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208-140
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Y-25A Reservoir Abandonment Compliance Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-140 50-029-21883-01-00 341J ADL 0028287, 0028288 13835 Conductor Surface Intermediate Liner Liner 9044 80 2631 10944 585 3523 10147 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 2-7/8" 8334 31 - 111 31 - 2662 28 - 10972 10722 - 11307 10312 - 13835 2370 31 - 111 31 - 2662 28 - 8863 8718 - 8994 8456 - 9044 10353 2260 4760 6820 10530 10147 5020 6870 7740 10160 10990 - 11307 5-1/2" 17# L-80 26 - 107178873 - 8994 Structural 5-1/2" TIW HBBP Packer No SSSV Installed 10222, 8390 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 9/11/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:13 pm, Aug 28, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.28 12:09:40 - 08'00' Torin Roschinger (4662) 325-524 10-407 JJL 9/4/25 *AOGCC witnessed tag TOC and CMIT-TxIA to 2500 psi. *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with lateral plug across all strings in confining zone. June 1, 2026 XX A.Dewhurst 03SEP25 DSR-9/9/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:54:42 -08'00'09/10/25 RBDMS JSB 091125 Res AB Sundry Well: Y-25A PTD: 208140 API: 50-029-21883-01 Well Name:Y-25A Permit to Drill Number:208-140 Well Type SU API Number:50-029-21883-01 Job Scope:Res Abandon Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd:TBD Estimated Start Date:9/11/2025 Estimated Duration:4days Regulatory Contact:Abbie Barker 907-564-4915 First Call Engineer:Finn Oestgaard 907-564-5026 Second Call Engineer:Oliver Sternicki 907-564-4891 Current Bottom Hole Pressure:3250 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2370 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:780 psi Min ID:2.30” Aluminum sleeve in SELRT @ 10,320’ Max Angle:92 deg @ 11,700’ MD Top of Sag:10,985’ MD Suspension Extension: Due to coil tubing staffing constraints we are unable to complete work to get required reservoir plugs in place in E- 18B, Y-25A, S-14A and W-09A prior to the required suspension renewal submission date of 8/28/25. Due to this we are requesting a temporary extension of the existing suspensions on the condition that we can show we are progressing this work by the suspension renewal submission due date of 8/28/25. To comply with this requirement, we are planning to have Sundries for this work submitted prior to 8/28/25. Well History: Y-25A is suspended well to be reservoir abandoned with future utility to be rotary sidetracked. It is a failed coil sidetrack drilled in 2008. During the primary cement job the rig experienced a tool failure and left the liner completely full of cement. There is a hole in the tubing @ 10,078’ and the lower half of the tubing has significant corrosion. The rig was going to run a scab liner after completing the sidetrack up to 6,050’. However, due to the results of the cement job the scab was never executed and the well has sat idle since. After the rig pulled off a CMIT-TxI was attempted and failed with a LLR of 1.3 BPM @ 2500 psi 12/27/2008. The well had passed a CMIT-TxI pre-rig to 2500 psi on 6/14/2008, after the failing combo post rig a PX plug was set @ 10,147’ and the well passed a CMIT-TxI to 2500 psi suggesting the kickout window injectivity to be 1.3 BPM @ 2500 psi. The confining zone is the Kingak, starting @ TSAG @ 10,985’ to TKNG @ 9,051’ Annular Cement: 9-5/8” Casing – Estimated TOC @ 6,622’ – based off volumetrics assuming 30% washout. No indications of issues from drilling reports. 5-1/2” Liner – Initial cement job pumped 22 bbls which did not pass a liner lap test, subsequent top jobs by the rig pumped a total of 53 bbls of class G cement into an annular volume of 54 bbls assuming 30% washout. Final squeeze pressure held 1700 psi for 4 hours with the rig. 3-1/2” Liner – No cement is believed to have been placed behind pipe. The liner has cement inside from PBTD to 10,353’ confirmed by a slickline tag 6/27/2025. Target TOC in the 5-1/2 tubing to be above the packer due to known issues with the TIW packer bleed port causing ambiguous pressure testing fails, bringing cement above the packer will eliminate the potential for post job pressure testing complications. Res AB Sundry Well: Y-25A PTD: 208140 API: 50-029-21883-01 Current Status: Y-25A is currently not operable and offline. Objectives: The intent of this program is to place a cement plug from 11,405’ (100’ below the kick out window) to 10,122’, resulting in a 240’ cement plug (10,734’ – 10,974’) across all strings of pipe in the confining zone. Variance Request: A variance is requested to the plugging requirements under 20 AAC 25.112(b). A lateral plug will be placed from 10,734’ – 10,974’MD, across the confining interval and will provide isolation of the reservoir and prevent vertical movement of fluid within the wellbore. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. Fullbore: 1. CMIT-TxI to 2500 psi to confirm PC Integrity, well is currently fluid packed. Slickline: 1. Dummy all gas lift valves & load IA with 410 bbls of dsl down to station 3 via pumping down the IA & taking returns up the tubing. Diesel column in the IA sets well up for balanced plug if sqz is not attained. 2. Pull PX Plug Fullbore: 1. Displace well with 250 bbls of 1% KCL. This will flush previous fluids out of the wellbore. 2. Roll right into injectivity test @ 2500 psi with 80 bbls of 1%KCL. Volume is calculated from 60 minutes @ previous injectivity rate to confirm injectivity has not changed. Extend injectivity test if trends have not stabilized for a 30 continuous minutes. Important to achieve stabile injectivity prior to cement job. Injectivity during the displacement should give decent indication if we’ll need more than 80 bbls of fluid for the injectivity test. 3. FP tubing to 2,200’ (51 bbls) - Previous injectivity through KO window = 1.3 BPM @ 2500 psi - Max pumping pressure = 2500 psi Displacement Volumes x 5-1/2” tubing to TOL @ 10,312 = 239 bbls x 3-1/2” x 5-1/2” from TOL to KO Window = 11.3 bbls x 3-1/2” x 4.5” OH to 100’ below KO Window = 0.78 bbls x Total = 251 bbls Coil Cementing: 1. RIH with nozzle, tag TOL @ 10,312’, PUH 5’ & confirm injectivity with 1% KCL into formation 2. Pump per following pump schedule, Max pressure= 2500 psi. - Pump schedule & fluids may be adjusted depending on results of injectivity test. a. 5 bbls freshwater b. ± 25 bbls of 15.8 ppg cement (1.5X cement volume) c. Displace with diesel d. After ~12.1 bbls pumped away (cement is 100’ past the window) lay in remaining volume of cement of 12.9 bbls, This will put TOC @ 9,756’. e. At safety squeeze away at most 8.5 bbls to ~2000 psi above WHP. Monitor squeezed cement volumes to maintain above target TOC of ~ 10,122’ f. - If unable to achieve squeeze pressure, leave as balanced plug & displace tubing 1:1 with 230 bbls diesel while POOH. Res AB Sundry Well: Y-25A PTD: 208140 API: 50-029-21883-01 - If formation squeezes off early, wash excess cement down to 10,122’ & FP tubing with 51 bbls (2,200’) of diesel while POOH. Cement Volumes: x 5.5” tubing from 10,122’-10,312’ MD: 190’ x 0.0232 bpf = 4.4 bbls x 3.5”x 5.5” annulus from 11,305’-10,312’ MD: 993’ x 0.0114 bpf = 11.3 bbls x 3.5” x 4.5 openhole from 11,305’ to 11,405’ MD: 100’ x 0.0078 bpf = 0.8 bbls Total cement: 16.5 bbls Cement Type/weight:Class G 15.8 ppg or similar Bottom hole static temp:215°F Thickening Time:8 hours (WSL discretion to adjust) Slickline 1. WOC 5 days, Drift and tag TOC –AOGCC Witnessed Fullbore 1. WOC 5 days, CMIT-TxI to 2500 psi –AOGCC Witnessed Attachments: x Current Schematic x Proposed Schematic x Sundry Change Form Res AB Sundry Well: Y-25A PTD: 208140 API: 50-029-21883-01 Current Schematic 208-140 Res AB Sundry Well: Y-25A PTD: 208140 API: 50-029-21883-01 Proposed Schematic 208-140 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 28, 2025Subject: Changes to Approved Sundry Procedure for Well Y-25ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y- 25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Date:Wednesday, August 20, 2025 2:28:33 PM From: Lau, Jack J (OGC) Sent: Wednesday, August 20, 2025 11:05 AM To: Torin Roschinger <torin.roschinger@hilcorp.com>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Good day Torin, Hilcorp’s request to extend the completion of the reservoir abandonments for the suspended wells listed below until June 1, 2026, is approved. The AOGCC appreciates Hilcorp’s effort to progress this activity before the June 1, 2025 date. E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Jack From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Wednesday, August 20, 2025 6:04 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) is safe. Good morning Jack, Earlier this summer Hilcorp requested permission from the AOGCC to move the following suspended well’s reservoir abandonments out to Q1/Q2 2026 due to the high rig activity and the inability to add well trained and competent crews to keep up with the work. The AOGCC granted permission, but we didn’t land on a specific date. I would like to propose that these wells all be completed by June 1, 2026 to allow time in Q2 should Q1 have similar inclement weather as it was 2 years ago and very little work was able to get executed January-March. Please note that while Hilcorp is requesting permission to extend these reservoir abandonments until June 1, 2026, it is our full intention to continue working with our service vendors this Fall to obtain crews/equipment to execute this work well before the requested extension date of June 1st. Please let me know if you approve this request. Suspended Wells under this request for Reservoir Abandonment extension: E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Please let me know if you have any question. Thank you, Torin Roschinger Hilcorp Energy Alaska Prudhoe Bay West - Operations Manager c. 406 570 9630 Torin.roschinger@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. 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 Y-25A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-140 50-029-21883-01-00 13835 Conductor Surface Intermediate Liner Liner 9044 80 2631 10944 585 3523 10147 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" x 2-7/8" 8334 31 - 111 31 - 2662 28 - 10972 10722 - 11307 10312 - 13835 31 - 111 31 - 2662 28 - 8863 8718 - 8994 8456 - 9044 None 2260 4760 6820 10530 10147 5020 6870 7740 10160 10990 - 11307 5-1/2" 17# L-80 26 - 10717 8873 - 8994 Structural 5-1/2" TIW HBBP Packer 10222 8390 Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 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 0028287, 0028288 26 - 8716 N/A N/A 0 0 0 0 0 0 0 50 20 255 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10222, 8390 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 By Grace Christianson at 8:32 am, Jul 11, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.10 20:32:40 - 08'00' Torin Roschinger (4662) DSR=7/21/25 RBDMS JSB 071725 JJL 7/21/25 ACTIVITY DATE SUMMARY 7/4/2025 T/I/O = 253/50/150. Temp = SI. Suspended well inspection (AOGCC witnessed by Guy Cook). No AL & No flowline. Well House, cellar & tree are clean. SV,SSV,MV = C. WV = LOTO. IA, OA = OTG. 09:00 Daily Report of Well Operations PBU Y-25A Y-25A 76 45 43 SUSPENDED 12/5/08 208-140 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 InspectNo:susGDC250704065855 Well Pressures (psi): Date Inspected:7/4/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:12/4/2008 Tubing:253 IA:50 OA:150 Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/27/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT Y-25A Permit Number:2081400 Wellhead Condition Old wellhead showing rust and considerable paint loss. However, the wellhead looked to be in good shape and showed no signs of leakage. Surrounding Surface Condition Good clean gravel pad with no signs of hydrocarbons. Condition of Cellar The cellar appeared to be free of debris and water. What appeared to be good clean gravel was present. Comments Well location was verified with a well pad map. Supervisor Comments Photos (9) Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 5, 2025 jbr 2025-0704_Suspend_PBU_Y-25A_photos_gc Page 1 of 5 Suspended Well Inspection – PBU Y-25A PTD 2081400 AOGCC Inspection Rpt # susGDC250704065855 Photos by AOGCC Inspector G. Cook 7/4/2025 2025-0704_Suspend_PBU_Y-25A_photos_gc Page 2 of 5 2025-0704_Suspend_PBU_Y-25A_photos_gc Page 3 of 5 2025-0704_Suspend_PBU_Y-25A_photos_gc Page 4 of 5 Tubing Pressure Gauge IA Pressure Gauge 2025-0704_Suspend_PBU_Y-25A_photos_gc Page 5 of 5 OA Pressure Gauge Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:208-140 6.50-029-21883-01-00 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 13835 10147 8334 10222 None 10147 8390 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" Conductor 31 - 111 31 - 111 Surface 2631 13-3/8" 31 - 2662 31 - 2662 5020 2260 Intermediate 10944 9-5/8" 47# 28 - 10972 28 - 8863 6870 4760 Liner 583 5-1/2" 10722 - 11305 8718 - 8994 7740 6820 Perforation Depth: Measured depth: 10990 - 11490 feet True vertical depth:8873 - 9009 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# L-80 26 - 10717 26 - 8715 10222 8390Packers and SSSV (type, measured and true vertical depth) 5-1/2" TIW HBBP Packer Liner 2-7/8" x 3-1/2" 10312 - 13835 8456 - 9044 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 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: Ryan Holt ryan.holt@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-659-5102 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 5 SPLUG 16. Well Status after work:Oil 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 measured9044 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspended Well Inspect Operations shutdown Change Approved Program 5 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 028288 PBU Y-25A 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 3:43 pm, Aug 04, 2020 RR Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.04 14:11:12 - 08'00' Stan Golis RBDMS HEW 8/5/2020 SFD 8/5/2020 SFD 8/5/2020MGR07AUG2020DSR-8/6/2020 , ADL 028288 ACTIVITY DATE SUMMARY 6/28/2020 T/I/O = 20/0/140. Temp = SI. SU well inspection (AOGCC witnessed by Bob Noble). No AL or flowline. SV = C. WV = LOTO. MV = O. IA, OA = OTG. 1200. Daily Report of Well Operations PBU Y-25A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:Y-25A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD):2081400 API Number: Operator:BP EXPLORATION (ALASKA) INC Date Suspended: 12/4/2008 Surface Location:Section: 33 Twsp: 11N Range: 13E Nearest active pad or road:Y Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 5 - Wellhead, cellar, tree, wellhouse & area behind wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: McEvoy Wellhead Cameron tree good condition Cellar description, condition, fluids: Clean gravel Rat Hole: N/A Wellhouse or protective barriers: Good Well identification sign: Good Tubing Pressure (or casing if no tubing): 20 psi Annulus pressures: IA - 0 psi OA - 140 psi Wellhead Photos taken (# and description): 2 - Wellhead, cellar & tree Work Required: None Operator Rep (name and signature):Ryan Holt AOGCC Inspector: Bob Noble Other Observers: Randy Mork Inspection Date: 6/28/2020 AOGCC Notice Date: 6/28/2020 Time of arrival: 12:05 PM Time of Departure: 12:10 PM Site access method: Drive 500292188301 Re-Inspection 76 45 43 SUSPENDED 12/5/08 Suspended Well Inspection Review Report InspectNo: susRCN200630150516 Date Inspected: 6/28/2020 Inspector: Bob Noble Well Name: PRUDHOE BAY UNIT Y -25A Permit Number: 2081400 Suspension Approval: Completion Report Suspension Date: 12/4/2008 Location Verified? VO If Verified, How? Other (specify in comments) ' Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 6/26/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Holt Wellbore Diagram Avail? ❑� Photos Taken? ❑� Well Pressures (psi): Tubing: 20 Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 140 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead is in good condition, No flowline, SSV had to be opened, No flowline, All lines brinded with guages, Wellhouse ✓ protecting wellhead. Condition of Cellar Good clean gravel Surrounding Surface Condition Good clean gravel Comments Location was verified with a pad map Supervisor Comments Photos(3)attached / JJ t -7 Z2JZ87io Wednesday, July 22, 2020 Suspended Well Inspection — PBU Y -25A PTD 2081400 AOGCC Inspect Report susRCN200630150516 Photos by AOGCC Inspector B. Noble 6/28/2020 J � - L WELL NAMEY•25A OWNER Prudhoe Bay Unit JOPERATOR BP Exploration (Alaska) Inc. API NUMBER 50-029-21883-01-00 SUR. LOCATION NE 114 Sec. 33, T11N, R13E DRILLING PERMIT 208-140 i V 2020-0628_Suspend_PBU_Y-25A_photos_bn.doex Page 1 of 2 I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-140 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21883-01-00 7. Property Designation(Lease Number): ADL 0028288 8. Well Name and Number: PBU Y-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: RECEIVED PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13835 feet Plugs 4 Pmeasured 10147 feet O�j true vertical 9044 feet Junk measured feet 2016 Effective Depth: measured 10147 feet Packer measured 10222 feet Q true vertical 8334 feet Packer true vertical 8390 feet 6,4 4,, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 31 -111 31-111 Surface 2632 13-3/8"68#L-80 31 -2662 31 -2662 5020 2260 Intermediate 10945 9-5/8"47#NT8OS 28-10972 28-8863 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: feet True vertical depth: feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 26-10717 26-8715 Packers and SSSV(type,measured and 5-1/2"TIW HBBP Packer 10222 8390 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): psi MAR descriptions including volumes used and final pressure: SCANNED MAR 0 8 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ 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 ❑ WAG 0 GINJ 0 SUSP Q 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 Phone +1 907 564 4424 Date 11/14/16 V'-rt, 2-114. 