HES HXO SSSV NIP, ID=3.813" Max Angle= 94°@ 11772' Datum MD= 9290' Datum TV D= 8800'SS X X GAS LIFT MANDRELS 9-5/8"CSG,40#, L-80,BTC-M, ID=8.835" - 3461' ' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3677 3675 1 KGB2-LS DOME INT 16 06/12/11 9-5/8"CSG,47#,L-80,NSCC, ID=8.681" --1 3548' 2 6288 6284 5 KGB2-LS *DMY INT 0 07/20/03 3.70"BOT DEPOY SLV, ID=3.000" -1 3901' I I 3 8237 8059 34 KGB2-LS *DMY INT 0 03/10/96 ALL MANDRELS REQUIRE A MODIFIED LATCH 45 KB LNR TOP PKR, ID=2.450" --I 3907' 2 *STA'S#2&#3=DM Y GLVS BEHIND PIPE Minimum ID = 2.375" @ 8774' r . 6660' -TUBING HOLE BEHIND 3" SEAL STINGER w/ NO-GO L `' 6795' I-TUBING HOLE PIPE 8306' -17"X 4-1/2"BKR S-3 PKR, ID=3.875" 7"CSG,264,L-80 BTC-M, .0383 bpf, ID=6,2/6" - 8139' X Z , 8329' '14-1/2"HES X NIP,ID=3.813" BEHIND PIPE ' 8341' -14-1/2"HES WLEG.ID=3.958" PI 4-1/2"TBG, 12.6#,L-80 BTM, - 8341' 8341' --l7"X 4-1/2"TM/LTPw/7.35"TBR, ID=5.249" .0152 bpf, ID=3.958" 8352' -17"X 4-1/2"TIW LNR HYDRO HGR,ID=3.915" 7"CSG,29#,L-80 BTC-M, .0371 bpf,ID=6.184" - 8554' 1 8774' -13'SEAL STINGER w/NO-GO, ID=2.375" 3-1/2 LNR,9.2#, 13CR-80 STL, .0087 bpf,ID=2.992" - 8773' g 8774' -13.70"DEPLOY SLV w/4.5"KB LTP, ID=3.00" 8810'?? -13,70'8 FT GEN 2 DEPLOY SLV, ID= 3.00" '4 8806' - ESTIMATED TOC 3-1/2 LNR,9.3#,L-80 STL,.0087 bpf, ID=2.992" - 8832' J---- 8832' -13-1/2"X 3-3/16"XO. ID=2.786" + MILLOUT WINDOW(15-48C) 8852'-8859' 4-1/2"WHIPSTOCK(TAGGED 05/22/11) -1 8850' LWT` 9510' -3-3/16"X 2-7/8"XO, ID=2.377" 4-1/2"LNR, 12.6#, L-80 NSCT, .0152 bpf, ID=3.958" -1 -8859 r w; '�,, PERFORATION SUMMARY ` REF LOG: MWD!GR/ ON 5/29/11 ANGLE AT TOP PERF: 89°@ 10220' Note: Refer to Production DB for historical perf data ` SIZE SPF INTERVAL Opn/Sqz DATE I ` 2" 6 10220-10270 0 06/01/11 ` 2" 6 10430-10770 0 06/01/11 3-3/16"LNR,6.24,L-80 TC11, 9510' 2" 6 10810-10900 0 06/01/11 ` 2" 6 11100-11170 0 06/01/11 .0076 bpf, ID=2.80" 2" 6 11210-11400 0 06/01/11 ` 2" 6 11490-11560 0 06/01/11 PBTD 11908' 2" 6 11650-11790 0 06/01/11 Vii' 2" 6 11850-11900 0 06/01/11 2-7/8"LNR,6.16#.L-80 STL,.0058 bpf,ID=2.441" -1 11946' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION WELL: 15-48C 02/23/03 JLM/KK CTD SIDETRACK(15-48A) PERMIT No: '2110300 11/26/05 NORDIC 1 CTD SIDETRACK(15-48B) API No: 50-029-22635-03 06/05/11 NORDIC 2 CTD SIDETRACK(15-48C) SEC 22,T11 N.R14E, 1309'FNL&259'FWL 06/15/11 ALH/PJC GLV C/O(6/12/11) 06/27/11 PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) /,i \ SEAN PARNELL,GOVERNOR 0 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-48C BP Exploration (Alaska), Inc. Permit No: 211-030 Surface Location: 3971' FSL, 5021' FEL, SEC. 22, T11N, R14E, UM Bottomhole Location: 1990' FSL, 3315' FEL, SEC. 21, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, '40? Daniel T. Seamount, Jr. Chair DATED this 1 day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) 1113.0G1 VGita STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMP 'ION FEB 2 8 2011 /i - PERMIT TO DRILL 20 