11 -- Form 10-404 Revised 5/2015 � � RBDMS I ,(i 6 fl 6 Submit Original Only- i V_ NOV�:ea. U it r • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad Y No 25A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2081400 API Number: 500292188301 Operator: BP EXPLORATION(ALASKA) INC Date Suspended: 12/4/2008 Surface Location: Section: 33 Twsp: 11N Range: 13E Nearest active pad or road: Y Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition: Clean Gravel pad, no visible hydrocarbons Pad or location surface: Flat Gravel Pad Location cleanup needed: None Pits condition: Good- Frozen Water, No Hydrocarbons Surrounding area condition: Good-Clean Water/fluids on pad: Frozen Puddles Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Gravel Road Photographs taken(#and description): 2-Photos, Wellhouse, behind wellhouse Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings,where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Production tree, no flowline, blinded, good condition Cellar description, condition,fluids: Gravel Cellar, Clean no hydrocarbons Rat Hole: N/A Wellhouse or protective barriers: Wellhouse, good condition Well identification sign: Yes Tubing Pressure (or casing if no tubing): SSV Closed on Hydraulics Annulus pressures: IA=40psi, OA=200psi Wellhead Photos taken (#and description): 1 Photo-Wellhead/Tree Work Required: None Operator Rep(name and signature): Joshua Stephens AOGCC Inspector: Jeff Jones Other Observers: Inspection Date: 10/10/2016 AOGCC Notice Date: /9/2016 Time of arrival: 1:30pm Time of Departure: 1:45pm Site access method: Pickup Truck • 0 ilaby 0.2 0.1 0 0.2 Miles Y-33A PB I ..Y-33A Y.33 Y-0 I a Xk-07APB t YY 33 3H 23A __ i 73APB' q ' A A Legend `` Pipelines(General) �� �� \ Y 19 �� Pipelines(Detailed) YJt .....i Y-IF —1111 °..,,, 3 03 iii Ou. Y ,(Y-10A _—SII w v-25A 1 'Y —N',�G --13 ,.:.e. "�, s;Y-10 . \ Y-28 —IN P= �Y30 "+..\ —Relict P/33.,: '.3 Y-09AC Ii. —t!tilit,1 Y-8011 '� 0,07 S lectcd Pipelines Y-1 io P-22 ;Y-t1A Y-1 �-.. ,Y-1 I Author: ..--`''' .,7 .1)'-'"----„,/, // i / 4 ..45 [ r-14c .:Y-14AY-108PB1 -3-IOBP83 . 14 November,2016 P-04 ,P-03L1 ,Y-Yf/BpB.4i:. BP1\catrgl ©BP Exploration(Alaska)Inc.An rights reserved.This map is mformahonai in nature and is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska- is.b web.b .com warranties as to accuracy completeness,or use for any purpose P 9 P P • TRS CM1N SAFETY NOTES: WELL EXCEEDS 70° V _ MCKY�2 5A • ACTUATOR = BAKER 11200'&GOES HORIZONTAL @ 11600'. Ka aEV= 78. 1' SUSPENDED BF.aEV= 51.21' 12/S/08 KOP= 3300' 2087' H5-1/2"CA MCO SSSV NP,D=4.562" Max Angie= 92°@ 11700' Datum MD= 11000' Datum TVD= 8800'SS J GAS LFT MANDRELS 13-318"CSG,68#,L-80 BTRS,D=12.415" --1----g-64* ST ND TVD DEV TYPE VLV LATCH PORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/08 5 6013 5388 45 CAM DOME RK 16 02/11/08 4 7973 6813 46 CAM DONE RK 16 02/11/08 43' 3 9302 7744 46 CAM SO RK 24 02/11/08 Minimum ID = 2.30" 2 10000 8227 44 CAM DM' RK 0 02/11/99 1 10068 8276 43 CAM DMY RK 0 04/03/04 Al? sleeve in SELRT@10320' - Hole in tubing above GLM#1 PDS caliper 2/25/08 H 10078'7---- I 10147' 1-45-112"PX PLUG(01/06/09)i I 1 10207' HTIW PBR SEAL ASSY 3-1/2"TEB,9.2#,STL,13Cr 0=2.992" —I 10312' l' �t C 10222' 9-5/8"X 5 1/2"TIW HBBP PKR,D=4.75" 10273' H 5-112"OTIS X NP,D=4.562" 45 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" -1 10710' 1 I 10314' H5-1/2"HES XN NP,D=milled to 4.55' I 10717' H5-1/2"TIW SEALI�PLEW/O SEALS MNTEBACK Sly — 10722' �— 1072I 9-5/8"X 5-1/2"11W RP LINF2 HGR H 10734' 9' _ 10338' —I 3-112"STL X NP,D=2.813" 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" —I 10974' -, , r UR R 6.4#,STL 13Cr80,D=2.441" H 11931-13836 15 1/2"w hipstock —L 11306' \ I 75 X0 --I 11831` /w-Y :': PERFORATION SUMMARY FIEF LOG M.MM) MAG VVR/GRON 11/24/88 ANGLE AT TOP FERF: 57©10990' ��, _TOC(cak:) —I 13385' 1 Note:Refer to Reduction D8 for historical pert data SIZE SFE INTERVAL Opnisgz GATE 3-1/2"LNR 9.2#,V AMTOP SC80,13Cr ID=2.992" H11931' 3-3/8" 6 10990-11020 C 05109!95 11481'CTM H FISI-t CBdTRALQ®CMT STNGS2 ASSY(09/15/08) 3-3/8' 6 11230-11250 C 2/15-17/96 • 3-3/8" 6 11260-11280 C 2115-17/96 11550' —I BKR CMT RETAINER(09/15/08) 3-3/8' 6 11296-11326 C 2/15-17/96 e'r j j ',', • i 3-3/8" 6 11330-11350 C 2/15-17/96 •�••���• 4� 11575' H 5-1/2"LNR,17#,L-80,.0232 bpf,D=4.892" 3-3/8" 6 11370-11380 C 2/15-17/96 444.�����.���.�������.���'t I 11579' —ICTC EXT CSG PKR 3-3/8" 6 11380-11410 C 01/30/96 '4./......••••4������1�11ii. -- 3-3/8" 6 11440-11460 C 2/15-17/96 Al'-'4•i j j j j•�•�•�•�•���••'• 3-3/8" 6 11460-11490 C 01/30/96 4'4........****.1.14.1/ .. . SLT 11614-13310 S 9/1608 �4�1�1�•�•�•�•�•�•�•�1�•'•. ''''4•••••••••••••4••1••144.14�... 4Q*4ijjj �4•. • • . i '•i`• 11/ 5-1/2'SLTD LNR,17#, 13418' -At,ip,j L-80,.0232 bpf,D=4.892" •`i t DATE REV BY QTS DATE REV BY COMMENTS F'RUDHOE BAY UNIT 12/10/88 ORIGINAL COMPLETION 01/14/09 MET/SV SET PX PLUG(01/06/09) VVaL: Y-25A 07/14/01 CH/KAK CORRECTIONS 07/14/14 MI CORRECTED CSG FF0 PERMIT No: 04/02/08 KDC/PJC SET VVRP(03/13/08) AA No: 50-029-21883-01 09/17/08 FMA NEL XP CMT SOZ SEC 33,T11N,R13E,1403'SNL&169'VVa 12/04108 NOI2t1UC2 CTD SIDETRACK 12/25/08 /TLH CORRECTIONS BP Exploration(Alaska) • i 0 0 = 0_ O c E m 2 c/) >' • � 3 � ~ O D0 -0 QWD .5 TD N ( O � � � m O0 0- a) •ca D a) Q. 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""+ ok "� A at r ., • .r ro ' .... .. ` f - „., 1 rRIO'' ''1111110„„. 40100,gts '' '-'•' ..14....,...., ,,,,,‘...,., ,•• I 4,7,,.'",,`.3'.,,,..,:‘,,.., .,... .,* * -,'.. .,..'.,...- ,,, ',,...,t ,'..:- ,„ „ , ....*, .., , ,.,,1;,i.,,,, .i.„„.,,,.-,,...,,,, '..,.., ,,..i. . '. . ..., ....,,... IP.' ' ft ,, ,.. ., 1:;t44.. •,.. , . , '..i'5J.:54155''r \ . . ,, ,,'5,'.'5:'•,' 5',.;.5 "'..:,:,.,'....‘,1:;:;'.... ' 4 . ., ' ' .''.1 IV,i1!;,•%`-'„'"'''''' .1i''' ''' ' •od 41... < .... . .. .., , ., . . <<..<.„, , , ..,....„< _ .„. ., .,. i.. 4- '4 4 t.4. ,.... , , -- . ..,.. 44 -*,..,...,,.„.„ — r ...,...„.... , . , ,..le„, .., , ,,,4, * . , . , , . , , . 1 , , t --,-' ,---: - '-' • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU Y-25A - Oper.Rep: J.Stephens PTD No.: 2081400 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: oshua.stevens(a)bo.com If Verified, How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 12/04/08 Date AOGCC Notified: 10/09/16 Sundry No.: Well Completion Report Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 40 OA 200 Condition of Wellhead: Good condition,wing valve,master valve&SSV closed,hydraulics disconnected.Outlet is blinded. Condition of Surrounding Surface Location: Clean level gravel pad with some frozen puddles,no visible hydrocarbon residue.Wellhouse in good condition. Follow Up Actions Needed: None. Comments: Well identified by pad map and well sign permanently attached to wellhouse.Mr.Stephens took photos at my direction and they are attached to his report. Attachments: none SCANNED _i UN 01 7. REVIEWED BY: Insp.Supry �? ti l Ila Comm PLB 12/2015 2016-1010_Suspend_PBU_Y-25Ajj.xlsx 411 • OFT74 • afP\�\I%% 4N THE STATE Alaska Oil and Gas ��► �, ®f Conservation Commission LAsKA 1 : = 333 West Seventh Avenue *�, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O ' +m :: Q Main: 907.279.1433 AL�SIL Fax 907.276.7542 www.aogcc.alaska.gov SCANNEK1 NOV 72015 Ryan Daniel Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. g P.O. Box 196612 `T Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-25A Sundry Number: 315-588 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. 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, per,(74__ Cathy . Foerster Chair DATED this 2i day of October, 2015 Encl. RBDMSS NOV 0 2 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI•N , APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend Q 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 " 1/5/22'14 57 13 • r'-C101 C 1,-/4 L 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 208-140• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21883-01-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? YesNo Q E Will planned perforations require a spacing exception? 0 PBU Y-25A • VF 9. Property Designation(Lease Number): 10. Field/Pools: c1,SEP 1 2015 ADL 0028288 ', .4l 4 0.02-'1,',2..2.)7 A M-46-/5 PRUDHOE BAY,PRUDHOE OIL- IA:Sr II;912 r6e 11. PRESENT WELL CONDITION SUMMARY 3' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): J k a IP 13835 • 9044 • 10147 8334 10147 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 31 -111 31 -111 0 0 Surface 2632 13-3/8"68#L-80 31 -2662 31 -2662 5020 2260 Intermediate 10945 9-5/8"47#NT8OS 28-10972 28-8863 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5-1/2"17#L-80 L-80 26-10717 Packers and SSSV Type: 5-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 10222, 8389.71 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development Q • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended Q • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true an corr ct to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan / Title Alaska Wells Integrity&Compliance Team Leader Signature Phone +1 907 564 5430 Date Pip 10L z D/-r— COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1� 315-� Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Approraf %S 99r givtfcal Cbn f.`n r,-1r on deet toe w7rvit of ��i`7 Stan fur 5v5pz -,c1rd i,-'C115 IA.,141-1--, by Fa-Li, vtitr4_y tvh,cy, bY,'r, S ttitSC 1....„,„IL, Gla5€v /--0A-b4ndc .�*-,tvzt primr t-o pad d<Con-1w,155e'orsr'v<�. Imo$ 4-P1cn f-o bc. 64Cv'Cloped 4vrd 40-0r-ov'td t -ov54 the eor.-rw1r'g51.i-, b'1 1 21 31 //F Spacing Exception Required? Yes 0 No " Subsequent Form Required:,nont r`-d r � n7.t.f • /%ict hire tz, dor-npty wi`1-h thre-4 e-4fri're.y,ttit wi 11 In vR 1' afz l� s p "" APPROVED BYTHE q Approved by: COMMISSIONER COMMISSION Date:!/-Z1?-l.5"- gie(417-L- t 0/7,.6/e5" v ORIGINAL RBDMS W!%/ n220,5 %%' Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments�/ in Duplicate /d_b /0. 26:•-n-- S • C, mg?� � LO2Rr N N N C N Or CO CO U N cDcD cD o i N I� j 3 O 00 N- N- m Lf) Cfl CD ti C3 N CO CO d' L[) r CO CO 00 O7 CO Cb CD CD O N- r N CO CO COO) CO H CO N- CO r co L() r CO CO M M N d N- CA N 00 OD 00 N c- LC) LO N- r N Is M O M T- - r O) CD CO CO N- ap O r r M 0 r r r r C.) Ci Q QN O r N M co"— r N NM N 6 T- r r M W O CD CD 0 CD O 00 CO U 00 Cy p 4• Z h _ 4 N C 20 4t CV N- 4 (1, i7) O — (Q U ao cV N a) U M r 0 r CV 00 U• P • 1 00 UP UP N L r O M O) O O) c Cb UD CD O CO CC) CD O • N J r r W O • Lj ' CD W U 0 Z Z W W W W pp OD ' Z_ ZZD ( Z J .7_1- J TREE_ , 6"CNV • SAFETY NOTES: WELL EXCEEDS 70° YVELLHEA-ACTUATOR = MCAKE Y-25A __..._ 11200'8 GOES HORIZONTAL 11600'. ACTUATOR BAKER KB.ELEV= 78.71 SUSPENDED BF.fiEV= 51.21' 12/5/08 KOP= 3300' 2097' —5-1/2"CA MCO SSSV NP,D=4.562" Max Angie= 92°@ 11700' Datum ND= 11000' Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,68#,L-80 BTRS,D=12.415" —j 26W ST MD ND DEV TYPE VLV LATCH FORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/08 5 6013 5388 45 CAM DOME RK 16 02/11/08 4 7973 6813 46 CAM DOME RK 16 02/11/08 4 3' 3 9302 7744 46 CAM SO RK 24 02/11/08 2 10000 8227 44 CAM DMY RK 0 02111/99 Minimum ID = 2.30" 1 10068 8276 43 CAM CMY RK 0 04/03/04 Al sleeve in SELRT@10320' Hole in tubing above GLM#1 FDS caber 2/25/08 —{ 10078' ----- 10147' 5-1/2"PX PLUG(01/06/09) i10207' —111W FBR SEAL ASSY 3-1/2"TEB,9.2#,Sit,130.N2.992" --j 10312' g ►,4 10222' —9-5/8"X 5-1/2"TIW t1BBP FKR,D=4.75" I ' 10273' H5-1/7M 0S X NP,D=4.562" 4 5� 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" ---I 10710' I 10314' N 5-1/2"HES XN NP,D milled=ned to 4.55" TNN TEBACK SLV H 10727 1071T H{5 1/2'11W SEAL?APPLE W10 SEALS 9-5/8"X 5-1/2'11W RP LN#2 HGR H 10734' 11 10729' BMO 10338' H 3-1/2"STL X NP,D=2.813" 9-518'CSG,47#,NT-80S NSCC,D=8.681' —1 10974' _J 2-7/8"LNR 6.4#,STL 130.80,D=2.441" H 11931-13836 5 1/2"w hipstock H 11306' . ° XO —i 11931' PERFORATION SUMMARY 7 6 # l r REF LOG: NL MM)B-MAG MORON ON 11/24/88 ANGLE AT TOP PERF: 57 a 10990' ✓ ' �'fJl ITOC(calc) —j 13386' Note:Refer to Production DB for historical perf data SIZE SW IJTER\/AL Op is DATE • 3-1/2"LNR 9.2#,VAMTOP SC80,130 D=2.992" — 11931' 3-3/8" 6 10990-11020 C 05/09/95 i 1 3-3/8" 6 11230-11250 C 2/15-17/96 r CTM — 11481' {F1SFt CENTRALIZED CMT SINGER ASSY(09/15/08) 3-3/8" 6 11260-11280 C 2/15-17/96 11550' HBKR CMT RETAINER(09/15/08) 3-3/8" 6 11296-11326 C 2/15-17/96 ','x'1'1'1'•'1', ,lri 3-3/8" 6 11330-11350 C 2/15-17/96 111111111111111111 • , 11575' H5-1/2'LNR,17#,L-80,.0232 bpf,D=4.892" 4.111/111/11♦ 3-3/8" 6 11370-11380 C 2/15-17/96 4 v41111111111111111111�P1.� 11579' —)CTC EXT CSG PKR 3-3/8" 6 11380-11410 C 01/30/96 �`#1#1111/111/11111111�1i. 3-3/8' 6 11440-11460 C 2/15-17/96 "kl '4�1111/11111111111111•1't. 3-3/8' 6 11460-11490 C 01/30/96 444#4#4#4......."..tSLT 11614-13310 S 9/1608 �4�111111111111/1111111'*. ''411�1�1�1�1�1�1�1�11111�*1 ♦•/4111111 ..44***� 111. • 14,•.11 /1�1,l 5-1/2'SLTD LNR, 17#, 13418' 4,1.111V L-80,.0232 bpf,ID=4.892" • DATE REV BY CONVENTS DATE REV BY COMvEPfTS PRUDFiOE BAY UNIT 12110/88 ORIGINAL COMPLETION 01/14/09 Mfg/SV SET PX PLUG(01/06/09) WELL: Y-25A 07/14/01 CHIKAK CORRECTIONS 07/14/14 JMD CORRECTED CSG NFO FB2MT No: 04/02/08 KDC/PJC SET WRP(03/13/08) AR No: 50-029-21883-01 09/17/08 PAN MILL XN,CMT SQZ SEC 33,T11N,R13E,1403'SNL&169'Wf3 12104/08 NORDIC2 CTT]SIDETRACK 12/25/08 /TLH CORRECTIONS BP Exploration(Alaska) bp BP Exploration(Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 28, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well Y-25A (PTD # 2081400) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well Y-25A on 06/03/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition Prudhoe Bay Unit well Y-25A was suspended on 12/04/2008. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with cement throughout the liner and a plug set at 10147' in the 5.5" tubing. The well is mechanically - sound as proven by a pressure test after the plug was set. Based on these conditions and the inspection on 06/03/2014 Prudhoe Bay Unit well Y-25A meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well Y-25A is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. Sincerely, • • • D uglas . Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Prudhoe Bay Well Y-25A (PTD 2081400) Technical Justification for Renewal of Suspended Status August 28, 2015 Well History and Status Prudhoe Bay Unit well Y-25A (PTD 2081400) was suspended on 12/04/2008. During the coiled tubing sidetrack the liner wiper plug launched prematurely during the liner cement job leaving the liner full of cement. The decision was made not to drill out the cement and leave the well freeze protected. The well is secured with cement throughout the liner and a plug set at 10147' in the 5.5" tubing. The well is mechanically sound as proven by a pressure test after the plug was set. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well Y-25A is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= NA/20/160 psi recorded on 06/03/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for Y-25A. 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 remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 5 Year Well Name: Dril'pad Y NO 25A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2081400 API Number 500292188301 Operator BP EXPLORATION(ALASKA)INC Date Suspended 12/41200e Surface Location: Section 33 Twsp 11N Range: 13E Nearest active pad or road: 1-1 Pad Take to Location Digital camera Map showing well location/Aerial photos Bnef well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings,tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires. 1)a description of the condition of the surface location,including discoloration, fluids or sheens visible on the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition Plywood,scaffolding behind wellhouse Pad or location surface: level gravel pad,covered subsidence Location cleanup needed: scaffolding platform Pits condition: snow melt,no sheen Surrounding area condition: Misc piping,platforms,cribbing behind house near pit Water/fluids on pad: snow melt Discoloration,Sheens on pad,pits or water: none Samples taken: None Access road condition: good Photographs taken(#and description): Yes.Wellhouse,surrounding area Condition of Wellhead AOGCC requires- 1)a description of the condition of the wellhead,2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description, condition Old SVS equipment, hoses, bucket with oily waste,WHItree looks good. Heater trunk, IA and OA valves open Cellar description,condition,fluids: snow melt, ice,no sheen Rat Hole: N/A Wellhouse or protective barriers: Yes, house. 