MC 25.005 Alaska Oil&Gas Cons.Commission la.Type of work: 1 b.Proposed Well Class: Z Development Oil 0 Service-Winj 0 Single Zone ilc. Specify ifhigJl psed for: ❑ Drill IR Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU 15-48C 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12090' TVD 8882'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028306 3971'FSL,5021'FEL,SEC.22,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3649'FSL,984'FEL, SEC.21,T11N, R14E, UM April 15,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1990'FSL,3315'FEL,SEC.21,T11N, R14E, UM 2560 26,200' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 66.7' feet 15.Distance to Nearest Well Open Surface: x- 676193 y-5960178 Zone- ASP4 GL Elevation above MSL: 32.9' feet to Same Pool: 700' 16.Deviated Wells: Kickoff Depth: 8880' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 3341 Surface: 2461 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD , MD ND (including stage data) 4-1/8" 3-3/16"x 2-7/8" 6.5#/6.2# L-80 TCII/STL 3260' 8830' •8556'ss, 12090',8882'ss 165 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 11646' 893g' None 11506' 8934' None Casing Length Size Cement Volume MD ND Conductor/Structural 114' 20" 260 sx Arcticset(Aoorox.) 114' 114' Surface 3514' 9-5/8" 995 sx CS III.305 sx'G'. 187 sx CS II 3548' 3546' Intermediate 8522' 7" 235 sx Class'G' 8554' 8324' Production Liner 854' 4-1/2" 316 sx Class'G' 8341'-9195' . 8146'-8844' Liner 2663' 3-1/2"x 3-3/16"x 2-7/8" 158 sx Class'G' ::7•'-11 . •T- :• ' .., •i-r :. ' 1 " 1 ,1 .1 c,• m - , 1 1'- •• ' ,11 • ' r 3 3•L •!/ Perforation Depth MD(ft): 10820'-11500' Perforation Depth TV (ft): 8923'-8934' 20.Attachments: 0 Property Plat IN BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mark Staudinger,564-5733 Printed Name Joh/ c,',A % 4/ Title Engineering Team Leader Prepared By Name/Number Signature i lirPhone 564-4711 Date 2A5---A/( Terre Hubble,564-4628 Commission Use Only Permit T. Drill API Number: Permit A rov Date: See cover letter for Number: _ f/Q3O 50-029-22635-03-00 311 I f I other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: V Soo dos i. ,BO r° Ts'— Other: _ r Samples Req'd: ❑Yes R/No Mud Log Req'd: 0 Yes �No - 2S-60 rsb 4n n -t (e . � 2S Measures: "Yes 0 No Directional Survey Req'd: [> 'Yes 0 No / ? / APPROVED BY THE COMMISSION / r Date �� ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 month's from the date of approval(20 AAC25.005(g)) Submit In Duplicate ORIGINAL & 3-Z-" ,,00. "A To: Alaska Oil &Gas Conservation Commission From: Mark Staudinger CTD Engineer 0 b ID Date: February 22"d, 2010 Re: 15-48C PTD Request Approval is requested for a permit to drill a CTD sidetrack from well 15-48B. Well 15-48B is a coil sidetrack drilled in Nov 2005. The well was completed with a 620' of perforations in Zone 1A. The 3-1/2" liner top was extended up to 4010' MD to cover known tubing holes at 6660' and 6795' MD and restore integrity. The well came on and remained fulltime until June 2006 when it hit LP MGOR. The well was then swapped to HP service and cycled near/at MGOR. In July 2009, 175' of perforations were added in Zone 1A. There was a small oil buzz, but the well was shut-in for high GOR within weeks. After being shut-in for a year, 15-48B was POP'ed in Oct 2010 and quickly reached max GOR. The well is currently shut-in. Reason for Sidetrack: 15-488 is no longer a competitive producer, and there are no remaining wellwork options. . The proposed sidetrack will access a-50-acre target in southwest DS 15. The well is in sound mechanical condition. It passed an MIT-IA to 3000 psi (December 2010) and the MIT-OA passed to 2000 psi (December 2010). A tubing calliper was ran (December 2010) from 3,677' to surface and found the tubing to be in good to fair condition with a maximum recorded wall penetration of 39%. A tubing patch was ran during a CTD sidetrack in November 2005 to patch holes in the 4-1/2" tubing at 6660' and 6795'. The tubing patch consists of 3-1/2", 8.81#, 13Cr-80, STL from 8876' to 4010' MD. The sidetrack, 15-48C, is scheduled to be drilled by Nordic 2 starting on April 15th, 2011 targeting Ivishak Zone' 1A/1B. The pre rig work includes pulling the LTP from the scab liner. The coiled tubing drilling rig Nordic 2 will then pull the 3-1/2" scab liner and set a 4-1/2" packer whipstock at 8,860' and to allow a kick off in Zone 3. The window will be milled, and the rig will then land and drill 3230 ft of Zn 1A/1 B lateral via 12 DLS. The well will be completed with 3-3/16" x 2-7/8" solid, cemented, and perforated liner. Finally, the 3-1/2" scab liner will be re-run. ' The following describes the planned work. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summary Pre-CT Rig Work: The pre CTD work is planned to begin March 10th, 2011. 1. W Check tubing hanger LDS. 2. W PPPOT-T to 5000 psi 3. S Dummy off GLM 4. D MIT-IA to 3000 psi, MIT-OA to 2000 psi. 5. S Drift and pull LTP. 6. V PT tree(MV,SV,WV) 7. D Bleed wellhead pressures down to zero. 8. D Bleed production flow lines and GL lines down to zero and blind flange. 9. 0 Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on April 15th, 2011 using Nordic Rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test 3. Pull Scab Liner 4. Drift and Caliper Tubing 5. Set 4'/z" packer whipstock. 6. Mill 3.80"single string high side window in the 4'/z" liner at 8860'. 7. Drill 12 DLS lateral sidetrack with 4-1/8" bi-center bit in Zone 1A/1B to a final TD of 12,090' md. 8. Run and cement 3-3/16"x 2-7/8" L-80 liner leaving TOL/TOC-30' inside window. 9. Perform cleanout/log run with mill, motor, and MCNL .�-t•s 10. Perforate well. �+ 11. Run Liner Top Packer. 12. Re-run Scab Liner and packer. 