1 door handle inoperable Well identification sign: Yes Tubing Pressure(or casing if no tubing). 0 psi.SSV closed Annulus pressures: IA.20,CA-160 psi Wellhead Photos taken(#and description) Yes,WH,tree,cellar Work Requiredclean up trash,remove equipment that is not being used on welt.remove oily waste bucket, clean drips from tree and WH,verify no leaks still exist Operator Rep(name and signature). Laurie Climer AOGCC Inspector Jeff Jones Other Observers Ryar(Hayes Inspection Date- 6/3/2014 AOGCC Notice Date: 6/1/2014 Time of arrival 12.45 PM Time of Departure 12:55 PM Site access method. truck • 410 TREE= 6'CM/ WELLHEAD. MCEVOY w 5� SAFETY NOTES:WELL EXCEEDS 70° ACTLI4TOR= BAKER 11200'dGOES HORIZONTAL la 11600'. KB ELEV= 781' SUSPENDED BF BEV= 5121 12/5/08 _ KOP= 3300' i••••— I 2097' } -I s 1/7 CAMEO SSW Nr,I1=4 562W Max Angie= 92'th 11700' Datum MD= 11000' Daum ND= 8800"53 GAS LET MANDRELS 13-3/8'CSG,68*,L-80 BTRS,D.12.415' H 2664• ST MD TVD CEV TYPE VLV LATCHPORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11108 5 6013 5388 45 CAM WW1 F8( I 16 02/11/08 4 7973 6813 46 CAM DONE RK 16 02/11/08 4 3 9302 7744 46 CAM SO RK = 24 02)11/08 Minimum ID= 2.30" 2 10000 8227 44 CAM DAY 1 18< 0 02/11/99 Ai sleeve in SELRT 10320' 1 10068 8276 43 CAM DAY d RI( 0 04/03/04 ;Holo n tubing above GLM II POG caliper 225/08 i-- 10078' I-. I10147 5 vz!x PLUG(01/0&01911 J- 5=1/2 { 1020T —TIW RIR SEA/ASSY 3-112"I t D,9.2p.5 TT.,13Cf 0=2.992' 1 { 10312' TS IMO 10222' 1--9-5/8"x 5-12"TNV HBBP PICK D=4.75• 10273 H5-1,2"OTIS X asp;D=4.56x• x5-12'196,17#x,L-80,0232 bpi,D.4.892' 1071 Q' 10314' H5-1/2'FES XN#40,13=oiled to 4.55i ITFW TEsAa(s'- H 10727 g 1071T 5-ur 18N SEAL NPPLE wro SEALS 1 I9 508'X 5-1/2.1 W RP LNR HGR J--{_ 10734' I1 10729' -law I 10338' H3-1/2"SR.X NP,D=2,813" [9-5/8`CSC,470,NT-80S NSOC,D=8.681' 1— 10974' ----41 221/3't.Pf16.41f,SM.13Cr80,ID=2.441' H 11931=13835 } 15 12"w Mistook 1-1 11305' 76= xo 11931' PEFPORATDN SLAMARY E4ff LOG: AL MWD ELMAG VIR1GR ON W24/88 M1 �� ANGLE AT TOP FEW- 57 010990' • (calc): 13316' I /tate PI>:ter to Roductxon DB for historical pert data '�"� SIZE M SPF INTERVAL OpnlSgz DATE 3-1/2*LAIR .VAMTOPsato,130-0=9 tsar I--{41951.1 3-318' 6 • 10990-11020 C 05,79,95 3-311r 6 11230-11250 C 2/15-17/96 ,11411'CTM 1-F1311 CB4TRALQSTINGER ED CMF STING ASSY(0&15/06) LIV3-3/8" 6 11260-11280 C 2/15-17/96 _. 11550 BKR GMT FETA ATER(09/15/08) 3-3/8" 6 11296-11326 C 2/15-17/96 - ►'171'1'1'4 V4 L� 3 318" 6 11330-11350= C 2/15 17/96 114411111,4 11676' 5-112'LW,1 fA,L-60, 0232 11_4/1„92'! 3318' 6 11370-11380 C 2t15-17/96 ,4,4�4�1'1�44411�f;1114144*. T / 3-3/8" 6 11380-11410 C 01/30 ♦�4..141414114111�11144'. ' 1Yfi7s Hc1� orres�r'wt 3-3/6- 6 11440-11460 C 2/15-17/96 A14�4;.�4�4�4�1�►+1�4�4�.4r4.4 3-318" 6 11460-11490 C 01(30(96 44440144 411. •.1441441 4/4. 4.4111111111114. SLT 11614-13310 3 911608 !4441114 411111414111/144.►, 14440111�4�1�44414�1�1�4�41 x,441114 . 11 . 4,1 5-1/7 SLID LFR,171f, 1 341 8' +*41„�.1!, L-80,.0232 bpi',D-4.897 �`'* DATE REV BY CO/A434TS DATE REV BY COMMENTS MEWS BAY UMT 12/10188 ORIGINAL COMPLETION 01/14)09 A /SV SET PX PLUG(01/06/09) _ WELL:Y-25A 07/14/01 CI9KAK CORRECTIONS 07/14/14 Al) CORRECTED CSG NFOPF31A4f No: 04/02(08 KDGPJC SET ARP(03/13108) ARNo:50-029-21883-01 09117/08 M RILL XN,CMI SOZ SFC33•T11N R13E 1403'SPL 8169'VIfl 12104108 NOROC2 CTD 911E f RACK 12/25/08 /TLH (X3' CIONS - B'Exploration(Alaska) • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp,Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells,of which many wuuid not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning. The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells, that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally, as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options (wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@,a laska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending if to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [ ;Eailto:Ryan.Daniel@bp.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only (potential future activities) and still in the very early scoping stage. They are not funded or approved yet, and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim, and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated) activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [ nailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • From: Sternicki, Oliver R [mailto:Ohver.Sternicki©bp.com] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki IOW w walkoQa Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickiabp.corn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp a@ alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development,or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • State of Alaska • Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppt alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoa@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.SternickiObp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory, development,or service well; no wells meet the (B) criteria. Regards, Oliver Sternicki WO abb.*walls Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickina bp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me, or come and discuss if we have an issue. Thanks Ryan 3 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@talaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU 5-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A)and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 4 Ima a Pro'ect Well History File Cove~age g 1 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. ~0 ~ _ ~ ~.~ Well History File Identifier anizin done ^ Two-sided III IIIIIIIIIII IIIII ^ Rescan Needed III II'lII IIII IIIIII Org g c ~ RE AN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. f ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: Date: /s/ BY: Maria D IIIIIIIII(IIIIIIIII Project Proofing ,,~ n gY: Maria Date: /s/ r r nnin Pre aration ,~_. x 30 = ~ D + ~ ~ =TOTAL PAGES ~~ Sca g p (Count does not include cover sheet) BY: _ Maria Date: ~ ~ /s/ IIIIIIIIIIIIII IIIII Production Scanning Stage 1 Page Count from Scanned File: ~ ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: 3 ~ /D /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ II II II III n is com lete at this Dint unless rescanrnng is required. I) I II II II ( Scanrn g p P ReScanned III IIIIIIIIIII IIIII BY: Maria Date: Comments about this file: /s/ o~a , ~,~ked iuummmmi 10/6/2005 Well History File Cover Page.doc 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 - JAN December 20, 2010 f � : :: J N Mr. Tom Maunder A 3 ?Oil laska Oil and Gas Conservation Commission 333 West 7 Avenue ,, nt ,, Anchorage, Alaska 99501 ''1 CStI A - a Sion Subject: Corrosion Inhibitor Treatments of GPB Y Pads — I 1 0 Dear Mr. Maunder, ---. Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor / Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y -02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y -03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y -04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 _ NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y-11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y -20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 _ NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 ,..,0,Y-25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y -26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y -27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y -28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y -29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y -30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y -32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y -34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y -36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ INSPECT Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ 208-1400 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21883-01-00 8. Property Designation (Lease Number) : e ~~~ 9. Well Name and Number: ADLO-028288 ~ ~ ~ PBU Y-25A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 13835 feet Plugs (measured) 10147' 1/6/09 feet true vertical 9043.81 feet Junk (measured) None feet Effective Depth measured 10295 feet Packer (measured) 10222 true vertical 8443.75 feet (true vertical) 8390 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2664 13-3/8" 68# L-80 SURFACE - 2664 SURFACE - 2664 4930 2270 Intermediate 10974 9-5/8" 47# NT80S SURFACE - 10974 SURFACE - 8864 6870 4760 Liner 571 5-1/2" 17# L-80 10734 - 11305 8725 - 8994 7740 6280 Liner 1619 3-1/2" 9.2# L-80 10312 - 11931 8456 - 8986 10160 10530 Liner 1904 2-7/8" 6.4# 13CR80 11931 - 13835 8986 - 9044 Perforation depth: Measured depth: NONE - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# LL-80 SURFACE -10170 SURFACE - 8351 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1/2" TIW HBBP PKR 10222 8390 $,~~..'6l~V 12. Stimulation or cement squeeze summary: ~ '~ ~ Intervals treated (measured): t~z ~j~ ~ r- ~.ic a;"? :`~ ~ ~~~ ~t . ~a~T11SS10(t .. ~ .. Treatment descriptions including volumes used and final pressure: ,}Oj';~~~;?~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date ') ~ '~0 win ~~r~r rycv~sc~ ~~c~w . w~N qU0 1 8 [YY~(~ ~ c, ~ yY•• ' !•~'~D </ • Prudhoe Bay Unit Well Y-25A, PTD 2081400 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU Y-25A on 7/18/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Lou Grimaldi waived the opportunity to witness the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one-quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU Y-25A was suspended on 12/04/08. • PBU Y-25A is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a plug at 10147 ft, above any open formation. • The well is mechanically sound as proven by a pressure test after the plug was set. MLB 08/17/10 • Staspended Well Site inspection dorm Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT Y-25A Field/Pool: PRUDHOE BAY / PRUDHOE OIL Permit !# (PTD}: 2081400 API Number: 50029218830100 Operator: BP EXPLORATION (ALASKA} INC Date Suspended: -~~f~988-1~ /o ~1 /a ~ Surface Location: Section: 33 Twsp: 11 N Range: 13E Nearest active pad or rand: Prudhoe Bay Y-Pad lake to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location lAer'ial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water', 2} photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Dry Location cleanup needed: Na Pits condition: Clean water Surrounding area condition: Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: Na Access road condition: Good Photographs taken (1# and description): 3: sign, wellhouse, pit. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition Good Cellar description, condition, fluids: Dry Rat Hole: N/A Weilhouse or protective barriers: Wellhouse Well identification sign: Yes Tubing Pressure {or casing if no tubing}: 15 psi Annulus pressures: IA: 0+ psi OA: 50 psi Wellhead Photos taken (# and description): 2: treelwellhead. Work Required: None Operator' Rep (name and signature): Torin Roschinger „/~ _~f.Y,r AOGCC Inspector: Lou Grimaldi {waived} Other Observers: Inspection Date: 7/18/2010 AOGCC Notice Date: Time of arrival: 11:30 AM Time of Departure: Jack Winslow 711 612 0 1 0 11:45 AM Site access method: Truck TREE _~ 6" CMI WELLHEAD= MCEVOY ACTUATOR= BAKER KB. ELEV = 78.71' BF. ELEV = 51.21' KOP = 3300' Max Angle = 92 @ 11700' Datum MD = 11000' Datum TVD = 8800' SS DRLG DRAFT SUSPENDED 12/5/08 13-3/8" GSG, 72#, L-80, ID = 12.347" I 2664' Minimum ID = 2.30" AI sleeve in SELRT@10320' Hole in tubing above GLM #1 POS caliper 2/25108 1 OI Y-25A V 43° 10207' ~-I TM/ FBR SEAL ASSY 3-112" TIEB, 9.2#, STL, 13Cr ID=2.992" I~ 10312' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TM/ TIEBACK SLV 9-5/8" X 5-1/2" TM/ RP LNR HGR 9-5/8" CSG, 47#, NT-80S, ID = 8.681" ~-~ 1Uy/3• 5 112"whipstock 11305' PERFORATION SUMMARY REF LOG: NL MWD ELMAG WR/GR ON 11/24/88 ANGLE AT TOP PERF: 57 @ 10990' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10990 - 1 1020 C 05109/95 3-3/8" 6 11230 - 11250 C 2/15-17/96 3-3/8" 6 11260 - 11280 C Z/15-17/96 3-3/8" 6 11296 - 11326 C Z/15-17/96 3-3/8" 6 11330 - 11350 C 2/15-17(96 3-3/8" 6 11370 - 11380 C 2115-17/96 3-3/8" 6 11380 - 11410 C 01 /30/96 3-3/8" 6 11440 - 11460 C 2/15-17/96 3-3/8" 6 11460 - 11490 C 01 /30/96 SLT 11614 - 13310 S 9/1608 4 76° SAFEfY NOTES: WELL EXCEEDS 70° @ 11200' & GOES HORIZONTAL @ 11600'. 2097 ~5-1/2"CAMCOSSSV NIP, ID=4.562" (,A C I IFT MA NI~RFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/08 5 6013 5388 45 CAM DOME RK 16 02/11!08 4 7973 6813 46 CAM DOME RK 16 02/11/08 3 9302 7744 46 CAM SO RK 24 02/11/08 2 10000 8227 44 CAM DMY RK 0 02/11/99 1 10068 8276 43 CAM DMY RK 0 04/03/04 10147' ~-i5-1/2" PXPLUG (01/06109) 10222' I9-5/8" X 5-1 /2" TMI HBBP PKR, ID = 4.75" 10273' S-1 /2" OTIS X NIP, ID = 4.562" 10314' -~5-112" HES XN NIP, ID =milled to 4.55" I 10717' 5-1/2" TIW SEAL NIPPLE W/O SEALS 10729' EiMD 10338' 3-112" STL X NIP, ID = 2.813" 2-7/8" LNR 6.4#. STL 13Cr80, ID = 2.44?" 1 1 931-1 3835 XO 11931' ~: TOC (talc) ~ 13385' ~ 3-112" LNR 9.2#, VAMTOP SC80. 13Cr ID = 2.992" 11931' 11481' CTM FISH: CENTRALIZED CMT STINGER ASSY (09115/08) 11550' BKR CMT RETAINER (09/15/08) ~~11575' S-1 /2" LNR, 17#, L-80, .0232 bpf, ID = 4.892„ 11~ 5~- CTC EXT CSG PKR 5-1/2" SLTD LNR, 17#, L-80, .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/10!88 ORIGINAL COMPLETION 01/14/09 MEF/SV SETPXPLUG (01/06!09) 07/14/01 CH/KAK CORRECTIONS 04/02/08 KDClPJC SET WRP (03(13!08) 09/17!08 IMM MILL XN, CMT SOZ 12/04/08 NORDIC2 CTD SIDETRACK 12/25/08 ITCH CORRECTIONS PRUDHOE BAY UNIT WELL: Y-25A PERMIT No: API No: 50-029-21883-01 SEC 33, T11N, R13E, 1403' SNL ~ 169' WEL BP Exploration (Alaska) i• • ' f 1 ~~,~ '' ~Exit~Ertry ~~ ~ ~"" •n~~_ ~._~~-~~? . an-E : ou~;2eas scn.tF : ~ ~ _ use Mnr an-E : roe PRUDHOE BAY UNMZ - Y PAD ~~ - ; ~; ---, `+,, ~ ~ 758'_. Entr ~Exd, - ~,~ i~~ -.~~• ~! ~ '~; y i~'~ ~ 1~ ~ ` l r r, ~ ~ _ ___ ____- ____ - _ r ~ ;; ~ I I +~ f -- _-_ - _ i~ f ~t ~~~ r ~ ~ r _" 07 I f ~ ` ~ ~, nr ewi U+ ~ A ~ ~ ~ ~ ~ _ ` -. ~ ~ i ..~ ~~ ~ f:. ~. i ~ i ~ at_ ~ ir.._ - ~~ ~''~ ^Wir~ilii!^,•:rrrctil~^r~i • i ~~IY.~'r~ W _ -- r~ - ro1~.~ -' w n, n: ~n rv na cow ro .,, cN w ~., w cr ro A ~ w ~ ro "mil ~ wth (ON .,p O'+ V'~Q LrN ,L w u A N w Q) --.~ ~ _ I _ _ - ~ ' i 4.< 7g5' t Q9' 767' ~ "` i ,~' bat w95 cgn '~ ~,s., ~ v= } ~- a, f ~, ; .~ y . ~ ~~8 , . , ,~ .;~, , ~~T, ~ x ~ y ,.. _ . ~ ~ ~". ~„'' ~-„ ~r..~ ~' .~.+ .~ Pad July 14, 2009 Approximate Scale: 1 "=300' 2009-19c-8-22 AFRO-t~TRlt q.~. 1W I~ a, ~'+d t ~'TtF. ~ V "~'3U~em+' anS~{~EE~~,~~ ~~ Y- L p' fir; ~ ~::.. ~ ~ ~~~ ~ i ~. d p~-0.~ >t~ pig., ~ ~ ! ~~ ~,'~ `` ~ a' I 3 R ~ // z .' ''~ 3 '4.i,.... ~5/ ,9-.< 'i K u. ~:4-`.--..ve ~°' ~ ~ i ~ ~ ~a . ~_ ~ y3 .. ~ °~ . ~¢ s .~ ~~~ , y r~{" ~ ,~ !°, ~ ~, ,~'~ Y ,, • t~1~N~R Prudhoe Bay Unit aPERAT~?R BP Exploration ~Alaslca} ln~. APB NUMBER 50-029-21383-01-00 SUIR. L~CAT~QN NE 1 /4 Sec. 33, T11 N, 813E y ~~ CI~ILL~N+~ PERi~UT X08=~ 40 • • ~, • i DATA SUBMITTAL COMPLIANCE REPORT 313/2010 Permit to Drill 2081400 Well Name/No. PRUDHOE BAY UNIT Y-25A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-21883-01-00 MD 13835 TVD 9044 Completion Date 12/4/2008 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATAINFORMATgN Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 11297 13835 Open 1/5/2009 ~/ ~Rpt Directional Survey 11297 13835 Open 1/5/2009 pt LIS Verification 10900 13835 Open 1/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ,- 1'ED C Pds 1754duction/Resistivity 10900 13835 Open 1/28/2009 LIS Veri, GR, ROP, RAD, ~ RAS, RPD, RPS 1 Log Induction/Resistivity 25 Col 11285 13835 Open 2/3/2009 MD MPR, GR 28-Nov-2008 Log Induction/Resistivity 5 Col 11285 13835 Open 2!3/2009 TVD MPR, GR 28-Nov- 2008 ~ L ~ og Gamma Ray 25 Col 11285 13835 Open 2/3/2009 MD GR 28-Nov-2008 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / IVY Chips Received? ~fitid-''~ Analysis ,Yf~l~" Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~ N 1~ J DATA SUBMITTAL COMPLIANCE REPORT 3/312010 Permit to Drill 2081400 Well Name/No. PRUDHOE BAY UNIT Y-25A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-21883-01-00 MD 13835 ND 9044 Completion Date 12/4/2008 Completion Status SUSP Current Status SUSP UIC N Comments: Compliance Reviewed By: Date: i • BAKER M~J6ME5 Esker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKAI'lUN (ALASKA) 1NC CUUN'1'Y NUK'1H SLUYE BUKUU(iH WELL NAME Y-25A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/29/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO #: 2298294 Copies of Copies Digi[al Copicc of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIItKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBII, PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTIIVE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~ b~' <<<~ `~' t ;~ ~ v ~•:{ Page 1 of I INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: Y-25A ~ Contains the following: ~ ~~ 1 LDWG Compact Disc (Includes Graphic Image f les) 1 LDWG lister summary '! 