13. Freeze protect well to 2200'TVD. 14. Set BPV. ND 7-1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 15. RDMO Nordic 2. Post-Rig Work: 1. Re-install S-riser, wellhouse and FL's 2. Pull BPV. 3. Install GLV. 4. RU PBGL. 5. RU test separator. Mud Program: • Well kill: 8.6 ppg seawater/brine. • • Milling/drilling: 8.6 ppg Geo-VIS for milling window and drilling. Disposal: • All Class II drilling and completion fluids and all other Class II wastes will go to Grind & Inject at DS 4. • All Class I wastes will go to Pad 3 for disposal. • Hole sizes: 4-1/8" 8860' and- 12,090' and Casing Program: Solid, cemented, and perforated completion. • 2-7/8", L-80, 6.5 lb/ft STL liner 9,500' and- 12,090' and • 3-3/16", L-80, 6.2 lb/ft TC-II liner 8,830' and-9,500' and • Planned 34 bbls of 15.8 class G cement will be used for liner cementing (assuming 4-1/8" hole size to TD and 20% excess in open hole). • TOC planned at 8830' MD. • Plan on running a liner top packer. • 3-1/2", 13Cr-80, 9.2 lb/ft STL Scab Liner 4,010' and-8,830' and' • Plan on running a liner top packer above scab liner. ' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 93°, inclination at kick off point is 34°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property-26,200' and (South). • Distance to nearest well within pool-700'from 15-02B. Anti-Collision • 15-01 B WP04 Extention 172' (ctr—ctr distance) Status: Plan for extension. Never Drilled. • 15-48A 32' (ctr—ctr distance) Status: Plugged and Abandoned. • 15-48B 45' (ctr—ctr distance) Status: Plugged and Abandoned. Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section while drilling. • Cased hole GR/CCUMCNL logs will be run. Hazards • DS 15 is not considered an H2S drill site. There are no producers on DS 15 or C-Pad with current H2S ' readings greater than 100 ppm. • The maximum recorded H2S level on DS 15 was 30 ppm on well 15-05A(November 2010). • Most recent H2S level on 15-486 is 20 ppm recorded on October 25th, 2010. • The lost circulation risk in the 15-48C is considered to be low and no fault crossing is planned. Reservoir Pressure • The max reservoir pressure is estimated to be 3,341 psi at 8,800 TVDss (7.3 ppg equivalent) based on average offset pressures. • Max expected surface pressure with gas(0.10 psi/ft)to surface is 2,461 psi. Mark Staudinger Coiled Tubing Drilling Engineer 564-5733 CC: Well File Sondra Stewman/Elizabeth Barker/Terrie Hubble TREE= CM/ = FMC � � �� B Sr�'�'Y NOTES: WELL ANGLE>70°@ 9200'***3- WELACTLHEAD LHEAD= BAKER C - 1, ,ROME LNR ORIGINAL WELLBORE& KB ELEV 66.T 15-48A NOT SHOWN BELOW XO @ 9418'*** BF.ELEV= KOP= 9495' Max Angle= 96 @ 10807' Datum MD= 9233' 2184' -14-1/2"HES HXO SVLN SSSV NIP, ID=3.813" I Datum TVD= 8800'SS 9-5/8"CSG,40#,L-80,BTC-M XO NSCC H 3461' 1.