1 color print - GR Directional Measured Depth Log (to follow) r 1 color print - GR Directional TVD Log (to follow) LAC Job#: 2298294 -.~ ~: ,~ ~ ~~ ~ ~ Sent by: Terri Tuminello _ Date: Ol ' "~ /~ Received by: / 1 ~ ~ Date: ' ~`~;_"~' ~~ ~ ~ ~/ ~.~~ ~, ~.~~~, ~a~;cr~c~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~n NIIGNES t n"t'rx1 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~o~-/old /~-S~~ ~1 ALAS~IL AND GASTCONSE VA ION COM~SSION RECEIVED ~~ ~ ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~IEC 3 i 2008 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended ' zoaAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b~1 #~~ Gas n ~Omm1SS - Developrr~~~ Exp oratory ^ Service ~ratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/47~b08 12. Permit to Drill Number 208-140 . 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ ~ ~ ~ •t•d4 11 2008 13. API Number 50-029-21883-01-00 . 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/28/2008 14. Well Name and Number: PBU Y-25A FEL, SEC. 33, T11 N, R13E, UM 1403 FNL, 169 Top of Productive Horizon: 876' FSL, 5055' FEL, SEC. 28, T11 N, R13E, UM g KB (ft above MSL): 78.7' ' Ground (ft MSL): 49.71' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 511' FNL, 1269' FEL, SEC. 32, T11N, R13E, UM 9. Plug Back Depth (MD+ND) 10295' 8444' Pool , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 644647 ~ y- 5948850' Zone- ASP4 10. Total Depth (MD+TVD) 13835' 9044' 16. Property Designation;~~ r•yo? oz8~Z89 ADL 028288 . TPI: x- 639714 y_ 5951035 Zone- ASP4 Zone- ASP4 Total De th: x- 638250 - 5949621 11. SSSV Depth (MD+ND) None 17. Land Use Permit: . p • y 18. Directional Survey ®Yes ^ No mi el r ni n ' t inf i n r AA 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): er'~.t.~~D //3C5~' ~ MWD DIR, GR, RES $99Y'Tt'a 22. CASING, LINER AND CEMENTING RECORD /"~•'0t CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " d r rf 1 rf 11 sCnr e " rf 17- 7 " 47# NT rf 1 7' rf 12-1/4" 4 u I ' -1 17# L- 1 7 7 4' -1/2" 1 ft CI 23. Open to production or inject ion? ^Yes ®No 24. TUBING RECORD If Yes, list each i MD+ND f T & B m Pe tt nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; ( o op o o 5-1/2", 17#, L-80 10710' 10222' MD TVD MD TVD 25. Ac10, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MO AMOUNT & KIND OF MATERIAL USED 2400' Freeze Protect w/ 105 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No ' Sidewal l Core s A uired? ^Yes ®No` If Yes to either question, list formations and intervals cored (MD+ND 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 AAC 250.071. tb~PLEi'101 None ~ ~, ~~N Q ~? 2DDD 0 art~~ _ ~ ~_ .~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE an ~ i•Z•~ G 28, GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No - Permafrost Top tf yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. From Y-25 Kicked Off in None Sadlerochit /Zone 4 11252' 8981' Zone 4BI 13736' 9031' Formation at Total Depth (Name): Zone 461 ~ 13736' 9031' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregojng is true and correct to the best of my knowledge. i' ~ ~ ?~ 3 ~/OS Signed Terrie Hubble ( Title Drilling Technologist Date PBU Y-25A 208-140 Preparnd By Name/Number. Terrie Hubble, 564-4628 Well Number P rmit No. Dri-~ing engineer: Mary Endacott 564-4388 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. IreM 1a: 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). IreM 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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 AAC 25.071. IreM 29: 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task I Code NPT ~ Phase Description of Operations 11/11/2008 01:00 - 02:00 1.00 MOB P PRE Continue to prep rig for move. 02:00 - 02:15 0.25 MOB P PRE PJSM -for pulling rig off of well Y-05B and moving down the pad to Y-25 02:15 - 03:00 0.75 MOB P PRE Move rig from Y-05B to Y-25. 03:00 - 03:30 0.50 MOB P PRE PJSM for moving rig over Y-25 03:30 - 04:30 1.00 MOB P PRE Spot rig over Y-25 Rig accept at 0430 hrs 04:30 - 07:00 2.50 MOB P PRE Berm cellar. Spot external tanks and misc equipment. Continue to prep replacement reel for use. 07:00 - 10:00 3.00 BOPSU P PRE Nu 7-1/16" BOPs. RD, move, spot and RU flow back tank. 10:00 - 15:00 5.00 BOPSU P PRE Perform initial BOP test as per AOGCC regs, PTD 2081400, and approved CTD plan. Test witnessed by AOGCC inspector J. Crisp. Test result data documented on AOGCC form and transmitted via a-mail to the AOGCC office in Anchorage. 15:00 - 17:45 2.75 BOPSU P PRE Hold PJSM. RU DSM lubricator. PT to 1000 psi. Well on a vac. RD DSM lubricator. 17:45 - 18:15 0.50 RIGU P PRE Crew change/safety mtg 18:15 - 20:45 2.50 RIGU P PRE Install internal grapple into CT and PT. Pull CT to floor and stab into injector. Replace packoff. Meg test line 20:45 - 22:05 1.33 RIGU P PRE Rev fill CT w/ KCI 1.4/400, then pump slack back w/ second circ 22:05 - 22:50 0.75 BOPSU P PRE Pressure test inner reel valve and packoff as part of BOP test. Blow down kill line and CT 22:50 - 23:45 0.92 RIGU P PRE RU hydraulic cutter and cut off 152' of CT (which is 1.04% slack) leaving 14343' w/ 354k RF . Pump slack forward to bung hole until wire exited 23:45 - 00:00 0.25 STWHIP P WEXIT MU CTC. PT 35k 11/12/2008 00:00 - 02:00 2.00 STWHIP P WEXIT Head up BHI UOC. PT CTC @ 4000 psi 02:00 - 02:30 0.50 STWHIP P WEXIT Pump slack forward 3.0/2250 Safety mtg re: MU BHA 02:30 - 03:30 1.00 STWHIP P WEXIT MU 5-1/2" WS + MWD assy 03:30 - 06:00 2.50 STWHIP P WEXIT RIH w/ BHA #1 circ KCI thru EDC 0.85/220 while take McOH returns to tiger tank. RIH to 10294' CTD 06:00 - 06:30 0.50 STWHIP N DFAL WEXIT Problems communicating with BHA. Trouble shoot from surface. Suspect a-line has a problem. 06:30 - 09:30 3.00 STWHIP N DFAL WEXIT Pull out of hole. Hold BHA PJSM. 09:30 - 10:30 1.00 STWHIP N DFAL WEXIT Get off well. Unstab coil. E-line had pulled out of e-connector. LD BHA. E-line end was just above coilconnector, but pulled out from anchor. 10:30 - 13:30 3.00 STWHIP N DFAL WEXIT RU to pump slack and cut additional coil. Cut 6' of coil. Found a-line. RU and pump slack back again. Cut 140' of additional coil. 13:30 - 15:00 1.50 STWHIP N DFAL WEXIT Re-head a-coil. Electrical, pressure & pull tests good. 15:00 - 15:30 0.50 STWHIP N DFAL WEXIT Stab coil. Test MWD tools. Get on well. 15:30 - 17:40 2.17 STWHIP N DFAL WEXIT Run in hole with BTT 5-1/2" whipstock circ KCI thru EDC 0.6/100 17:40 - 19:15 1.58 STWHIP P WEXIT Log GR tie-in down from 10980'. Corr +2' to PDC log Log CCL tie-in down from 10850' and find collars on depth to Printed: 12/8/2008 12:21:34 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task Code NPT Phas~ Description of Operations. 11/12/2008 17:40 - 19:15 1.58 STWHIP P WEXIT PDC log 19:15 - 19:30 0.25 STWHIP P WEXIT Park w/ BOWS at 11317' w/ TF 30L. 47.5k, 26k 19:30 - 21:45 2.25 STWHIP P WEXIT 21:45 - 23:10 1.42 STWHIP P WEXIT 23:10 - 00:00 0.83 ZONISO P WEXIT 11/13/2008 00:00 - 01:15 1.25 ZONISO P WEXIT 01:15 - 01:30 0.251 ZONISO P WEXIT 01:30 - 02:10 0.671 ZONISO P WEXIT 02:10 - 02:35 I 0.421 ZONISO I P I I W EXIT 02:35 - 02:50 I 0.251 ZONISO I P I I WEXIT 02:50 - 03:35 I 0.751 ZONISO I P I I WEXIT 03:35 - 04:30 I 0.921 ZONISO I P I I W EXIT 04:30 - 05:30 1.001 ZONISO P WEXIT 05:30 - 07:00 1.501 ZONISO P W EXIT 07:00 - 08:15 1.251 ZONISO P W EXIT 08:15 - 09:45 1.50 STWHIP N RREP WEXIT 09:45 - 10:45 1.00 STWHIP P WEXIT 16:00 - 16:30 0.50 STWHIP P WEXIT 16:30 - 18:30 2.00 STWHIP P WEXIT Close EDC. Pressure up and tool stroked at 3200 psi while setting WS. Stack 4k wob. PUH 46.3k PVT 228 Preliminary setting depths TOWS 11305', RA 11314' POH w/ setting tool LD setting tool. LD MWD assy Change out packoff RU nozzle assy MIRU SWS cementers RIH circ KCI thru nozzle 1.0/320 Finish RIH circ KCI thru nozzle 1.1/355 losing -0.1 bpm w/ 8.7 ECD Safety mtg re: pump cement Tag at 11317' CTD, Corr to 11305'. PUH 50.5k w/ 3k OP IA 325 Park at 11285' while cementers finish batch up and circ biozan to reel SWS pump 2 bbls FW to reel. PT 4000. SWS load CT w/ 15 bbls 15.8 ppg 'G' cement at 80F and 0.8/500 (had poor prime on both pumps). Cement had 90 cc FL w/ 5:32 TT. IA 352 Rig displace w/ 38 bbls biozan at 1.96/1.86/430 followed by 1 KCI IA 410 Red rate to 1.0/200 w/ cement at noz. POH 30'/min 55.2k from 11290' leaving cement in 5-1/2" liner to 10650' Park at 10382' safety and see 0.52/170 psi w/full returns, IA=350 psi SI choke and pressure up wellbore system at 0.5 bpm w/ 5.0 bbls to 1000 psi whp and 1320 psi IAP in 10 minutes. SD pump and monitor for 30 min w/ little bleed off after leaking surface equipment was isolated Bleed off wellbore pressure while RIH and dilute cement w/ biozan 1.0/320 at 40'/min. Tag WS. PUH to 10600'. RIH jetting 2.73/1900 to WS POOH jetting cement to surface 2.65/2000 and get a fair amount of gas back from IA. Take all returns to tiger tank while removing KCI from pits and replacing w/ biozan down the CT. Swap to cuttings box w/ cement at surface Slow down pulling speed while investigate elastomers missing from injector At surface. Get off well. Change nozzle to swizzle stick. Jet out BOPs. Inspect chains. Replace deformed elastomers behind 17 gripper blocks. Hold PJSM. MU 4.55" one step HCC window mill with 4.55" diamond strinca reamer on 2-7/8 motor. Run in hole. Tag something at 10,346' (probably nipple) PU and ream through same. Tag up in liner at 10,988'. 1840 psi fs at 2.54 bpm in/out. Mill through perfs/cmt from 10,988' to 11023'. Log GR tie in from 10,980'. Subtract 2' correction. Tag pinch point at 11,306.5'. Page 2 of 19 Spud Date: 10/29/1988 11 /11 /2008 End: 12/4/2008 Printed: 12/8/2008 12:21:34 PM ~ r BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations - - - 11/13/2008 16:30 - 18:30 2.00 STWHIP P - WEXIT -- 1550 psi fs at 2.53 bpm in/out. Start time milling, adding 0.05' dictated by weight, which is increasing. 18:30 - 00:00 5.50 STWHIP P WEXIT Time mill from 11307.4' 2.52/1600 w/ 50-100 psi dill, 1.7-4.3k wob w/ 8.64 ECD using occasional fresh biozan sweeps. Mill to 11310' 11/14/2008 00:00 - 05:30 5.50 STWHIP P WEXIT Continue time milling window from 11310.0' 2.51/1700 w/ 100 psi dill, 1.8-2.5k wob w/ 8.57 ECD. Mill to 11314.2' and lost 2k wob and 100 psi MW 05:30 - 06:00 0.50 STWHIP P WEXIT Drill rathole to 11325' while pump final 40 bbl biozan pill 06:00 - 09:00 3.00 STWHIP P WEXIT Make several up and down passes to dress window. 1720 psi fs at 2.50 bpm in/out. Dry drift window. 09:00 - 12:00 3.00 STWHIP P WEXIT Circulate out of hole at 1850 psi fs at 2.90 bpm in. Hold BHA PJSM. Tag up, 12:00 - 13:00 1.00 STWHIP P WEXIT Get of well. LD Inteq tools, PH6, and BTT motor. Mill gauged 4.54" nogo Inspect injector chains. 13:00 - 14:00 1.00 DRILL N RREP PROD1 Continue to inspect chains. Replace some elastomer sections. 14:00 - 14:45 0.75 DRILL P PROD1 MU BHA #4. 1.5 deg AKO with Hycalog DS49 4.5" bit. Test tools. Get on well. 14:45 - 17:30 2.75 DRILL P PROD1 Run in hole. Set down in packer at 10,226'. Adjust TF to HS. Popped through. Continue to RIH. 17:30 - 18:30 1.00 DRILL P PRODi Log tie-in, corr -5'. RIH thru window w/set down on first slow speed pass 18:30 - 20:15 1.75 DRILL P PROD1 Drill from 11325' 2.50/2460/60L w/ 100-250 psi dill, 0.30-0.60k wob w/ 8.85 ECD w/ a few initial stalls followed by steady penetration while swapping the wellbore to reconditioned Flo Pro mud. Drilled to 11404' and see that surveys of 25' of hole are not giving required build (getting 6 DLS and need 12-15 DLS) Geos noted samples mostly cement. 20:15 - 20:30 0.25 DRILL P PROD1 Wiper to window, pull thru window clean. Open EDC 20:30 - 22:50 2.33 DRILL N DPRB PRODi POH circ thru EDC 2.95/2300 22:50 - 00:00 1.17 DRILL N DPRB PRODi LD drilling BHA. Bit was 1-4-I w/cutters on taper chipped off. Adjust motor to 2.1 deg, change bit. Adjust injector auto-drill 11/15/2008 00:00 - 04:30 4.50 DRILL N DFAL PROD1 BHI found that the TF parameters after this run differered from the parameters which were set before the run. Change out the HOT. Tool tested fine in pipeshed. MU motor to BHA and scribe. Move tools outside onto ground and confirm tool checks okay 04:30 - 05:10 0.67 DRILL N DFAL PROD1 MU correction run BHA 05:10 - 07:30 2.33 DRILL N DFAL PROD1 RIH w/ BHA #5 (2.1 deg motor) circ thru EDC 0.50/830 07:30 - 08:00 0.50 DRILL N DFAL PROD1 Log gr tie in from 11,000. Subtract 6' correction. 08:00 - 08:30 0.50 DRILL N DFAL PROD1 Close EDC. Run in hole. 08:30 - 09:30 1.00 DRILL N DFAL PROD1 Call town to dicuss the plan forward. Decide to set cement Plug• 09:30 - 12:30 3.00 STKOH N DFAL PROD1 Paint EOP flag at 10952'. Pull out of hole. Hold PJSM. 12:30 - 13:30 1.00 STKOH N DFAL PROD1 LD Inteq BHA. Bit in new condition. 13:30 - 14:00 0.50 STKOH N DFAL PROD1 MU 3.0" nozzle on 3 joints oh 2-3/8" PH6. 14:00 - 17:00 3.00 STKOH N DFAL PROD1 Run in hole. RU cementers. Printed: 12/8/2008 12:21:34 PM ~ ~ BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task' Code ~ NPT Phase Description of Operations 11/15/2008 14:00 - 17:00 3.00 STKOH N DFAL PROD1 Prep to displace well to 2% KCL water. Correct to EOP (-7') Tag TD at 11,404'. 17:00 - 19:00 2.00 STKOH N DFAL PROD1 Continue to displace well to 2% KCL. 19:00 - 19:15 0.25 STKOH N DFAL PROD1 Safety mtg re: cement plug 19:15 - 20:10 0.92 STKOH N DFAL PROD1 Cementers take on water and prep to batch up cement kickoff plug Slow recip CT 1 1 200-1 1 400' 0.55/70 w/ KCI Pump biozan to reel 1.21/370 20:10 - 20:40 0.50 STKOH N DFAL PROD1 SWS cementers pump 5 bbls FW. PT 4000. Batch up and load CT w/ 8.0 bbls 17.0 ppg G cement at 78F 1.04/300, 1.35/900 20:40 - 21:20 0.67 STKOH N DFAL PROD1 Rig displace w/ 30 bbls biozan 1.5/970 followed by KCI 2.0/750 POOH 47k from 11390' w/ 1 bbl out noz and lay in cement 1/1 ~ 1.5/430 at 50'/min to 11050' PUH to safety 21:20 - 22:20 1.00 STKOH N DFAL PROD1 PUH slow from 10750' pumping occassionaly while WOC to settle 22:20 - 22:45 0.42 STKOH N DFAL PROD1 Dilute cement with biozan from 1 1 050-1 1 300' 1.0/350 at 30'/min. POH to 11000' at min rate. RIH rediluting 2.0/920 50'/min to 11300' 22:45 - 00:00 1.25 STKOH N DFAL PROD1 POH jetting 2.96/1900 cement to surface. Sent 60 bbls of max 9.40 ppg returns to cuttings box 11/16/2008 00:00 - 01:00 1.00 STKOH N DFAL PROD1 Finish POOH w/ cementing assy 2.9/2100 01:00 - 01:40 0.67 STKOH N DFAL PROD1 LD PH6 and nozzle. MU swizzle stick 01:40 - 02:50 1.17 STKOH N DFAL PROD1 Jet stack, function test BOP rams, function reel house valves. LD swizzle stick. Blow down lines, blow back CT w/air 02:50 - 03:20 0.50 STKOH P PRODi Safety mtg re: hand injury awareness 03:20 - 06:00 2.67 STKOH N DFAL PROD1 Set injector over bung hole. Nordic open BOP doors and inspect ram cavities. Perform BOP body pressure test to 3500 and 250-300 psi. Clean HP filter in reel house. SWS change HP hyd filters 06:00 - 06:30 0.50 STKOH N DFAL PROD1 Crew change. Make rounds. 06:30 - 09:00 2.50 STKOH N DFAL PROD1 Close up BOPs after inspection. Continue to inspect injector chains and replace deformed elastomers. 09:00 - 10:00 1.00 STKOH P PROD1 Hold safety stand down on the rig to review hand safety incidents and protocol. SLB, Nordic, BHI attending meeting. 10:00 - 18:00 8.00 STKOH N DFAL PROD1 Finish inspecting and maintaining forward injector chain. Replace and test high pressure filters on injector and power pack. Drain planetary oil from reel system. Continue ULS diesel plumbing work. Rig lost power twice during afternoon. Problem with #3 genset. Rig electrician reports that genset software license has expired. 18:00 - 18:45 0.75 STKOH N DFAL PROD1 Crew change/safety mtg Returning Nordic crew given hand injury awareness presentation 18:45 - 00:00 5.25 STKOH N DFAL PROD1 Nordic prepped wall by gas buster for paint. Replaced reel slings. Open up both mud pumps for inspection. Cleaned suction and discharge screens SWS continue injector inspection, filled reel planetary gearbox Printed: 12/8/2008 12:21:34 PM 13P EXPLORATION Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To I~, Hours Task Code NPT Phase -- 11/16/2008 18:45 - 00:00 5.25 STKOH N DFAL PROD1 11/17/2008 00:00 - 06:00 6.00 STKOH N DFAL PROD1 06:00 - 06:30 0.50 STKOH N DFAL PROD1 II 06:30 - 13:30 I 7.00 I STKOH I N I DFAL I PROD1 13:30 - 18:00 4.50 STKOH N DFAL PROD1 18:00 - 18:30 0.50 STKOH N DFAL PROD1 18:30 - 00:00 5.50 STKOH N DFAL PROD1 11/18/2008 100:00 - 06:00 6.00 STKOH N DFAL PROD1 06:00 - 06:30 0.50 STKOH N DFAL PROD1 06:30 - 08:30 2.00 STKOH N DFAL PROD1 08:30 - 09:00 0.50 BOPSUF~ P PROD1 09:00 - 14:30 5.50 STKOH N DFAL PROD1 14:30 - 19:30 5.001 STKOH N DFAL PRODi 19:30 - 22:25 I 2.921 STKOH I N I DFAL I PROD1 22:25 - 23:30 1.08 STKOH N DFAL PROD1 23:30 - 00:00 0.50 STKOH N DFAL PROD1 11/19/2008 00:00 - 00:30 0.50 STKOH N DFAL PROD1 00:30 - 01:20 0.83 STKOH N DFAL PRODi 01:20 - 02:30 1.17 STKOH N DFAL PROD1 02:30 - 03:00 0.50 STKOH N DFAL PROD1 11 /11 /2008 Page 5 of 19 ~ Spud Date: 10/29/1988 End: 12/4/2008 Description of Operations w/ oil Nordic replaced swabs and liners in pump #2, swabs in pump #1. Replaced SWS injector sling SWS finished inspection of injector and greased same. Replaced 15 additional deformed elastomers Crew change. Make rounds. Hold PJSMs to proceed with tasks. Change lamp in pipe shed. Paint pipe shed walls. Replace sodium light bulbs in pipe shed. Big improvement. Test mwd tools in pipe shed with hand held magnet. Hold PJSM to power down rig. Swap to satellite camp power. Monitor DGS magnetic field readings with tool elevated in pipe shed. Shut down all power on rig. Make readings from DGS. Power rig back up. No change in any magnetic field measurements before, during, or after rig power up/down/up. Begin changing out hydraulic hoses to injector. Crew change/safety mtg Finish removal of hyd hoses from injector bundle. Replace fittings. Paint pipeshed walls Install new hyd hoses to injector. Wrap and test. Move stoodback CSH out of the way. Bring deflector beam to floor and prep. BHI perform tool tests with and with out the magnetic shield device Crew change. Make rounds on rig. Hold PJSM for derrick work. Arrange tools on catwalk for testing. Perform weekly BOPE function test. Continue with rig projects. Continue to trouble shoot BHI tool problem. PU injector so BHI can meg test line and perform other checks. Nordic electrician use oscilloscope and work with onsite BHI personnel. Pump thru the kill line at drilling rate and use choke to get draw on generators. Use both pumps. Electrician verified rig grounding M/U nozzle + checks, RIH to thaw out CT. RIH to 4,100 ft and pump down CT. Circulate below 3,000 ft until out MM temp levels off, after 70 bbls. POOH. PJSM for change out BHA. Overhead loads, pinch points were discussed. Tag stripper and remove nozzle. M/U BHA #10 for downhole troubleshooting. Continue M/U BHA #10. RIH with BHA #10. Turn orientor, power tool on and off at various pump rates. POOH. Tag stripper, PJSM for L/D BHA. Crew positions and hand traps were discussed. UD BHA. Printed: 12/8/2008 12:27:34 PM BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase '; Description of Operations 11/19/2008 03:00 - 08:30 5.50 STKOH N DFAL PROD1 Lay out tool on catwalk for inspection. Tool is referencing high side correctly, the same as when it went in. Continue to break apart tool sections and inspect. 08:30 - 09:30 1.00 STKOH N DFAL PRODi Blow back CT w/air. BHI perform meg/power tests 09:30 - 18:00 8.50 STKOH N DFAL PROD1 Safety mtg re: BHI testing tools while crew replace deflector beam Rig welder cut out deflector beam and replace w/ prefab from Cassidy Engr. 18:00 - 23:00 5.00 STKOH N DFAL PROD1 BHI specialists on location. Check pipe shed for magnetic fields, and magnetized objects. Find several joints of pipe on the rack that are magnetized. 23:00 - 00:00 1.00 STKOH N DFAL PRODi Fill well with 3 bbls. Line up both pumps to pump across tree through choke, see if this induces any magnetic fields. 11/20/2008 00:00 - 05:00 5.00 STKOH N DFAL PRODi Continue checking tool and pipe shed magnetics with various combinations of generators and CT power pack running. 05:00 - 08:00 3.00 STKOH N DFAL PROD1 Lower toolstring outside to verify highside measurement there. Can not find any surface conditions that would affect or replicate what has happend downhole. Based on AM call, decide to go forward cautiously and monitor closely. Will mill out cement w/ full drilling BHA (incl res tool) 08:00 - 10:40 2.67 STKOH N DFAL PROD1 Perform final checks on tool string 10:40 - 10:50 0.17 STKOH N DFAL PRODi Safety mtg re: MU drilling BHA 10:50 - 11:40 0.83 STKOH N DFAL PRODi MU milling BHA w/ used 4.55" mill on straight motor w/full MWD incl MPR 11:40 - 13:40 2.00 STKOH N DFAL PROD1 RIH w/ BHA #11 circ thru mill 0.35/80 13:40 - 13:50 0.17 STKOH N DFAL PROD1 Tag at 10990', PUH 46k. Start motor. RIH and mill thru obstruction w/o resistance 13:50 - 14:00 0.17 STKOH N DFAL PROD1 Log GR tie-in down from 11010' 0.41/100, Corr -6.0' 14:00 - 14:40 0.67 STKOH N DFAL PROD1 RIH 0.57/150 to set down at 11078'. Precautionary ream C~ 5-10'/min 2.54/1870 w/ one stringer at 11090'. Stall at 11303' 14:40 - 16:00 1.33 STKOH N DFAL PROD1 Mill cement from 11302.1' 2.52/1830 w/ 100-300 psi diff, 2.5-4.5k wob at avg 20'/hr rate to 11323' which is 10' below the window 16:00 - 16:15 0.25 STKOH N DFAL PROD1 Ream window while finish displacing 30 bbl biozan pill thru mill 16:15 - 18:40 2.42 STKOH N DFAL PRODi POH circ thru mill 2.54/1500. PJSM before tagging stripper. Keeping extra personnel out of harm's way was discussed. 18:40 - 19:40 1.00 STKOH N DFAL PROD1 Tag stripper and flow check well. UD BHA #11 and check HOT, tool is reading OK the same as when it went in. 19:40 - 20:50 1.17 STKOH N DFAL PROD1 M/U BHA #12. 4.5" M609 bit, 2-7/8" Xtreme motor with 2.2 deg AKO, 3" CoilTrak with MPR. 20:50 - 23:00 2.17 STKOH N DFAL PROD1 RIH, circ 0.56 bpm / 150 psi through open EDC. Set down wt at 10,230 ft, with a 40L TF. Likely the 9-5/8" x 5-1/2" Packer. Pick up and try to go to high side, up wt is 43 Klbs. Lose communication with BHA after tagging. 23:00 - 00:00 1.00 STKOH N DFAL PROD1 Not able to restore comms with tool, POOH. 11/21/2008 00:00 - 00:30 0.50 STKOH N DFAL PROD1 Continue POOH due to loss of communication with BHA. 00:30 - 03:10 2.67 STKOH N DFAL PROD1 PJSM for change out BHA. UD BHA #12, troubleshoot and find boot that connects DPS Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Operations Summary Report Legal Well Name: Y-25 Page 7 of 19 ~ Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task Code' NPT Phase 11/21/2008 00:30 - 03:10 2.67 STKOH N DFAL PROD1 03:10 - 04:10 1.00 STKOH N DFAL PROD1 04:10 - 06:00 1.83 STKOH N DFAL PROD1 06:00 - 06:25 0.42 STKOH N DFAL PROD1 06:25 - 06:40 0.25 STKOH N DFAL PROD1 06:40 - 07:20 0.67 STKOH N DFAL PROD1 07:20 - 08:30 1.171 STKOH N DFAL ~ PROD1 08:30 - 08:45 0.25 DRILL P PROD1 08:45 - 09:30 0.75 DRILL P PROD1 09:30 - 09:45 0.25 DRILL P PROD1 09:45 - 12:10 2.42 DRILL P PRODi 12:10 - 13:20 1.17 DRILL P PROD1 13:20 - 13:30 0.17 DRILL P PROD1 13:30 - 14:00 0.50 DRILL P PROD1 14:00 - 15:55 1.92 DRILL P PROD1 15:55 - 16:15 0.33 DRILL P PROD1 16:15 - 19:00 2.75 DRILL N DFAL PRODi 19:00 - 20:50 I 1.831 DRILL I N I DFAL I PROD1 20:50 - 23:00 2.17 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL N DFAL PRODi 11/22/2008 100:00 - 01:10 1.171 DRILL ~ N ~ DFAL ~ PROD1 01:10 - 05:30 4.331 DRILL N DFAL PROD1 05:30 - 06:10 0.671 DRILL N DFAL PROD1 06:10 - 06:20 0.17 DRILL P PROD1 06:20 - 07:50 1.50 DRILL P PROD1 Description of Operations and Gamma is broken. P/U BHA #13 - 4.5" M609 bit, 2-7/8" Xtreme motor with 2.2 deg AKO, 3" CoilTrak with MPR. RIH BHA #13. Pump 0.25 bpm through bit while RIH. Log tie-in down from 11000', corr -3' RIH w/ sli wt loss at BOW to tag at 11324' Drill build from 11324' 2.51/2050/30L w/ 100-200 psi diff, 0.0-1.2k wob w/ 8.68 ECD at 60-100'/hr w/ no initial stalls. Swap to used Flo Pro mud. Drill to 11375' Drill turn from 11375' 2.51/2100/50L w/ 100-300 psi diff, 1.0-2.Ok wob w/ 8.78 ECD at 60'/hr while fin displace wellbore to mud. Drill to 11450' Wiper to window was clean Drill from 11450' 2.45/2150/100L w/ 200 psi diff, 1.4-2.5k wob w/ 9.14 ECD Drill to 11510' Wiper to window was clean Open EDC. POOH circ thru EDC 2.83/2000 LD drilling BHA #13. Check BHI tools, okay. Adjust motor to 1.6 deg, bit okay Safety mtg re: MU BHA MU drilling BHA #14 RIH w/ BHA #14 circ thru EDC 0.33/520 Log tie-in down from 11000' to 11032', corr -6' Close EDC RIH to 11151' and BHI see spurious anomolay w/ TF and 'stops'. PUH from 11080' slow while BHI does diagnostics. Open/close EDC and check for effects-none noted. Tool is sending up bad TF readings. Not able to reset it or verify what TF we are at. Stop between 2 collars at 10,907 ft and shut off tool for 10 min, then try to find high side by running the TF up against an end stop and re-calibrating. Unsuccessful. POOH. PJSM for change out BHA. Tag stripper and flow check well. UD BHA #14 and troubleshoot. Bit is 1-1, will re-run. Test BHA #15 on catwalk. M/U BHA #15 - 4.5" M609 bit, 2-7/8" Xtreme motor with 1.6 deg AKO, 3" CoilTrak with MPR. RIH BHA #15. Plan is to re-create the failure without cycling the pumps or EDC as in the last run to eliminate those as creating the problem. Pull past area with magnetized collars. Tool fails same mode as before in this spot then resets itself when getting to a clean area. Pull to a clean area and try cycling the pump and EDC, problem is not repeated. Log from 11,006 ft down at 275 fUmin. Change tool data rate and increase logging speed to get past highly magnetized area. Correction is -6.5 ft. Continue on to log PIP tag. Wiper to TD tagged at 11511' PVT 470 Drill from 11511' 2.59/2220/20L w/ 100-200 psi diff, 1.0-2.Ok Printed: 12/8/2008 12:21:34 PM ~ ~ BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To !I Hours 'I Task Code NPT Phase i Description of Operations 11/22/2008 06:20 - 07:50 1.50 DRILL P PROD1 wob w/ 9.13 ECD at 88 deg NBI and build to 93 deg while drilling to 11650' PVT 469 07:50 - 08:20 0.50 DRILL P PROD1 Wiper to window was clean both directions 08:20 - 09:00 0.67 DRILL P PROD1 Swap TF to right and drill from 11650' 2.66/2250/908 w/ difficulty due to TF change. Ream hole to straighten DLS 09:00 - 10:55 1.92 DRILL P PROD1 Drill from 11660' 2.65/2240/1008 w/ 100-300 psi dill, 1.0-2.Ok wob w/ 9.16 ECD at 94 deg. Drill to 11800' 10:55 - 11:30 0.58 DRILL P PROD1 Wiper to window 11:30 - 13:50 2.33 DRILL P PROD1 Drill from 11800' 2.45/2000/1008 w/ 100-300 psi dill, 1.5-2.6k wob w/ 9.14 ECD at 93 deg. Vibration is too high to get surveys while drilling at pump rates above 2.5 bpm 13:50 - 14:30 0.67 DRILL P PROD1 Wiper 2.7/2300 to window was clean. Pull thru window, open EDC. Wiper 3.0/2000 to 10900'. RBIH to 11000' 14:30 - 14:45 0.25 DRILL P PROD1 Log tie-in down from 11000' 3.0/1980, Corr +10' 14:45 - 15:20 0.58 DRILL P PROD1 Wiper back to TD was clean PVT 460 15:20 - 16:30 1.17 DRILL P PROD1 Drill from 11950' 2.44/2020/908 w/ 100-400 psi diff, 1.5-3.5k wob w/ 9.23 ECD at 92 deg. Drill to 12008' 16:30 - 17:40 1.17 DRILL P PROD1 Drill from 12008' w/ a couple stalls and slower penetration. Acts like formation change. Drill to 12060' and are back in sand again. Determine that Shublik was grazed at 11920-940' and again at 12008-12028' PVT 458 17:40 - 18:40 1.00 DRILL P PROD1 Wiper to window to test the water. Have several 10k OP's w/ associated MW at 1 1 940-1 1 920'. Nothing seen on down pass. 18:40 - 20:00 1.33 DRILL P PROD1 Drill from 12,056 ft and swap to left. 2.40 / 2.39 bpm C~ 2000-2300 psi. PVT = 456 bbls. Hold around 87.5 deg inc for now with 90L TF. Initial ROP is 80 - 100 ft/hr with DWOB = 2 - 3 Klbs, CT wt is 17 Klbs. Several stalls around 12,090 - 12,100 ft, with occasional wt stacking. Drill to 12,118 ft. 20:00 - 20:15 0.25 DRILL P PROD1 Short wiper from 12,118 ft to 12,000 ft. MW seen at 12,020 ft. 20:15 - 22:10 1.92 DRILL P PRODi Drill from 12,118 ft. 2.62 / 2.63 bpm C~ 2200-2500 psi. PVT = 450 bbls. Maintain ROP at 120 ft/hr to keep it sliding. Short wiper from 12,140 ft back to 11,900 ft. Stall pulling up at 11,940 ft, orient to correct TF, nothing seen. Drill to 12,200 ft. 22:10 - 23:20 1.17 DRILL P PROD1 Wiper trip from 12,200 ft to window. Increase rate to 2.69 bpm / 2,270 psi for wiper. Clean pass up and down. 23:20 - 00:00 0.67 DRILL P PROD1 Drill from 12,200 ft. 2.42 / 2.42 bpm ~ 1900-2200 psi. PVT = 439 bbl. Drop inc to 85 deg, hold this for now. Drill to 12,240 ft. 11/23/2008 00:00 - 02:20 2.33 DRILL P PROD1 Continue driling from 12,240 ft. Frequent wt stacking. Drill to 12,305 ft. 02:20 - 03:30 1.17 DRILL P PROD1 Wiper trip from 12,305 ft to window. Pull through window and open EDC, pump 3.0 bpm / 2,000 psi up to 10,900 ft. 03:30 - 05:00 1.50 DRILL P PROD1 Log from 11,005 ft down. First pass shows unfamiliar GR features. Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Page 9 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To II Hours ~ Task Code NPT I Phase Spud Date: 10/29/1988 11 /11 /2008 End: 12/4/2008 Description of Operations 11/23/2008 03:30 - 05:00 1.50 DRILL P PROD1 Log again from higher up. Correct +26 ft. 05:00 - 05:40 0.67 DRILL P PROD1 Stop at 11,276 ft and correct depth, switch back to slow data 05:40 - 06:00 I 0.331 DRILL I P 06:00 - 06:20 0.33 DRILL P 06:20 - 08:25 2.08 DRILL P 08:25 - 09:30 1.08 DRILL P 09:30 - 12:40 3.17 DRILL P 12:40 - 13:30 0.83 DRILL P 13:30 - 14:20 0.83 DRILL P 14:20 - 14:35 0.25 DRILL N 14:35 - 16:00 1.42 DRILL P 16:00 - 16:45 0.75 DRILL P 16:45 - 17:45 1.00 DRILL N 17:45 - 19:15 1.50 DRILL N 19:15 - 20:45 1.50 DRILL N 20:45 - 21:00 0.25 DRILL N 21:00 - 22:20 1.33 DRILL N 22:20 - 00:00 I 1.671 BOPSUR P 11/24/2008 100:00 - 03:00 I 3.001 BOPSUFi P PROD1 PROD1 PROD1 PRODi PRODi PROD1 PROD1 DFAL PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 03:00 - 07:30 4.50 DRILL N DFAL PROD1 07:30 - 07:40 0.17 DRILL N DFAL PROD1 07:40 - 09:00 1.33 DRILL N DFAL PROD1 09:00 - 12:00 3.00 DRILL N DFAL PROD1 12:00 - 15:00 ~ 3.00 ~ DRILL ~ P ~ ~ PROD1 rate, close EDC. Continue wiper trip to bottom. Tag 12,319 ft. Drill at 2.42 / 2.41 bpm ~ 2300-3000 psi. Swapping to new mud. Drill to 12335' 300' wiper Drill from 12335' 2.44/2240/90L w/ 100-500 psi dill, 0.7-2.5k wob w/ 9.38 ECD at 83 deg. Drilling w/ neg surface wt. Drill to 12463' Wiper to window was clean Drill from tag at 12456' 2.47/2320/100L w/ 200-500 psi diff, 1.5-3.Ok wob w/ 9.51 ECD at 84 deg w/ +12k surface wt at times. Drill in spurts to 12606' Wiper to window was clean POH circ thru EDC 3.03/2300 Park at 8114' and check out CT pinhole-very small leak and already on reel. Can't find w/ 800 psi. Reel has 534k RF POOH filling from BS LD drilling BHA MIRU SWS N2. Circ FW into reel and displace mud over bung hole Safety mtg re: N2 blowdown. Cool down N2, PT 4000 Blow down reel w/ N2 to tiger tank and bleed off. 19:00 -Fill well with 3 bbls, shut swab back in. Remove BHI cable head and CT connector. Install internal grapple connector. PJSM for pulling CT across. Crew positions and communications were discussed. Pull CT across and secure it to shipping reel. 21:40 -Fill well with 5 bbls. Remove 1502 line from inside reel. Start BOP test. Test witness waived by AOGCC inspector Chuck Scheve. PJSM, then lower pinholed reel onto trailer. Secure reel to trailer, spot new reel in position, lift into reel house. Finish BOPE test w/ all rams, annular, and stabbing valve tested. RU 1502 hardline in reel Continue to prep reel for pulling CT across. Meg test wire at junction box. Check brass in injector 03:30 -Fill well with 5 bbls. 05:00 -Fill well with 6 bbls. Safety mtg re: pull CT to injector Install internal grapple and PT. Pull CT to floor and stab into injector. Replace packoff Rev fill CT w/ 3 bbls McOH followed by FW PT hardline, inner reel valve and packoff as part of BOPE test Attempt to pump slack back at 3.8 bpm w/o success (1 preloaded in FF reel-15700') Dress CT stub and install CTC (twice). PT 40k. Head up BHI. Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations 11/24/2008 12:00 - 15:00 3.00 DRILL P PROD1 PT 4000 MU BHA while pump slack forward over the bunghole 2.4/1500 and displace CT back to mud. Standback BHA 15:00 - 20:30 5.50 DRILL N SFAL PROD1 Check injector gripper blocks/elastomers and need to replace more elastomers. SWS decide to replace all gripper blocks and elastomers. Crew begin removing the same while mechanics and parts are enroute. 20:00 -Fill well with 2 bbls. 20:30 - 21:20 0.83 DRILL P PROD1 Gripper blocks finished, PJSM for P/U BHA. M/U BHA #16 - 3.25" x 4.25" bicenter + 1.2 deg AKO + Agitator + 3.0" CoilTrak. 21:20 - 23:45 2.42 DRILL P PROD1 RIH BHA #16. Pump min rate through bit while RIH. Log from 11,000 ft down at 275 ft/hr. No correction. Continue RIH. Stop at 11,284 ft and verify end stop position of orienter, OK. 23:45 - 00:00 0.25 DRILL P PROD1 Pass through window at 30L TF, RIH to find bottom. 11/25/2008 00:00 - 03:05 3.08 DRILL P PROD1 Tag bottom at 12,607 ft. Drill at 2.50 / 2.47 bpm @ 3200-3800 psi. PVT = 255 bbls. Maintain 97 deg inc for now, continue LH turn. Initial ROP is 60 fUhr. Some wt stacking. Past 12,710 start to reduce inc to 93, start RH turn. Drill to 12,750 ft. 03:05 - 04:50 1.75 DRILL P PROD1 Wiper trip to window. Up wt is 47 Klbs. Clean pass up and down. 04:50 - 07:00 2.17 DRILL P PROD1 Drill from 12,750 ft. 2.58 / 2.56 bpm C~ 3400-3900 psi. PVT = 234 bbls. ROP is 80 - 120 ft/hr with DWOB = 1-3 Klbs, CT wt 19 Klbs while drilling. Drill from 12854' 2.47/3250/108 w/ 300-600 dill, 1.5-2.5k wob w/ 9.61 ECD at 60-100'/hr at 97 degw/ +20k string wt Drill to 12900' and see res trending down PVT 229 07:00 - 07:45 0.75 DRILL P PROD1 Wiper to window 07:45 - 08:05 0.33 DRILL P PROD1 Pull thru window, open EDC and jet liner to 10900' 08:05 - 08:15 0.17 DRILL P PROD1 Log tie-in at 300'/hr, corr +8.5'. Close EDC 08:15 - 09:05 0.83 DRILL P PROD1 Wiper to TD Bleed IAP from 635 psi to 400 psi due to feeding in McOH and clabbering mud due to wellbore warming from hot reservoir 09:05 - 11:20 2.25 DRILL P PROD1 Drill from 12900' 2.44/2.38/3250/1108 w/ 200-500 psi diff, 0.8-2.5k wob w/ 9.58 ECD at 97 deg. Differential sticky while surveying at 12933' and 13000'. Drill to 13050' 11:20 - 13:15 1.92 DRILL P PROD1 Wiper to window 13:15 - 15:50 2.58 DRILL P PROD1 Drill from 13050ft 2.44/2.38/3250/1108 w/ 200-500 psi diff, 0.8-2.5k wob w/ 9.58 ECD at 97 deg. Drill to 13200ft. 15:50 - 17:35 1.75 DRILL P PROD1 Wiper to the window. Open EDC & jet to 10,000ft & back down to 11,000ft. 17:35 - 17:45 0.17 DRILL P PROD1 Log down for tie-in from 11000ft, RIH to 11,100ft & correct depth (+10ft corr). 