--- 9-5/8"CSG,40#,L-80,NSCC, ID=8.835" - 3548' GAS LIFT MANDRELS _ ST MD TVD DEV TYPE VLV LATCH PORT DATE 1* 3677 3675 1 KGB2-LS DMY INT 0 12/11/10 BKR KB LTP&SEAL STINGER w/LOC,ID=2.350" - 4010' re 2* 6288 6284 5 KGB2-LS DMY** INT 0 07/20/03 3* 8237 8059 34 KGB2-LS DMY** INT 0 03/10/96 3.70"BOT LNR DEPOY SLV,ID=3.000" - 4017' * MANDRELS REQUIRE MODIFIED LATCH ii ** BEHIND PIPE 3.70" X 3-1/2"XO,ID=2.990" - 4022' Minimum ID =2.35" @ 4010' BKR KB LTP & SEAL STINGER w/LOC Z 8306' -7"X 4-1/2"BKR S-3 PKR,ID=3.875" 8329' H 4-1/2"HES X NIP,ID=3.813" 7"CSG,26#,L-80,BTC-M,X0 29#,L-80,BTC-M -I 8139' I-x I I x BEHIND PIPE 4-1/2"TBG, 12.6#,L-80,NSCT, - 8341' _ >9 8341' 1 7"X 4-1/2"TNN LNR PKR .0152 bpf, ID=3.958" &HYDRO HGR,ID=3.915" 7"CSG,29#, L-80,BTC-M,ID=6.059" -I 8554' I---, t , 8874' 1 3-1/2"X 2-7/8"XO,ID=2.370" I 3-1/2 LNR,9.2#,13CR-80,STL,.0087 bpf,ID=2.992" - 8874' I-- / J 8876' -2-7/8"SEAL ASSY, ID=2.360" 8879' -3.7"LNR SLV&BKR HYDRO SET -' = RETRIEVABLE PKR, ID=2.560" ESTIMATED TOP OF CEMENT 8884' r 4 • 8889' -BOT 3"SEAL STINGER& • • LNR DEPLOY SLV,ID=2.355" 4 • i i 8910' H3-1/2"HOWCO X NIP,ID=2.813" I 3-1/2"LNR,8.81#,L-80,STL,.0087 bpf,ID=2.867" 8942' 4, • 44 j� 8942' -13-1/2"X 3-3/16"XO, ID=2.786" WHIPSTOCK(11/15/05) -I 9195' I i &� ,`. MILLOUT WINDOW(15-48B) 9195'-9203' RA PIP TAG -I 9204' i•` N. PERFORATION SUMMARY I ■ REF LOG:MWD/GR/ ON 11/15/05 P '1 ANGLE AT TOP PERF: 64°@ 9250' • 1. 1 . 9390' - 3-3/16"X 2-7/8"X0, Note:Refer to Production DB for historical perf data *1 •• ID=2.377" SIZE SPF INTERVAL Opn/Sqz DATE 1•1 �1 2" 6 9250-9300 0 07/16/09 2" 6 9410-9485 0 07/16/09 3-3/16"LNR,6.2#,L-80,TC-II, H 9390' I ` 2" 6 9550-9600 0 07/16/09 .0076 bpf,ID=2.80" 2" 6 10820-11200 0 11/25/05 2" 6 11230-11450 0 11/25/05 ` 11506' -I PBTD 2" 6 11480- 11500 0 11/25/05 2-7/8"LNR,6.16#,L-80,STL, .0058 bpf,ID=2.441" H 11542' TD - 11646' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28/96 ORIGINAL COMPLETION 07/26/09 TTR/PJC PERFS(07/16/09) WELL: 15-48B 02/23/03 JLM/KK CTD SIDETRACK(15-48A) 09/28/09 JLJ/SV GLV C/O(08/06/09) PERMIT No: 2051660 11/26/05 NORDIC 1 CTD SIDETRACK(15-48B) 12/11/10 AH/PJC GLV C/O API No: 50-029-22635-01 11/29/05 KSB/TLH GLV C/O SEC 22,T11N,R14E,2967.84'FEL&1006.73'FNL 04/03/07 KSB/PJC DRLG DRAFT CORRECTIONS 04/29/07 NS/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) WELLHEAD= ACTUATOR= BAKER CI 1548C 11/WIROME LNR** ORIGINAL WELLBORE&'3 RB—EL—EV= 66.7' Proposed CTD Sidetrack 15-48A NOT SHOWN BELOW XO 6)9418'••• BF.ELEv= — —? note: failed PPPOT-T - KOP= 9495' Max Angle=►6 @ 10807 TxIA comm thru holes in tuoii Datum MD= 9233' 2184' -4-1/2"HES HXO SV LN SSSV NIP, ID=3.813" Datum TVD= 8800'SS O 9-5/8"CSG,40#,L-80 BTC-M XO NSCC H 3461' I— V 9-5/8"CSG,40#, L-80,NSCC, ID=8.835" -I 3648' ST MD GAS LIFT MANDRELS _ TVD DEV TYPE VLV LATCH FORT DATE 1''3677 3675 1 KGB2-LS CMY INT 0 12/11/10 2* 6288 6284 5 KGB2-LS DMY" INT 0 07/20/03 BKR KB LTP&SEAL STINGER w/LOC, ID=2.250" -L 4010' 3' 8237 8059 34 KGB2-LS DMY" INT 0 03/10/96 1111K.4 PM * 3.70"BOT LNR DEPOY SLV, ID=3.000" H 4017' MANDRELS REQUIRE MODIFIED LATCH " BEHIND PIPE 0 hole 6660' MD ..-- hole 6795' MD Minimum ID =2.35" @ 4010' BKR KB LTP & SEAL STINGER w/LOC ►Z It.:41 8306' H7"x 4-1/2"BKR S-3 PKR,ID=3.875" 8329' H4-1/2"HES X NIP,ID=3.813" 7"CSG,26#,L-80, BTC-M,XO 29#, L-80, BTC-M H 8139' H I BEHIND PIPE 4-12"TBG, 12.6#, L-80, NSCT, -L 8341' I it,'" I. _ 8341' -17"X 4-1/2"INV WR PKR .0152 bpf, ID=3.958" &HYDRO HGR,ID=3.915" = . TSGR: 8496' MD , - .,. 3-1/2 LN`, -. •, fsGR-60,ai 9 — . . 0' rerun. scab l;htr TCGL: 8800' MD BCGL: 8875' MD - Pull existing patch - Highside, Zone 3 Exit, 34 degs 1 — 8810' - 3.7" deployment sleeve /4.5" KB LTP - Rerun patch . 8830' - TOL/TOC ESTIMATED TOP OF CEMENT H 8884' 9500' - 3-3/16' x 2-7/8" xo 12 090' - TD 3-1/2"LNR,8.81#, L-80, STL,.0087 bpf, ID=2.867" H 8942' „ WHIPSTOCK(11/15!05) H 9195' ,------- - 4-1/2" packer whipstock RA PIP TA G 9204' 4 8879' 3.7"LNR SLV&BKR HYDRO SET PERFORATION SUMMARY1 RETRIEVABLE PKR,ID=2.560" REF LOG MVVD/GR/ ON 11/15/05 \ 8889' BOT 3'SEAL STINGER& ANGLE AT TOP PERP 64°@ 9250' NN LNR DEPLOY SLV,ID 2.355" Note: Refer to Production DB for historical perf data 8910' -13-1/2"HOWCO X NIP, ID=2.813" SIZE SPF INTERVAL Opn/Sqz DATE 8942' -f2 3-1 "X 3-3/16"XO,ID=2.786" 2" 6 . 9250-9300 07/16/09 2" 6 9410-9485 .. 07/16/09 MILLOUT WINDOW(15-48B) 9195'-9203' 2" 6 9550-9600 C 07/16/09 / 2" 6 10820-11200 C 11/25/05 \13-3/16"LNR,6.2#,L-80,ICH, 39398'X2-7/8"XO, 2" 6 11230- 11450 C 1125/05 yl.0076 bpf, ID=2.80" ID=2.377" 2" 6 11480- 11500 11/25/05 11606' —PBTD I. 2-7/8"LNR,6.16#, L-80, STL, .0058 bpf,ID=2.441" H 11642' TD -I 11646' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/28196 ORIGINAL COMPLETION 07/26/09 TTR/PJC PERFS(07/16/09) WELL: 15-48C 02/23/03 JLM/KK CTD SIDETRACK(15-48A) 0928/09 JLJ/SV GLV C/0(08/06/09) PERMT No:'2051660 11/26/05 NORDIC 1 CTD SIDETRACK(15-48B) 12/11/10 AH/PJC GLV GO API No: 50-029-22635 1129/05 KSB/TLH'GLV C/O SEC 22,T11 N, R14E,2967.84'FEL&1006.73'FNL c 04/03/07 KSB/PJC DRLG DRAFT CORRECTIONS _ 0429/07 NS/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • -'- ... ra a, 0 2 IRU . 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'_ 111 �Y, / in =ri MM 41M ■�� VV� • (u?/8 S8)(+)42101%1(-)41noS • B NM BPPASSPORT R HUGHES Travelling Cylinder Report by 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 15-48 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 15 MD Reference: 66:48 5/30/1996 17:14©66.70ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: 15-48 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 15-48C Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 1 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB DS 07 07-28-07-28A-07-28A Out of range 07-28-07-28AL1 -07-28AL1 Out of range PB DS 15 15-01 -15-01 -15-01 10,661.19 9,500.00 1,343.32 192.11 1,151.63 Pass-Major Risk 15-01 -15-01A-15-01A 11,413.48 11,392.00 615.60 235.75 380.40 Pass-Major Risk 15-01 -15-01B-15-01B 9,163.05 11,375.00 122.67 139.19 11.37 Pass-Major Risk 15-01 -15-01B-15-01B wp04 Extension 9,172.31 11,350.00 171.55 391.00 -180.68 FAIL-Major Risk 15-02-15-02-15-02 12,063.04 9,125.00 1,389.21 280.76 1,278.17 Pass-Major Risk 15-02-15-02A-15-02A 12,063.04 9,125.00 1,389.21 280.76 1,278.17 Pass-Major Risk 15-02-15-02APB1 -15-02APB1 