17:45 - 19:10 1.42 DRILL P PROD1 Wiper to window, Open EDC jet tubing to 10,900 ft. RIH and tie in C~ 11,020' w/ +10 ft correction Continue wiper to bottom. 19:10 - 20:25 1.25 DRILL P PROD1 Drill ahead from 13,205 ft. While swaping mud systems to new Printetl: 12/8/2008 7'L:Ll::i4 F'M BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ~', From - To Hours Task Code I NPT ' Phase Description of Operations 11/25/2008 19:10 - 20:25 1.25 DRILL ~ P PROD1 FloPro. 20:25 - 00:00 3.58 DRILL P PROD1 11/26/2008 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 01:10 0.92 DRILL P PROD1 01:10 - 01:55 0.75 DRILL P PROD1 01:55 - 02:55 1.00 DRILL P PROD1 02:55 - 04:55 2.00 DRILL P PROD1 04:55 - 05:20 0.42 DRILL P PRODi 05:20 - 06:40 1.33 DRILL P PROD1 06:40 - 09:30 2.83 DRILL P PROD1 09:30 - 11:30 2.00 DRILL P PROD1 11:30 - 13:00 1.50 DRILL P PROD1 13:00 - 14:40 1.67 DRILL N DFAL PRODi 14:40 - 17:00 2.33 DRILL N DFAL PROD1 17:00 - 19:20 2.33 DRILL N DFAL PROD1 19:20 - 23:15 3.92 DRILL N DFAL PROD1 23:15 - 00:00 0.75 DRILL N DFAL PROD1 11/27/2008 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 01:45 0.25 DRILL N DFAL PROD1 Drill to 13,238 ft. Failing to get required turn rate to stay in polygon, need 12 deg/100 ft build and only getting 8 deg and 5 deg/100 ft. Consult with Town GEO and DD. Decied to POOH for AKO change. POOH for AKO change. Pump min rate through window. Open EDC and pump 3.0 bpm PJSM while POOH on BHA LD Unstab injector and LD BHA #16 Change AKO from 1.2 deg to 1.6 AKO Verify Internal scribe while OOH. PU BHA #17 Stab onto well. RIH with 1.6 deg AKO BHA. 0=.37 bpm Log for GR tie in Stop at 11,270 ft and correct - 3 ft. Continue to RIH Pump 2.50 bpm in open hole section. Drill lateral section from 13,238ft with 110E TF. Op = 2.46 / 2.41 bpm at 3600 psi fs Density = 8.65 / 8.70 ppg WOB 1.Ok-2.5K BHP /ECD /WHP = 4350 psi / 9.4 ppg / 30 psi Vp = 279 bbl DHCT = 180degF SCT=95degF ROP at 50-110 fph Drill to 13,400ft. Slightly sticky at 13,300ft. Wiper to the window & to TD -clean. Drill lateral section from 13,400ft with 110E TF. Op = 2.49 / 2.41 bpm at 3600 psi fs Density = 8.67 / 8.70 ppg WOB 1.Ok-2.OK BHP/ECD/WHP=4950psi/9.5ppg/40 psi Vp = 252 bbl DHCT = 180degF SCT=101 degF ROP at 50-110 fph Drill to 13,511ft. Tool failure. Wiper to the window. PUH to 10,000ft. Test inner reel a-line connections - ok. POH & pump 2.7bpm through the bit. No losses while POH. PJSM regarding handling BHA. Flow check. Pop off well. Blow down BHA. Inspect CTC -good. Test a-line -good. Inspect agitator -good. Inspect bit - 1 chipped cutter on the snout. LD BHA #17. Test tools on the catwalk. Replaced tool string Makeing up BHA #18 now and tested OK on catwalk. PU tools and stab on well. Tools tested bad once stabed on well. Still having trouble communicating to tool string with MWD computers. Un-stab from well, LD tools again and test on cat walk. P&C was bad, changed out P&C with old P&C from BHA #17 with new lower half, now BHA #18 which tested good. RIH with BHA #18 Continue to RIH lost 15 bbls on RIH to 11,000 ft Log for GR tie in ~ 10,986 ft. -2 ft correction. Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ', Code NPT Phase 11/27/2008 101:45 - 04:55 3.171 DRILL N DFAL PROD1 04:55 - 05:25 0.501 DRILL P PROD1 05:25 - 08:10 I 2.751 DRILL I P I I PROD1 08:10 - 09:35 I 1.421 DRILL I P I I PROD1 09:35 - 11:15 1.67 DRILL P PROD1 11:15 - 11:25 0.17 DRILL P PROD1 11:25 - 13:45 2.33 DRILL P PROD1 13:45 - 16:20 2.58 DRILL N DFAL PROD1 16:20 - 17:45 1.421 DRILL N DFAL PRODi 17:45 - 19:40 1.921 DRILL N DFAL PROD1 19:40 - 19:55 0.25 DRILL N DFAL PROD1 19:55 - 22:30 2.58 DRILL P PROD1 Spud Date: 10/29/1988 11 /11 /2008 End: 12/4/2008 Description of Operations Continue to RIH Pump min rate through window 0=2.23/2.34 ~ 22.5 fpm in open hole. Cp slowly pressuring up to 4000 psi ~ 11,700 NO WOB back to normal by 11,770 ft Cp Pressuring up faster @ 12,650 ft to 4000 psi light WOB. Multiple tries with Op=2.25 bpm Pressure would come down while picking up. This is a low spot. Push through with 0=1.0 bpm to 12,700 ft Wiper back to 12,350 ft with 0=2.5 bpm. Continue to RIH small pressure increases till about 13,000 ft. Tag bottom at 13,519 ft and drill ahead. Drilling ~ 13,530 ft Op=2.46/2.41 bpm C~3 3500 psi Den=8.66/8.74 ppg ECD=9.6ppg Press Diff=1390 psi DH WOB=1080 # CT WT=19,850#'s ROP=2 fpm / 120 FPH SEVXYX=3 drilled to 13,605 ft keep stacking out after 3 BHA wipers and still stacking, Wiper to window. PVT=419 bbls. Wiper to window & to TD -motor work at 12,550ft. 0=2.68/2.48 bpm ~ 25 fpm and 3340 psi. Drill lateral section from 13,605ft with 120R TF. Op = 2.46 / 2.41 bpm at 3150 psi fs Density = 8.69 / 8.71 ppg WOB 1.Ok-2.5K BHP/ECD/WHP=4430 psi/9.55 ppg/30 psi Vp = 405 bbl ROP at 80-110 fph Drill to 13,680ft. Stacking, won't drill. 500ft wiper. Drill lateral section from 13,680ft with 120R TF. Op = 2.46 / 2.41 bpm at 3150 psi fs Density = 8.69 / 8.71 ppg WOB 1.Ok-2.5K BHP/ECD/WHP=4430 psi/9.55 ppg/30 psi Vp = 405 bbl ROP at 80-110 fph Drill to 13,730ft. Stacking, won't drill. Wiper trip, again. BHA is plugging up. Broke circulation at 4700psi. BHA keeps wanting to plug up. POH. Open EDC & jet while POH. Will change out motor, agitator & float sub. Rebuild pump #1. Flow check. Pop off well. Blow down BHA. Swap out agitator, motor, float sub. Bit was fine, motor was fine, no trash above agitator -test was good, float sub was fine. Take apart UOC - no trash on flow sub. MU new motor + new agitator + new float sub. Stab onto well. Power up & test tools. Set counters. RIH, test agitator while RIH -good. Lost 12 bbls on the way in hole to 11,000 ft Log for GR tie in from 11,015 ft to 11,064 ft. -4 ft correction PUH to 10,900 ft and log to 11,500 ft for GEO's log tie in of OH Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 11/27/2008 19:55 - 22:30 2.58 DRILL P PRODi logs to cased hole. 22:30 - 23:45 1.25 DRILL P PROD1 Continue to trip in hole. 23:45 - 00:00 0.25 DRILL P PROD1 Tag bottom ~ 13,736 ft and drill ahead. Drill to 13,746 ft midnight depth. 11/28/2008 00:00 - 01:00 1.00 DRILL P PROD1 Continue drilling ahead Drilling C~3 13,746 ft Op=2.27/2.23 bpm C~ 3560 psi Den=8.72/8.75 ppg ECD=9.71 ppg Diff Press=1293 psi DH W0B=1610#'s CT WT=13,747#'s ROP=.7 fpm / 41 FPH SEVXYX = 5 PVT=344 bbls ~ 13,748 ft increased WOB to 2680 #'s to improve SEVXYX = 2 ROP=2.0 fpm / 120 FPH Drill to 13,835 ft 01:00 - 03:15 2.25 DRILL P PROD1 Wiper trip while GEO's evaluate / decied to drill further. Op=2.76/2.62 bpm @ 4100 psi Pressure is wandering up and down slowly +/-200 psi. C~ 11,440 ft Op=2.73/2.56 C~ 3550 psi Still wandering +/- 500 psi HOT failed about 12,000 ft. Pump min rate and pull through window Stop open EDC, Failed too. 03:15 - 03:35 0.33 DRILL N DFAL PROD1 PUH for GR tie in Log down from 11,010 to 11,070 ft C~ 11,058 ft the rest of the BHA quit working. 03:35 - 06:00 2.42 DRILL N DFAL PROD1 POOH after complete tool failure. Fill hole across the top. 06:00 - 07:35 1.58 DRILL N DFAL PROD1 Crew change, PJSM on LD of BHA. Blow down BHA. Swap out entire tool string & leave out agitator. 07:35 - 09:35 2.00 DRILL N DFAL PROD1 RIH. 09:35 - 09:45 0.17 DRILL N DFAL PROD1 Log down for tie-in (-aft corr. 09:45 - 10:05 0.33 DRILL N DFAL PROD1 PUH to 10150ft. 10:05 - 10:30 0.42 DRILL P PROD1 Log down CCL from 10,170ft to 10,400ft for proper TOL placement. 10:30 - 12:25 1.92 DRILL P PROD1 RIH & wiper to TD -amazingly clean. Tag TD at 13,835ft. 12:25 - 13:45 1.33 DRILL P PROD1 POH laying in 150k LSRV liner pill. 13:45 - 16:00 2.25 DRILL P PROD1 Open EDC & POH. PJSM while POH. 16:00 - 16:50 0.83 DRILL P PROD1 Pop off well. Blow down & LD BHA. Cut off CTC. 16:50 - 18:45 1.92 CASE P RUNPRD Cut off CTC & pump out 304ft of a-line (twice as much as the paperwork says we have!). Prep end of a-line. RU handling equipment w/ Doyon torque turn equipment. Hoist BOT equipment to the RF. 18:45 - 19:45 1.00 CASE P RUNPRD Remove SLB CTC and Install BTT CTC. PT & pull test CTC. 19:45 - 20:05 0.33 CASE P RUNPRD PJSM on running liner 20:05 - 20:30 0.42 CASE P RUNPRD Run liner. PU liner. 20:30 - 20:50 0.33 CASE N HMAN RUNPRD When starting to MU Float and latch collar assembly with Eckels, crew referenced a torque value sheet that was made up and in dog house. The torque values for 2 7/8" STL were listed on his sheet as 1,500-1,800 ft-Ibs vs actual of 800-1000 ft-Ibs. Latch collar and 4 ft pup joint were damaged. Pulled assembly out of hole to re inspect all joints and wait on new Printed: 12/8/2008 12:21:34 PM ~ ~ BP EXPLORATION Page 14 of 19 Operations. Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date Frorn - To ', Hours Task Code NPT Phase. Description of Operations 11/28/2008 20:30 - 20:50 0.33 CASE N HMAN RUNPRD parts from Baker. 20:50 - 21:55 1.08 CASE N HMAN RUNPRD Wait on replacement parts. 21:55 - 22:10 0.25 CASE N HMAN RUNPRD Re make up Float, landing collar, and pup joint. 22:10 - 00:00 1.83 CASE P RUNPRD Continue to make up liner following CTD Liner running RP. In finding optimal field MU torque as per section 5.7 with the help of Doyon torque turn services. optimum was in the book range between 800 to 1000 ft-Ibs. 11/29/2008 00:00 - 08:30 8.50 CASE P RUNPRD Continue to pick up liner using Doyon Torque Turn services. Stopping to fill liner every 10 jnt's. 08:30 - 10:00 1.50 CASE P RUNPRD RIH w/liner. WT ck at window 56k up wt. Run in OH at 100ft/min. Start setting down at 12,850ft & made it to 13,522ft. Work pipe, 65-72k up WT. Attempt to pump while RIH 0.5bpm/1500psi -hydraulics us out. PU 72k, pump 1.68bpm/2600psi & slowly PUH to 13,000ft to clean up the hole. WT slowly dropped to 47k-52k. 10:00 - 10:40 0.67 CASE P RUNPRD PU 72k, pump 1.68bpm/2600psi & slowly PUH to 13,000ft to clean up the hole. WT slowly dropped to 47k-52k. 10:40 - 11:00 0.33 CASE P RUNPRD RIH at 80Wmin & made it to 13,610ft. 11:00 - 11:25 0.42 CASE P RUNPRD PU 72k, pump 1.8bpm/2500psi & slowly PUH to 13,450ft to clean up the hole. WT slowly dropped to 49k-52k. 11:25 - 11:35 0.17 CASE P RUNPRD RIH at 80Wmin & made it to 13,628ft. 11:35 - 12:10 0.58 CASE P RUNPRD PU 72k, pump 2bpm/2600psi & slowly PUH to 13,450ft to clean up the hole. WT slowly dropped to 49k-52k. Pump 15bb1 hi-vis pill. 12:10 - 12:25 0.25 CASE P RUNPRD RIH at 50ft/min -smooth. Tag up at 13,625ft. 12:25 - 12:50 0.42 CASE P RUNPRD Slowly PUH & pump hi-vis pill out of liner at 2.2bpm/2800psi. Pump 20 bbl 2% KCL to-vis pill. 12:50 - 13:00 0.17 CASE P RUNPRD RIH at 100fUmin. Tag up several times at 13,625ft. 13:00 - 13:40 0.67 CASE P RUNPRD Slowly PUH & pump to-vis pill out of liner at 2.2bpm/2400psi. 13:40 - 13:45 0.08 CASE P RUNPRD RIH. Tag up at 13,625ft. 13:45 - 17:05 3.33 CONDH N DPRB RUNPRD . Circulate out to-vis pill while POH. Hi-vis pill revealed some cuttings. PJSM while POH. 17:05 - 23:40 6.58 CONDH N DPRB RUNPRD Tag up. Flow check well. Pop off. LD CTLRT. Lay down 14 jnts of 3.5" VamTop. Stand back liner in the derrick. While standing back 3.5" VamTop liner noticed "scraching or scaring" on Stands 13 through 17, or Jnt's 68 - 77. Deep enough to catch a finger nail but un-measurable. Cementralizers were pretty balled up too. Lost 9 bbls on trip out. 23:40 - 00:00 0.33 CONDH N DPRB RUNPRD SLB serviced injector and inspected chain bearings. 11/30/2008 00:00 - 00:30 0.50 CONDH N DPRB RUNPRD Continue to service injector chains. 00:30 - 01:00 0.50 BOPSU P RUNPRD Perform Weekly BOP Function test as per AOGCC regs and well permit. While SLB continues inspections. Replaced 7 pins in injector chains. 01:00 - 01:15 0.25 CONDH N DPRB RUNPRD PJSM for pumping slack and cutting coil. 01:15 - 03:50 2.58 CONDH N DPRB RUNPRD Pick up injector, cut off BTT CTC, stab on well and pump for slack management. Unstab from well cut 374 ft of coil. Tested eline. Test good with 800 Meg Ohms and res of 52 ohms. MU SLB CTC. Pull test to 40,000 #'s and Pressure tested to 3,500 psi. 03:50 - 05:00 1.17 CONDH N DPRB RUNPRD MU BHI's UOC and test. First test failed cleaned up connection and passed with 1260 meg ohms and 67 ohms. Printed: 12/8/2008 12:21:34 PM BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours I Task Code NPT ! Phase Description of Operations 11/30/2008 05:00 - 05:10 0.17 CONDH N DPRB RUNPRD PJSM on PU of drilling BHA. 05:10 - 05:40 0.50 CONDH N DPRB RUNPRD PU drilling BHA. Stab on well. 05:40 - 07:35 1.92 CONDH N DPRB RUNPRD RIH with drilling BHA for clean out run. 07:35 - 07:45 0.17 CONDH N DPRB RUNPRD Log down for tie-in (+3ft). 07:45 - 10:45 3.00 CONDH N DPRB RUNPRD Wiper to TD, 2.55bpm/2900psi. Set down twice at 13,780ft, 30k overpull. Backream to 13,600ft. Set down w/ no motor work at 13775ft & 13765ft. Reduce pump rate to 1 bpm, set down ~ 13,750ft but popped through & no further past 13,790ft. Clean PU, backream to 13,750ft using 2.75bpm/3200psi. set down at 13,775ft w/ no motor work & no WOB -appears to be further up hole. 10:45 - 11:15 0.50 CONDH N DPRB RUNPRD Backream from 13,790ft to 13,600ft, no motor work & clean PU. 11:15 - 11:40 0.42 CONDH N DPRB RUNPRD Slowly wiper to TD. Tag up at 13,772ft, drop pump rate to 1 bpm & got past. Very ratty past 13,775ft. Tag bottom at 13,833ft. 11:40 - 13:10 1.50 CONDH N DPRB RUNPRD Backream from 13,833ft to 13,500ft, no motor work & clean PU. 13:10 - 13:23 0.22 CONDH N DPRB RUNPRD Wiper to TD. Slight motor work at 13,775ft, 13,805ft. Tag at 13,833ft. 13:23 - 18:45 5.37 CONDH N DPRB RUNPRD Backream/ream (very clean PU) from 13,833ft to 13,700ft while pumping 15bb1 hi-vis followed by 290bb1s of fresh flo-pro liner pill. Lay in from TD. Open EDC in the 5-1/2" liner & slowly PUH to jet liner. 18:45 - 18:55 0.17 CONDH N DPRB RUNPRD PJSM on stand back injector and LD drilling BHA. 18:55 - 19:35 0.67 CONDH N DPRB RUNPRD Stand back injector and LD BHI drilling BHA. 19:35 - 20:15 0.67 CONDH N DPRB RUNPRD Pump out 341 ft of Eline from coil. 20:15 - 21:00 0.75 CONDH N DPRB RUNPRD Clean up rig floor and RU for running liner. 21:00 - 21:15 0.25 CONDH N DPRB RUNPRD PJSM for running liner and installing BTT CTC. 21:15 - 21:45 0.50 CONDH N DPRB RUNPRD Install BTT CT connector. Pull test to 40,000 #'s Pressure test to 3,500 psi Stand back injector. 21:45 - 00:00 2.25 CONDH N DPRB RUNPRD pick up liner. 12/1/2008 00:00 - 05:00 5.00 CONDH N DPRB RUNPRD Continue to pick up liner. Lost 9 bbls picking up liner. PU BTT SELRT and 3 Jnt's 2 3/8" PH-6. PU Injector and stab on well. 05:00 - 07:00 2.00 CONDH N DPRB RUNPRD RIH with liner. Op=0.26/0.48 bpm ~ 90 fpm with trips set ~ 1,500 psi X7,500 ft Op=0.22/0.73 031250 psi ~ 96 fpm. WT ck at window 53k. RIH @ 100ft/min, start stacking out at 12,700ft. Place liner at 13,835ft. 07:00 - 08:50 1.83 CONDH P RUNPRD Circulate 2bpm/2600psi, 1.5bpm/2000psi. Line up for ball drop position. Fill pits w/ slick 2% KCL. Bring on &vis up 40 bbls of Biozan to assist in ball dropping. 08:50 - 11:25 2.58 CEMT P RUNPRD Pump 10bb1 hi-vis pill w/ 5/8" ball followed by slick 2% KCL. Landed at 43.3bbls, pressure up & shear C~1 4000psi. PU - released from liner - PU ift. Circulate well to slick 2% KCL. With well swapped over, final rate 3bpm/1350, 1.5bpm/430psi. While pumping 3.04bpm in/2.94bpm out 11:25 - 11:40 0.25 CEMT P RUNPRD PJSM regarding pumping cement. Printed: 12/8/2008 12:21:34 PM ~ ~ BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: Y-25 Common W ell Name: Y-25 Spud Date: 10/29/1988 Event Nam e: REENTE R+COM PLET E Start : 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To-, Hours I', Task Code NPT Phase'.. Description of Operations 12/1/2008 11:40 - 12:40 1.00 CEMT P RUNPRD Continue to circulate 3bpm/1320psi. Batch up 50bbls of class 'G' cement, starting at 12:15. Pump bio to reel iron. P.T. cement iron 250/3800psi. 12:40 - 16:20 3.67 CEMT P RUNPRD Pump 43.8bbls of class 'G' cement 2bpm/2000psi. Clean up cement line. Swap to rig pumps & displace cement w/ biozan ~ 2.57bpm/2160psi. Pressured up at 43.8bbls away w/ 4.3bbls on the backside. Bleed off pressure, PU & unsling from the liner. Exhaust 14bbls of cement & 5bbls of biozan. Sting back into the liner & presure up to 4600psi -holding. P.T. cementers to 9500psi. Pressure up liner to 7800psi-holding. Bleed off & ramp upon pressure 5 times to 7800psi. Unsling & pump 60bbls of bio followed by slick 2% KCL ~ 5.8bpm/4100psi - very little cement recovered, total pump 1.5 times BU. Sting back into the liner, tagged Eft higher. Pressure up -got returns. Pump down coil & sting into liner. Pressure up to 7800psi - solid. 16:20 - 18:40 2.33 CEMT N CEMT RUNPRD POH pumping 18:40 - 18:50 0.17 CEMT N CEMT RUNPRD PJSM on LD of BHA 18:50 - 20:00 1.17 CEMT N CEMT RUNPRD Unstab injector, Pull BHA. Bottom stinger of SELRT was broken off. Very clean break in top threaded section inside bottom of piston from SELRT. 20:00 - 22:10 2.17 CEMT N CEMT RUNPRD Jet out BOP stack. Get off well for BOP inspection. Inspect BOP and shell test. Check screen in reel house, and standing iron. ---while consulting with Baker and Town on plan forward. 22:10 - 22:20 0.17 CEMT N CEMT RUNPRD PJSM on PU of milling BHA. 22:20 - 22:55 0.58 CEMT N CEMT RUNPRD PU milling BHA #24 with 4.55" diamond parabolic mill to clean out 5 1/2 liner. 