12,063.04 9,125.00 1,389.21 280.76 1,278.17 Pass-Major Risk 15-02-15-02B-15-02B 12,046.49 9,150.00 1,371.79 277.95 1,257.97 Pass-Major Risk 15-02-15-028-15-02B wp10 12,066.10 9,150.00 1,378.52 277.96 1,263.03 Pass-Major Risk 15-02-15-02BPB1 -15-02BPB1 12,046.49 9,150.00 1,371.79 277.95 1,257.97 Pass-Major Risk 15-02-15-02BP62-15-02BPB2 12,046.49 9,150.00 1,371.79 277.95 1,257.97 Pass-Major Risk 15-03-15-03-15-03 9,329.03 9,225.00 439.40 251.79 191.25 Pass-Major Risk 15-04-15-04-15-04 Out of range 15-04-15-04A-15-04A Out of range 15-04-15-04B-15-04B 9,107.80 12,865.00 779.94 636.02 165.75 Pass-Major Risk 15-04-15-04BPB1 -15-04BPB1 9,515.78 12,141.00 1,186.06 544.80 641.34 Pass-Major Risk 15-05-15-05-15-05 Out of range 15-05-15-05A-15-05A Out of range 15-05-15-05APB1 -15-05APB1 Out of range 15-06-15-06-15-06 Out of range 15-06A-15-06A-15-06A 9,000.00 11,275.00 1,347.39 336.40 1,180.49 Pass-Major Risk 15-06APB1 -15-06APB1 -15-06APB1 Out of range 15-20-15-20A-15-20A 8,795.88 10,872.00 790.37 204.00 604.29 Pass-Major Risk 15-23-15-23-15-23 11,990.64 11,275.00 450.77 356.00 96.16 Pass-Major Risk 15-23-15-23A-15-23A 10,409.07 9,475.00 646.86 171.76 489.48 Pass-Major Risk 15-24-15-24-15-24 Out of range 15-26-15-26-15-26 8,784.94 9,000.00 887.46 297.71 603.20 Pass-Major Risk 15-26-15-26A-15-26A 8,784.94 9,000.00 887.46 297.71 603.20 Pass-Major Risk 15-26-15-26B-15-26B 8,789.93 9,000.00 890.25 299.42 604.62 Pass-Major Risk 15-47-15-47-15-47 Out of range 15-48-15-48-15-48 8,875.00 8,875.00 0.16 5.53 -1.86 FAIL-Major Risk 15-48-15-48A-15-48A 10,170.68 10,825.00 32.18 102.23 -53.62 FAIL-Major Risk 15-48-15-48B-15-48B 9,448.96 9,500.00 14.85 42.59 -24.11 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2/1/2011 3:31:12PM Page 3 of 42 COMPASS 2003.16 Build 73 Alaska Department of Natural "esources Land Administration System Page 1 of 1 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find 1 Alaska DNR Case Summary File Type: ADL File Number: 28306 8 Printable Case File Summary See Township,Range,Section and Acreage? O Yes No [ New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28306 Search for Status Plat Updates As of 03/01/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 15 Section Acres:640 Search Plats Meridian: U Township: 011N Range: 014E Section: 16 Section Acres:640 Meridian: U Township: 011N Range: 014E Section: 21 Section Acres:640 Meridian: U Township: 011N Range: 014E Section: 22 Section Acres:640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-127 11N 14E UM 15,16,21,22 2560.00 U-3- 7 End of Case Summary Last updated on 03/01/2011. 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TRANSMITTAL LETTER CHECKLIST WELL NAME /POI/ / :..1ft7 PTD# 0V10.r4 / Development Service Exploratory Stratigraphic Test Non-Conventional Well • FIELD: ,, ,e..:40,"-/oe- 2Ay POOL: P,e4/0/46' /9Y ©/L Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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