22:55 - 00:00 1.08 CEMT N CEMT RUNPRD RIH with BHA #24 Clean to 6,000 ft at midnight 12/2/2008 00:00 - 01:30 1.50 CEMT N CEMT RUNPRD Continue to RIH Op=2.23/2.42 bpm C~? 980 psi den=8.44/8.54 ppg Clean all the way in to 10,012 ft then small bobble and little motor work that quickly went away. Clean again to 10,308.8 ft tagged again and motor stalled. Dry tag again C~3 10,307.7 ft. 01:30 - 03:45 2.25 CEMT N CEMT RUNPRD POOH Op=2.72/2.40 bpm ~ 1350 psi den= 8.45/8.59 ppg Contact SL PE for unit ~ 01:50 03:45 - 03:55 0.17 CEMT N CEMT RUNPRD PJSM on LD of BHA and standing injector back on it's legs 03:55 - 04:20 0.42 CEMT N CEMT RUNPRD LD milling BHA # 24 No markings on Mill. 04:20 - 05:00 0.67 CEMT N CEMT RUNPRD Wait on SLB SL unit to arrive. 05:00 - 05:20 0.33 CEMT N CEMT RUNPRD PJSM for spotting in SL unit and RU. 05:20 - 09:30 4.17 CEMT N CEMT RUNPRD Spot unit and RU to run 4.40" LIB. Install night cap & circulate across the top to keep the hole full _ 12bbls in the first hour. 16bbls over all & seems stable at 7:30am. 09:30 - 11:30 2.00 EVAL N CEMT RUNPRD Run 4.0" od LIBH. Tag TOL at 10,348'. POOH. PD tools. LIB shows inpression of TOL. No indication of stinger. 11:30 - 13:30 2.00 EVAL N CEMT RUNPRD Run 3.8" OD LIB. Tag at 10,354'. POOH. No indication of stinger. Printetl: 12/82008 1L:'Ll:J4 YM L_~ BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ', From - To Hours.. Task Code.-NPT Phase Description of Operations - _ - 12/2/2008 13:30 - 16:00 2.50 EVAL - N CEMT RUNPRD -- Run 2.80" LIB. Tag aluminum profile in liner top sleeve. POOH. 16:00 - 17:00 1.00 EVAL N CEMT RUNPRD Evaluate LIB information. 17:00 - 19:00 2.00 EVAL N CEMT RUNPRD Hold PJSM. RD SLB slickline unit. 19:00 - 20:00 1.00 EVAL N CEMT RUNPRD Wait on Baker mill to arrive, Discuss with town problem of 2.80" mill and decide to go with 2.31 "Diamond Parabolic Mill. 20:00 - 20:10 0.17 REMCM N CEMT RUNPRD PJSM for MU of milling BHA 20:10 - 20:50 0.67 REMCM N CEMT RUNPRD PU milling BHA #25 with 2.31 DPM and No jars. 20:50 - 23:10 2.33 REMCM N CEMT RUNPRD RIH with BHA #25 Tag ~ 10,265.8 ft 23:10 - 23:30 0.33 REMCM N CEMT RUNPRD PU with 40K UP WT Tag again slower C~3 10,263 ft PU and set down again at .5 fpm Tagged ~ 10,262.9 ft and stalled again. Op=1.61/1.58 bpm C~ 1556 psi 23:30 - 00:00 0.50 REMCM N CEMT RUNPRD Time mill ahead from 10,262.8 ft ~ 0.1 fU4 min. Qp=1.64/1.62 bpm ~ 1315 psi 12/3/2008 00:00 - 05:15 5.25 REMCM N CEMT RUNPRD Continue to time mill ahead. X00:15 no more Motor Work while continuing to stack weight. Weight quickly mills off when not pushing. Set down to 10,264 ft. PU to 10,255 ft to verify free spin and not sticking. Set back down at 10,264 with 2200 CT WOB and no motor work, continue to push ROP of 14 FPH very little change in CP. FS=1315 psi and CP=1330 psi, 10,265 ROP=3.6 FPM / 215 FPH. ~ 10,269.75 ft Motor Work with CP=1420 psi with 2,700 CT WOB ROP=0.2 fpm / 13 FPH Stalled ~ 10,273 after CP worked up to 1580 psi. Mill down to 10,288.8 ft and PU with wiper to 10,255 ft. While wipering down got CP=1800 psi ~ 10,277 ft, milled off to 1500 psi and slowly milling down again. stalled ~ 10,277.8 ft and stalled. continued to stall 7 times slowly working down to 10,290 ft. With first BU sample around 187 bbls had some aluminum, and lots of green cement. (182.35 bbl for BU from first Tag) With 290 bbls out got a VERY small peice of rubber? out across shakers. BU from area and time of stalling C~ 10,278 ft and 478 bbls out still cement, scale, hard black grit, and some "schmoo" lumps. Milled to 10,295 ft. -Consensus is "no rubber" 05:15 - 08:00 2.75 REMCM N CEMT RUNPRD POOH keeping pit watcher in pits to watch the shakers. 0=1.63/1.51 bpm @ 22 fpm. 08:00 - 09:00 1.00 REMCM N CEMT RUNPRD Lay down milling BHA. 09:00 - 19:10 10.17 DEMOB P POST Run 1-1/4" CSH into well from derrick. 19:10 - 20:10 1.00 DEMOB P POST Pull out of hole and LD CSH in singles. Remove from pipe shed. Place in storage bunk. Also cut off BTT CTC and install SLB CTC. Printed: 12/8/2008 12:21:34 PM • BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations - 12/3/2008 19:10 - 20:10 1.00 -- DEMOB P - POST Pull tested to 35K and PT to 3500 psi. 20:10 - 20:55 0.75 DEMOB P POST MU up stinger BHA with BHI's UOC & LOC for eline anchor and checks. 20:55 - 21:30 0.58 DEMOB P POST RIH with stinger to displace well to KCL and FP 21:30 - 21:45 0.25 DEMOB P POST PJSM with LRHOS and crew on RU of LR to IA. 21:45 - 22:45 1.00 DEMOB P POST Continue to RIH while LRHO rigs up to IA. 22:45 - 00:00 1.25 DEMOB P POST Freeze protect IA with LRHOS 12/4/2008 100:00 - 00:25 0.421 DEMOB ~ P 00:25 - 01:45 I 1.331 DEMOB I P 01:45 - 02:15 0.50 DEMOB P 02:15 - 02:55 0.67 DEMOB P 02:55 - 03:10 0.25 DEMOB P 03:10 - 04:00 0.831 DEMOB ~ P 04:00 - 04:20 0.33 DEMOB P 04:20 - 05:00 0.67 DEMOB P 05:00 - 07:00 2.00 DEMOB N 07:00 - 08:30 1.50 DEMOB P 08:30 - 11:30 I 3.001 DEMOB I P 11:30 - 14:45 I 3.251 DEMOB I P 14:45 - 19:00 I 4.251 DEMOB I P Starting IA pressure 349 psi. Slowly walk pumps up to 1.5 bpm @ 570 psi IA press. Had to hold back pressure on Well head to maintain 1 for 1 returns Slowed LR pumps down to 1 bpm out. lowest density was 4.99 ppg mostly 5.5 ppg WH=359 psi IA = 845 psi pumped 85 bbls by 00:00 POST Finish pumping with LRHOS pumped 105 bbls diesel in IA. With pumps down IA=375 psi WH=22 psi. IA Fp to 2,400 ft POST Displace 5 1/2" tubing to KCL 0=2.15/1.96 den=8.44/7.67 After 50 bbls out den=8.44/8.43 POST Load coil with 55 bls diesel from LRHOS den=6.89/8.6 ppg POST Continue displacement with rig pump while POOH. PJSM with Valve crew on setting BPV. POST Tag up, close the swab. IA=134 OA=11 and WH =0 (before it was shut in) Stand back injector and LD nozzle. POST Install night cap open swab and monitor well. No well head pressure /flow. With well dead, dry rod in BPV. Difficulty getting BPV set. Found SSV partly closed. Opened SSV and set BPV. POST PJSM on blow down of Coil. POST Stab back on well and pump SLB chemical cocktail. Blow down with N2. SFAL POST SLB N2 truck broke down. Heater will not fire off. SLB to dispatch mechanics, replacement truck unavailable. POST Replacement pumper in place and rigged up. Hold second PJSM to discuss job with day crew. Displace reel to N2. Blow down to tiger tank. Rig down SLB N2 unit. POST Hold PJSMs to discuss unstabbing coil. MU grapple and pull test same. Unstab coil and pull back to reel. Secure coil on rail. POST Spot Veco truck. Hold PJSM to lower reel to bed truck. Remove reel from rig. POST Continue to prep for rig move. Clean pits. Printed: 12/8/2008 12:21:34 PM • BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: Y-25 Common Well Name: Y-25 Spud Date: 10/29/1988 Event Name: REENTER+COMPLETE Start: 11/11/2008 End: 12/4/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 12/4/2008 14:45 - 19:00 4.25 DEMOB P POST Complete pit leak repairs. Thaw and clean cuttings box. Change packoffs. Remove injector gripper blocks. ND BOPS. 19:00 - 20:00 1.00 DEMOB P POST NU Tree cap and PT to 3500 psi. -Passed Rig released from y-25A ~ 20:00 Hrs. Printed: 12/8/2008 12:21:34 PM °9 ~ BP Alaska by u°~~~ Baker Hughes INTEQ Survey Report r~~~ BAKER Yll[~Y~~ . -~..~ Company: BP Amoco Date: 12/1/2008 "time: 10:07:04 Pagc: 1 i Field: Prudhoe Bay Cu-ordinate(NE) Reference: Well: Y-25, True North I Site: PB Y Pad Vertical (TVll) Reference: 37:25 10/29/1988 00:00 78.7 Well: Y-25 Section (VS) Reference: Well (O.OON,O.OOE,278.OOAzi) Wellpath: Y-25A Survey. Calculation Method: Minimum Curvature llb: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Site: PB Y Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-25 Slot Name: 25 Y-25 Well Position: +N/-S 369.16 ft Northing: 5948849.82 ft Lafitude: 70 16 3.666 N +E/-W -3094.04 ft Easting : 644648.28 ft Longitude: 148 49 49.050 W Position Uncertainty: 0.00 ft Wellpath: Y-25A 500292188301 Drilled From: Tie-on Depth: Y-25 11297.00 ft Current Datum: 37:25 10/29/1988 00:00 Height 78.70 ft Above System Datum: Mean Sea Level Magnetic Data: 9/2/2008 Field Strength: 57672 nT Declination: Mag Dip Angle: 23.00 deg 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.70 0.00 0.00 278.00 Survey Program for Definitive Wellpath Date: 9/3/2008 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 11297.00 1 : Schlumberger GCT multi shot GCT-MS Schlumberger GCT multishot 11305.00 13835.00 MWD (11305.00-13835.00) MWD MWD -Standard Annotation MD TVD ft ft 11297.00 8992.10 TIP 11305.00 8993.95 KOP 13835.00 9043.81 TD Survey: MWD Start Date: 11/21/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey i~1D Incl ft deg 11297.00 76.50 • 11305.00 76.71 11340.59 80.28 11371.84 86.17 11405.59 87.22 11405.80 87.23 11430.35 87.49 11462.51 90.15 11488.41 89.02 11510.51 87.70 11536.12 92.46 Azim deg TVD ft Sys TVD ft N/S ft 282.20 8992.10 8913.40 2290.70 282.28 8993.95 • 8915.25 2292.35 275.52 9001.05 8922.35 2297.73 269.68 9004.74 8926.04 2299.12 263.50 9006.69 8927.99 2297.12 263.46 9006.70 8928.00 2297.09 258.94 9007.83 8929.13 2293.34 253.08 9008.49 8929.79 2285.57 246.90 9008.68 8929.98 2276.72 241.81 9009.31 8930.61 2267.16 239.19 9009.28 8930.58 2254.55 E/W ft MapN ft - MapE ft - - VS ft DLS Tool deg/100ft - -4932.12 _ 5951045.15 639673.43 5202.86 0.00 MWD -4939.72 5951046.66 639665.80 5210.62 2.80 MWD -4974.15 5951051.37 639631.27 5245.46 21.14 MWD -5005.13 5951052.17 639600.28 5276.33 26.44 MWD -5038.74 5951049.52 639566.71 5309.34 18.55 MWD -5038.95 5951049.50 639566.50 5309.54 18.38 MWD -5063.18 5951045.28 639542.35 5333.01 18.42 MWD -5094.36 5951036.91 639511.33 5362.81 20.01 MWD -5118.69 5951027.59 639487.18 5385.67 24.26 MWD -5138.59 5951017.65 639467.46 5404.05 23.78 MWD -5160.88 5951004.62 639445.43 5424.36 21.21 MWD ~tib°~; ~ BP Alaska ;~p~~~ by Baker Hughes INTEQ Survey Report r~~r BAKER Nu~HEs INTEQ -- Company: BP Amoco - -- Date: 12/1/2008 Time: 10:07:04 Page: 2 Field: Pru dhoe Bay C u-ordinate(NE) Reference: Well: Y-25, Tr ue North Site: PB Y Pad Vertical (TVD) Reference: 37:25 10/29/ 1988 00:00 78.7 I Well: Y-25 Section (VS) Reference: Well (O.OON,O .OOE,278.OOAzi) Wcllpath: Y-25A Su rvey Calcula tion Method: Minimum Curvature Db: Oracle Survev MU Incl Azim TVD Sys TVD lYlS E/W MapN MupE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11566.20 93.90 235.11 9007.61 8928.91 2238.26 -5186.10 5950987.86 639420.52 5447.08 14.36 MWD 11599.02 92.85 228.72 9005.68 8926.98 2218.07 -5211.87 5950967.17 639395.14 5469.79 19.70 MWD 11641.69 94.15 219.68 9003.06 8924.36 2187.57 -5241.54 5950936.11 639366.08 5494.92 21.36 MWD 11674.07 93.13 221.93 9001.01 8922.31 2163.11 -5262.65 5950911.25 639345.43 5512.43 7.62 MWD 11706.61 94.09 227.73 8998.96 8920.26 2140.09 -5285.54 5950887.79 639323.00 5531.89 18.03 MWD 11742.72 93.60 236.31 8996.53 8917.83 2117.94 -5313.91 5950865.10 639295.06 5556.90 23.75 MWD 11776.38 93.81 242.81 8994.36 8915.66 2100.93 -5342.85 5950847.54 639266.45 5583.20 19.28 MWD 11827.97 93.23 253.24 8991.18 8912.48 2081.69 -5390.54 5950827.39 639219.15 5627.74 20.21 MWD 11860.65 92.37 259.93 8989.58 8910.88 2074.12 -5422.27 5950819.22 639187.57 5658.11 20.62 MWD 11894.42 93.32 270.03 8987.90 8909.20 2071.17 -5455.83 5950815.62 639154.08 5690.93 30.00 MWD 11928.01 93.23 276.86 8985.98 8907.28 2073.18 -5489.28 5950816.99 639120.59 5724.34 20.30 MWD 11952.45 90.28 279.86 8985.23 8906.53 2076.74 -5513.44 5950820.08 639096.37 5748.76 17.21 MWD 11984.65 88.93 286.71 8985.45 8906.75 2084.13 -5544.76 5950826.87 639064.92 5780.80 21.68 MWD 12013.68 89.23 292.54 8985.92 8907.22 2093.88 -5572.09 5950836.09 639037.41 5809.22 20.11 MWD 12045.98 87.75 300.77 8986.77 8908.07 2108.35 -5600.92 5950850.00 639008.31 5839.79 25.88 MWD 12073.68 89.05 299.48 8987.55 8908.85 2122.24 -5624.87 5950863.43 638984.10 5865.44 6.61 MWD 12102.59 90.40 295.33 8987.68 8908.98 2135.55 -5650.53 5950876.24 638958.19 5892.70 15.09 MWD 12148.93 88.68 287.82 8988.06 8909.36 2152.57 -5693.59 5950892.44 638914.81 5937.71 16.62 MWD 12178.79 84.63 282.57 8989.80 8911.10 2160.38 -5722.34 5950899.69 638885.92 5967.26 22.18 MWD 12207.98 84.10 277.87 8992.67 8913.97 2165.54 -5750.92 5950904.30 638857.25 5996.28 16.13 MWD 12248.46 84.71 272.65 8996.62 8917.92 2169.23 -5791.02 5950907.22 638817.09 6036.51 12.92 MWD 12284.38 83.55 268.71 9000.29 8921.59 2169.65 -5826.74 5950906.95 638781.37 6071.94 11.38 MWD 12318.63 82.77 262.43 9004.37 8925.67 2167.03 -5860.63 5950903.68 638747.54 6105.14 18.35 MWD 12366.81 82.34 253.50 9010.63 8931.93 2157.08 -5907.31 5950892.84 638701.07 6149.97 18.40 MWD 12398.06 84.10 245.23 9014.33 8935.63 2146.15 -5936.32 5950881.35 638672.27 6177.18 26.87 MWD 12437.50 84.65 234.11 9018.20 8939.50 2126.36 -5970.14 5950860.92 638638.84 6207.92 28.09 MWD 12473.75 84.15 226.91 9021.75 8943.05 2103.43 -5997.96 5950837.46 638611.46 6232.29 19.82 MWD 12497.65 84.97 221.77 9024.01 8945.31 2086.42 -6014.59 5950820.14 638595.17 6246.38 21.68 MWD 12532.03 84.96 216.24 9027.03 8948.33 2059.82 -6036.13 5950793.13 638574.14 6264.01 16.02 MWD 12564.35 93.29 211.66 9027.53 8948.83 2033.04 -6054.16 5950766.01 638556.63 6278.14 29.41 MWD 12593.78 97.33 203.59 9024.80 8946.10 2007.11 -6067.74 5950739.82 638543.56 6287.98 30.55 MWD 12624.86 96.31 199.43 9021.11 8942.41 1978.41 -6079.05 5950710.91 638532.80 6295.19 13.69 MWD 12653.02 94.24 197.09 9018.52 8939.82 1951.78 -6087.83 5950684.12 638524.53 6300.18 11.07 MWD 12687.77 92.18 195.12 9016.57 8937.87 1918.45 -6097.46 5950650.61 638515.55 6305.07 8.20 MWD 12723.43 92.40 197.23 9015.15 8936.45 1884.23 -6107.38 5950616.21 638506.28 6310.14 5.94 MWD 12760.02 92.36 202.51 9013.63 8934.93 1849.86 -6119.80 5950581.61 638494.53 6317.66 14.42 MWD 12791.54 93.26 207.95 9012.08 8933.38 1821.39 -6133.22 5950552.90 638481.66 6326.98 17.47 MWD 12825.56 93.44 210.58 9010.09 8931.39 1791.77 -6149.82 5950522.96 638465.64 6339.30 7.74 MWD 12855.08 93.17 214.38 9008.39 8929.69 1766.91 -6165.64 5950497.81 638450.29 6351.51 12.88 MWD 12890.83 93.90 219.86 9006.18 8927.48 1738.47 -6187.17 5950468.96 638429.32 6368.87 15.44 MWD 12917.79 92.64 224.36 9004.64 8925.94 1718.51 -6205.21 5950448.65 638411.67 6383.96 17.31 MWD 12949.12 92.70 226.44 9003.18 8924.48 1696.54 -6227.49 5950426.26 638389.81 6402.97 6.63 MWD 12988.32 91.20 230.72 9001.85 8923.15 1670.62 -6256.86 5950399.79 638360.95 6428.45 11.56 MWD 13013.86 90.52 227.79 9001.47 8922.77 1653.96 -6276.21 5950382.76 638341.93 6445.29 11.78 MWD 13047.94 91.53 223.72 9000.86 8922.16 1630.19 -6300.61 5950358.52 638317.99 6466.15 12.30 MWD 13089.67 95.17 219.74 8998.42 8919.72 1599.11 -6328.33 5950326.92 638290.87 6489.27 12.91 MWD 13125.70 96.53 216.09 8994.74 8916.04 1570.84 -6350.36 5950298.24 638269.40 6507.15 10.76 MWD 13155.81 95.97 213.49 8991.47 8912.77 1546.26 -6367.43 5950273.34 638252.80 6520.64 8.78 MWD 13185.00 95.26 212.16 8988.61 8909.91 1521.85 -6383.18 5950248.63 638237.52 6532.83 5.15 MWD 13218.04 93.93 208.54 8985.96 8907.26 1493.44 -6399.81 5950219.90 638221.44 6545.36 11.64 MWD 13247.44 91.41 204.26 8984.59 8905.89 1467.14 -6412.87 5950193.36 638208.89 6554.62 16.88 MWD 13293.13 86.56 199.06 8985.40 8906.70 1424.71 -6429.72 5950150.62 638192.86 6565.41 15.56 MWD 13329.69 85.91 192.69 8987.80 8909.10 1389.64 -6439.69 5950115.36 638183.56 6570.40 17.48 MWD ~~~~~~~ ` BP Alaska ', Baker Hughes INTEQ Survey Report rr..r BAKER HUGHES INTEQ Company: BP Amoco Date: 12/1!2008 Time: 10:07:04 Page: 3 Field: Pru dhoe Bay Co-ordinate(NE) Refercncc: Well: Y-25, True North Site: PB Y Pad Vertical (TVD ) Reference: 37:25 10/29/ 1988 00:00 78.7 Well: Y-25 Section (VS) Refercncc: Well (O.OON,O. OOE,278.OOAzi) Wcllpath: Y-25A Survey Calcul ation :~4ethod: Minimum Curvature Db: Orade Sm~vcv MD Inc! Azim TVll Sys TVD N/S E/W vlapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 13366.36 85.82 185.89 8990.45 8911.75 1353.57 -6445.60 5950079.19 638178.36 6571.23 18.50 MWD 13406.94 85.05 179.16 8993.68 8914.98 1313.18 -6447.38 5950038.78 638177.35 6567.38 16.64 MWD 13433.57 84.65 175.18 8996.08 8917.38 1286.69 -6446.07 5950012.32 638179.17 6562.39 14.96 MWD 13465.11 84.16 171.58 8999.15 8920.45 1255.52 -6442.45 5949981.23 638183.38 6554.47 11.47 MWD 13495.34 83.98 167.69 9002.28 8923.58 1225.95 -6437.04 5949951.77 638189.36 6545.00 12.81 MWD 13527.26 84.70 162.61 9005.43 8926.73 1195.25 -6428.90 5949921.24 638198.09 6532.67 16.00 MWD 13568.75 85.97 160.00 9008.80 8930.10 1156.09 -6415.65 5949882.34 638212.09 6514.10 6.98 MWD 13607.15 83.87 163.28 9012.20 8933.50 1119.79 -6403.60 5949846.28 638224.83 6497.12 10.11 MWD 13635.65 82.67 164.71 9015.54 8936.84 1092.59 -6395.80 5949819.23 638233.16 6485.61 6.52 MWD 13669.28 81.55 171.51 9020.16 8941.46 1060.01 -6388.94 5949786.80 638240.64 6474.28 20.30 MWD 13710.63 80.30 172.87 9026.69 8947.99 1019.56 -6383.39 5949746.46 638246.97 6463.15 4.44 MWD 13740.73 81.27 176.97 9031.51 8952.81 989.97 -6380.76 5949716.93 638250.16 6456.43 13.83 MWD 13767.79 82.71 180.63 9035.28 8956.58 963.19 -6380.20 5949690.17 638251.24 6452.15 14.41 MWD 113835.00 82.71 180.63 9043.81 8965.11 896.52 -6380.93 .5949623.51 638251.78• 6443.60 0.00 MWD TREE _ ~ 6" CM/ WECLHEAD= MCEVOY ACTUATOR = BAKER KB. ELEV = 78.71' BF. ELEV = 51.21' KOP = 3300' Max Angle = 92 @ 11700' Datum MD = 11000' Datum ND = 8800' SS DRLG DRAFT SUSPENDED 12/5/08 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.30" AI sleeve in SELRT@10320' Hole in tubing above GLM #1 PDS caliper 2/25!08 3-1/2" TIEB, 9.2#, STL, 13Cr ID=2.992" l~ 10312' 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TNV TIEBA CK SLV 9-5/8" X 5-1 /2" TMI RP LNR HGR 9-5/8" CSG, 47#, NT-80S, ID = 8.681" 5 1/2"whipstock I 11305' I SAFETY NOTES: WELL EXCEEDS 70° @ Y -2 5 A 11200' ~ GOES HORI20NTAL @ 11600'. 5-1/2" CAMCO SSSV NIP, ID= 4.562" GAS LIFT MANDRELS 43° ST MD ND DEV NPE VLV LATCH PORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/08 5 6013 5388 45 CAM DOME RK 16 02/11!08 4 7973 6813 46 CAM DOME RK 16 02!11/08 3 9302 7744 46 CAM SO RK 24 02/11/08 2 10000 8227 44 CAM DMY RK 0 02/11/99 1 10068 8276 43 CAM DMY RK 0 04/03/04 10147' I-i 5-1 /2" OTIS SLIDING SLEEV E ID = 4.562" 10207' ~--1TMl PBR SEAL ASSY 10222' 9-5/8" X 5-1 /2" TMJ HBBP PKR, ID = 4.75" 10273' 5-1/2" OTIS X NIP, ID = 4.562" 10314' -j 5-1 /2" HES XN NIP, ID =milled to 4.55" 10717' 5-1/2" TNV SEAL NIPPLE W/O SEALS 10729' ELMD 10338' 3-1 /2" STL X NIP, ID = 2.813" 2-7/8" LNR 6.4#, STL 13Cr80, ID = 2.441" 1 1 931-1 383 5 76° PERFORATION SUMMARY REF LOG: NL MWD ELMAG WR/GR ON 11 /24/88 A NGLE AT TOP PERF: 57 @ 10990' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10990 - 11020 C 05/09/95 3-3/8" 6 11230 - 11250 C 2/15-17/96 3-3/8" 6 11260 - 11280 C 2/15-17/96 3-3/8" 6 11296 - 11326 C 2/15-17/96 3-3/8" 6 11330 - 11350 C 2/15-17/96 3-3/8" 6 11370 - 11380 C 2/15-17/96 3-3/8" 6 11380 - 11410 C 01/30/96 3-3/8" 6 11440 - 11460 C 2/15-17/96 3-3/8" 6 11460 - 11490 C 01 /30/96 SLT 11614 - 13310 S 9/1608 XO I~ 11931' TOC (talc) ~ 13385' 3-112" LNR 9.2#, VAMTOP SC80, 13Cr ID = 2.992" 11931' 11481' CTM FISH: CENTRALIZED CMr STINGER ASSY (09/15/08) 11550' BKR CMT RETAINER (09/15/08) ~~11575' 5-1 /2" LNR, 17#, L-80, .0232 bpf, ID = 4.892„ 11~57~ CTC EXT CSG PKR 5-1/2" SLTD LNR, 17#, L-80, .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/10/88 ORIGINAL COMPLETION 07/14/01 CH/KAK CORRECTIONS 04/02/08 KDC/PJC SET WRP (03/13108) 09/17/08 IMM MILL XN, CMT SOZ 12/04/08 NORDIC2 CTD SIDETRACK 12/25/08 /TLH CORRECTIONS PRUDHOE BAY UNIT WELL: Y-25A PERMff No: API No: 50-029-21883-01 SEC 33, T11 N, R13E, 1403' SNL & 169' WEL BP Exploration (Alaska) riw~ BAKER HUGHES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: December 18, 2008 Please find enclosed directional survey data for the following wells: G-02B Y-05B E-328 Y-05BPB1 Z-OlB Y-25~} ~ C-30A C-23C Enclosed for each well is: tea copies of directional starvey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LRZ-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECENED BY: ~ ,State of Alaska AOGCC DATE: ~~_ ,1,..~ ~ -,~,.~. Cc: State of Alaska, AOGCC Nordic 2 RDMO Y-2~A • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 03, 2008 10:50 AM To: 'Endacott, Mary S" Cc: Hubble, Terrie L; Schmoyer, AI; NSU, ADW Drlg Nordic 2 Supervisor Subject: RE: Nordic 2 RDMO Y-25A (208-140) Page 1 of 1 Thanks Mary. Bummer!!! If this well will be left "as is" for a while, then i# should be considered suspended. Call or message with any questions. Tom Maunder, PE AOGCC From: Endacott, Mary S [mailto:Mary.Endacott@bp.comJ Sent: Wednesday, December 03, 2008 9:45 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie l.; Schmoyer, AI; NSU, ADW Drlg Nordic 2 Supervisor Subject: Nordic 2 RDMO Y-25A Tom Nordic 2 will be moving off Y-25A sometime today or early tomorrow. The liner wiper plug launched prematurely leaving the liner full of cement. We are choosing not do drill out cement and leaving the well freeze protected. We will be deciding the fate of the well and proceed from there. More to follow. See attached sketch of what we`re left with. Thanks, «Y-25Apost. jpg» Mary S. Endacott BP Alaska Coil Tubing Drlg Engr office 790d 907-564-4388 endacoms@bp.com 12!3/2008 TREE- 6' CUU UUELLHEAd- IAG~OY ACTUATOR- 8A1~i I~ . ELE1~ - 78.71' _ . 9 F . ELES1 ~ .~. :.._.__~ _ . ~, ~. _ -.5121' ~._~_~... I%D P ~ _~..__ _..____..__._.._ 1.~x A r gle - 3~Q ~_.._~__.___a. w 52 ~ 11700 datum IJId- 11m0 oai~ m iir a - B~oQ SS 13~ CSG,73q. Lam, ID- 1217' ~TC~ SiL~~tr~~k: SAFETY NOTES: V~ELL E}~CEEOS 70° ~ 11200' ~ GOES HOF~I~ONTAL $11 SO~p ~7' ~11I CA YIIGd SSSS! NIP, D - ~ S62' GAS LIFT !)fA NOR 9.S ST ~Id l5i d d2d TYPE tf L51 LATCH PORT I 6 33816 332 12 CAM dO ME R K 16 0: 5 6013 5388 IS CAM dO IJIE R K 16 0~ ~ 7973 6813 46 CAM dO IaE R I{ 16 0~ 3 9342 7711 46 CAM SO R K 2 ~ Ot 2 1 mm 8227 ~~ CA I)I d L14r R K 0 Ot 1 10068 5276 i3 CA IA d SAY R K 0 0~ ~~ MIt11t1'ILIt'1'1I~ _ ~.~~' AI ;~I~ett+~ in SE LRT4~1Q308' 12'TIEB,9~,STL,13Cr Cr2.592' ~~10322 elm O ld, 1 f iP, L~LI, Lf..7! Uhl, U - 4 ~`~fL- TW TIEBACKSLV 9~~ Xrif~' TUU RP LNR HGR 9~F8' CSC, i7i~, NT~OS, G -8b81' 5 1 ~ K~ Y td 1C~#~ 1 PERFO RATD N SUMAAA RY REF LOG: NL ~lUQ ELIAAG UURfiR ON 11l21~B ANGLEATTOPPERF: 57~ 10950' Ndie: Rerier b Prodretbr d91br i ttarCalpe ridafa SQE SPF NTERUAL Op11Sc{~ BATE 3 3r6' 6 10990 -11024 C OSJ09~95 3~~' 6 112 -11250 C. 215-17!55 316' 6 1 12~ -11280 C 2115-17J56 3,3~' 6 11296 -11326 C 2115-17!'96 3~~' 6 113 -11350 C• 2116-1756 3,3~' 6 11370 -11380 C 2115-17'96 3~~' 6 113 -11110 C 011~~96 3~r6' 6 1111[! - 11160 C~ 2115-17J56 3-3+6' 6 11iW - 11150 ~_ 01130J96 SLT 11611- 13310 S 911 ~8 101c17' S-tf2' OT6 SLIdNG SLE~iEId- 1,561 10~p7' TUU P9R SEALASSY 10~ 9~6' X ~1f2• TUU H6 BP PWi, Id- 1.7: 10273 5-11~' OTYS }C NIP. [! - ~ S62' 1031~1~ 5-1 f:" HES~€N NIP, D-mlpdta~ISS' 14717' S-1l~' TUU S@q L NIPP LE UU1O SEALS ~~-,,~ 107291 EL lUd '1031:=.' 3-1 ~' STL X NIP, a -'~.S 13' ~__~4~_°~ 2-7aS LNR 6.ItJ, STL 13G130, G - 2.111' 19$31-'1.3£ 5-112• SLTd LNR,17ip, LSO, D232 Gpt', D - 1892' GATE ReJ BY CO MA~ENTS BATE REV 8Y CO LILIENTS 121108 ORIGINAL UDM PLETIDN 03111 A8 CJN1Tl.H BP PULLEaIPLUG SET311A8 0711 iA 1 CHJ14q IC CO RRBCTO NS OIA2A$ I~CIPJG SET UU RP ~3113AS) 01~03A1 GJB114q GLk~CA 09117 A8 IIJIIJI IALL7CN,CI,ATSQ2: OI~~US JRA1R H B P SET ~IAIAS~ 12J~3~08 MSE CTd SIdEfRACK PRUGHOEBAY UNIT ~ QUELL: Y-25A PERMR Na: API No: 50-029-21883-01 SBG 33, T1 1 N, R13E,1 X03 SNL & 169r DUEL ~~ • ~ ~ ~ ~ a SARAH PAL/N, GOVERNOR °~-~~~ OIIJ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA7'IOAT C01rII-iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-25A BP Exploration Alaska Inc. Permit No: 208-140 Surface Location: 1403' FNL, 169' FEL, SEC. 33, T11N, R13E, UM Bottomhole Location: 453' FNL, 1238' FEL, SEC. 32, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~~_ Cathy P Foe ster Commissioner ,Gl" DATED this ~ day of September, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ AND GAS CONSERVATION PERMIT TO DRILL ~n aac ~s nns 'S-O~' ~~t, ~ SEP Q 4 2008 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service Multiple Zone ^ Stratigraphic Test ®Development Oil $ Single Zone ~,: , ~ 1 c. Specify if s r p ^ Coalbed Methane ^ C~#11~~ ^ Shale Gas 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Y-25A 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 13788' TVD 8980'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 7. Property Designation: ADL 028287, 028288 Pool 1403' FNL, 169' FEL, SEC. 33, T11 N, R13E, UM Top of Productive Horizon: UM R13E T11N SEC 28 4813' FEL 819' FSL 8. Land Use Permit: 13. Approximate Spud Date: October 15, 2008 , , , . , , Total Depth: 453' FNL, 1238' FEL, SEC. 32, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 15,390' 4b. Location of Well (State Base Plane Coordinates): Surface: x-644647 y-5948850 Zone-ASP4 10. KB Elevation (Hei ht above GL): 78.7' feet 15. Distance to Nearest Well Within Pool: 6~' 16. Deviated Wells: Kickoff Depth: 11300 feet Maximum Hole A le: 101 d Tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2370 .r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 31 /7' x 2-7/g' Tap / STL # 1 1 g, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Reentry Operations) Total Depth MD (ft): 13418' Casin Total Depth TVD (ft): Len th Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10147' 13310' 9007' Yes, Unknown Depth Size Cement Volume MD D Conductor! Structural " Surface - I Intermediate Liner - Perforation Depth MD (ft): Below Plug: 10990' -13310' Perforation Depth TVD (ft): 8873' - 900T 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Re resentative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mary Endacott, 564-4388 Printed Name Joh M Title Engineering Team Leader Prepared ey Name/Nwnber Si nature Phone 564-4711 Date Terrie Hubble, 564-4628 G i 'on Permit To 08 Od API Number: 50-029-21883-01-00 Permit rov~l, 6 See cover letter for 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: LJ Samples Req'd: ^ Yes ~No Mud Log Req'd:^ Yes ~No ~QQ ~~ ~ ~Q~ „~~~. ~~ ~~,~~ HZS Measures: Yes ^ No Directional Survey Req'd: GI Yes ^ No Other: v APPROVED BY THE COMMISSION Date ~ ~ COMMISSIONER Fonn 10-401 Revised 12/2005 a by BPXA Prudhoe Bay Y-25A CTD Sidetrack September 3, 2008 CTD Sidetrack Summary Pre-Rig Work Summary: (Scheduled to begin on September 11, 2008) 1. Passed CMIT T x IA 6-17-08 2. Mill XN ~ 10314' to 4.55" (pending mill availability) 3. Drift for 5-1/2" cement retainer to 11,600', set retainer+++ X11,550' (in blank pipe) 4. Squeeze long slotted liner with ~130bbbl cement +++Cement retainer may not set in corroded pipe, if so, then lay in cement 5. Drift for 5-1/2" monobore whipstock Baker permanent, special 4.55" tray OD to 11,400' Rig Sidetrack Operations: (Scheduled to begin on October 15, 2008 using Nordic rig 2) 1. MIRU 2. NU 7-1/16" CT Drilling ROPE and test 3. Set Baker permanent 5'h" whipstock at 11,300' 4. Downsqueeze ~13bb1 15.8ppq cement 6. Drill lateral with 4.5" bit 7. Run 3-1/2" x 2-7/8" 13Cr liner string, cement with 45bb1 15.8ppg 8. Clean out and CCVCNL 9. Perforate well 10. Run 3-1/2" 13Cr tieback to isolate hole in tubing, LTP to 6050' 11. FP, Set BPV. ND 7-1/16" stack. FP tree and PT tree cap 12. RDMO Post-Rig Work: 1. Pull BPV. 2. Re-install well house and FLs 3. Run gas lift design 4. RU test separator, flow test well. 1000' of Zone 4 Perforations ~ ~t ~~~~ Mud Program: • Well kill: 8.4 ppg brine. • • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.5" Casing Program: fully cemented liner • 3-1/2", 13Cr80, 9.2#, VAMTOP 10,280'-12,600' • 2-7/8", 13Cr80 6.4# STL 12,600' -13,787' • Tieback 3-1/2", 13Cr80, 9.2# STL 10,280'- 6,050' • 45 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD ~ 13,787', 4.5" hole and planning on 40% excess in the open hole interval) • TOC planned at TOL Existing casing/tubing Information 13-3/8" 72#, L-80, Burst 5380psi, collapse 2670psi 9 5/8", NT-80S, 47#, Burst 6870 psi, collapse 4750 psi 5-1/2", L-80, 17#, Burst 7740 psi, collapse 6280 psi Tbg: 5-1/2" L-80, 17# Burst 7740 psi, collapse 6280psi 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 100 deg at 13,164' • Magnetic and inclination surreys will be taken every 30 tt. No gyro will be run • Distance to nearest property -15,390 ft • Distance to nearest well within pool - 600 ft. (P-23i, from planned TD) Logging • MW D directional, Gamma Ray & Resistivity will be run over all of the open hole section. • Cased hole MCNUGR/CCL, logs will be run Hazards • The maximum recorded H2S level on Y Pad was 200 ppm on well Y-28; Y-25 is measured at 10ppm • One small fault crossing, lost circulation not expected • Crest in Shublik, could result in wellbore instability Reservoir Pressure • Expected reservoir pressure 3,250 psi at -8,800' TVDSS. (7.1 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,370 psi. M.S.Endacott ~ _ CTD En ineer 9 CC: Well File Sondra Stewman/Terrie Hubble JVELLHEAD = MCEVOY 4CTUATOR= BAKER <B. ELEV = 78.71' 3F. ELEV....- 51.21' 40P = ~. 3300' Vlax Angle = 92 @ 11700' datum MD = 11000' datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 4.455" @ 10314' 5-1 /2" HES XN NIPPLE 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TMJ TIEBACK SLV 9-5/8" X 5-1/2" TIW RP LNR HGR 9-5/8" CSG, 47#, NT-80S, ID = 8.681" PERFORATION SUMMARY REF LOG: NL MWD ELMAG WR/GR ON 11/24/88 ANGLE AT TOP PERF: 57 @ 10990' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10990 - 11020 C 05109/95 3-3/8" 6 11230 - 11250 G 2/15-17/96 3-3/8" 6 11260 - 11280 C 2/15-17/96 3-3/8" 6 11296 - 11326 C 2/15-17196 3-3/8" 6 11330 - 11350 C 2/15-17/96 3-3/8" 6 11370 - 11380 C 2/15-17/96 3-3/8" 6 11380 - 11410 C 01/30/96 3-318" 6 11440 - 11460 C 2/15-17/96 3-3/8" 6 11460 - 11490 C 01 /30/96 SLT 11614 - 13310 G 12/06/88 Y-25 ~J 5-1/2" CAMCO SSSV NIP, ID = 4.562" GAS LIFT MANDRELS SAFETY NOTES: WELL EXCEEDS 70° @ 11200' 8~ GOES HORIZONTAL @ 11600'. ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/0! 5 6013 5388 45 CAM DOME RK 16 02/11/0! 4 7973 6813 46 CAM DOME RK 16 02/11/0! 3 9302 7744 46 CAM SO RK 24 02/11/0! 2 10000 8227 44 CAM DMY RK 0 02/11/95 1 10068 8276 43 CAM DMY RK 0 04/03/0 10147' -~ 5-1 /2" OTIS SLIDING SLEEV E ID = 4.562" 10147' 5-1/2" PX PLUG (06/16/08) 10207' TNV PBR SEAL ASSY 10222' 9-5/8" X 5-1/2" TNV HBBP PKR, ID = 4.75" 10273' 5-1/2" OTIS X NIP, ID = 4.562" 103-~ 5-1/2" HES XN NIP,ID = 4.455" 10717' -~5-1/2" TNV SEAL NIPPLE W/O SEALS 10729' ELMD _~-I FISH: WRP ELEMENTS (06/16/08) 11575' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4. 11579' I~ CTC EXT CSG PKR . ` ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ` 5-1/2" SLTD LNR, 17#, L-80, .0232 bpf, ID = 4.892" FISH: IBP BANDS (8) & 2' OF FISH NECK (02/28/08) 13310' 1 PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 12/10/88 ORIGINALCOMPLETION 03/11/08 CJN/TLH IBP PULLED/PLUG SET3/1/08 07/14/01 CWKAK CORRECTIONS 04/02/08 KDGPJC SET WRP (03/13/08) 04/03/04 GJB/KA GLV C/O 06/28/08 BSFJSV PXN PULL (03/12/08) 04/23/05 JRA/TLH IBP SET (04/04/05) 06/28/08 BSE/SV SET PX /WRP PULLED (06/16/0! 09/10/05 KSB/TLH IBP PULLED (06/05/05) 07/01/08 PJC DRAWING CORRECTIONS 02/11/08 KSB/TLH GLV C/O & ND CORRECTIONS PRUDHOE BAY UNIT WELL: Y-25 PERMIT No: 1881310 API No: 50-029-21883-00 SEC 33, T11 N, R13E, 1403' SNL & 169' WEL BP Exploration (Alaska) TREE = 6" CMJ WELLHEAD = MCEVOY ACTUATOR= BAKER KB. ELEV = 78.71' BF. ELEV = 51.21' KOP = 3300' Max Angle = 92 @ 11700' Datum MD = 11000' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Y -2 5 A SAFETY NOTES: WELL EXCEEDS 70° @ • 11200' & GOES HORIZONTAL @ 11600'. Proposed CTD Sidetrack 5-1/2" CAMCO SSSV NIP, ID = 4.562" 6050' top 3-1/2" 13Cr tie back 5-1/2 x 3-1/2" WFD ER PKR Minimum ID = GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3386 3382 12 CAM DOME RK 16 02/11/08 5 6013 5388 45 CAM DOME RK 16 02/11/08 4 7973 6813 46 CAM DOME RK 16 02/11/08 3 9302 7744 46 CAM SO RK 24 02/11/08 2 10000 8227 44 CAM DMY RK 0 02/11/99 '~~-A~~4 ~~MY RK 0 04/03/04 10147, ~~ 5-1 /2" OTIS SLIDING SLEEV E ID = 4.562" 10207' TNV PBR SEAL ASSY 10222' 9-5/8" X 5-1/2" TM/ HBBP PKR, ID = 4.75" 10273' S-1/2" OTIS X NIP, ID = 4.562" 10280' ~~TOP 3-1/2" x 2-7/8" LINER BG, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ '1071 U, TNV TIEBACK SLV 10722 9-5/8" X 5-1/2" TNV RP LNR HGR 10734' 9-5/8" CSG, 47#, NT-80S, ID = 8.681 " 10973 5 1/2" monobore w hipstock 11300' 5 1/2" cement retainer 11550' PERFORATION SUMMARY REF LOG: NL MWD ELMAG WR/GR ON 11/24/88 ANGLE AT TOP PERF: 57 @ 10990' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10990 - 11020 C 05/09/95 3-3/8" 6 11230 - 11250 C 2/15-17/96 3-3/8" 6 11260 - 11280 C 2/15-17/96 3-3/8" 6 11296 - 11326 C 2/15-17/96 3-3/8" 6 11330 - 11350 C 2/15-17/96 3-3/8" 6 11370 - 11380 C 2/15-17/96 3-3/8" 6 11380 - 11410 C 01 /30/96 3-3/8" 6 11440 - 11460 C 2/15-17/96 3-3/8" 6 11460 - 11490 C 01 /30/96 SLT 11614 - 13310 C 12/06!88 10314' 5-1/2" HES XN NIP, ID =milled to 4.55" 10717' S-1/2" TNV SEAL NIPPLE W/O SEALS 1/2" x 2-7/8" 13Cr Liner, Cemented & Perf'd I 13787' x0 12600' PBTD 13740' 11575' S-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 11579' CTC IXT CSG PKR ~~ ?~ • ???~ FISH: IBP BANDS (8) & 2" ` ~ OF FISH NECK (02/28/08) ~ 13310' PBTD 5-1/2" SLTD LNR, 17#, L-80, .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/10/88 ORIGINALCOMPLETION 03/11/08 CJN/TLH IBP PULLED/PLUG SET3/1/08 07/14!01 CWKAK CORRECTIONS 04/02/08 KDGPJC SET WRP (03/13/08) 04/03/04 GJB/KA GLV GO 09/03/08 MSE PROPOSED CTD SIDETRACK 04/23/05 JRA/TLH IBP SET (04/04/05) 09/10/05 KSB/TLH IBP PULLED (06105/05) 02/11/08 KSB/TLH GLV GO & TVD CORRECTIONS PRUDHOE BAY UNfr WELL: Y-25A PERMIT No: API No: 50-029-21883-01 SEC 33, T11 N, R13E, 1403' SNL & 169' WEL BP Exploration (Alaska) P Alaska ~~- ~jyj .~I~aR BNUG LEGEND V_25I~_z5, R Plan 5, V-25A h -- PWnS Wiak no er: saar w, n..sl c.,w ar m ~,.., av s.rxN v rm a.. mrmm o.. -- -- weur.rxoeruu _ ~ U! 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Aso„,;n, , , ~ ..w ~ » ~ .,~ » aam ~ ~ ,. ~ n~ , ,.~ • J by ~ BP Alaska Baker Hughes INTEQ Planning Report ~~~ mss 1NTGQ I Company: BP Amoco Date: 9/3!2008 Time: 15:06:39 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-25, True North Site: PB Y Pad Vertical (TVD) Reference: 37 :25 10/29/1988 00:00 78.7 Well: Y-25 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Wellpath: Plan 5, Y-25A Survey Calculation Method: Mi nimum Curvature I)b: Qracle Field: Prudhoe Bay North Slope UNITED STATES j Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Modet: bggm2007 i Site: PB Y Pad TR-11-13 f UNITED STATES :North Slope ' Site Position: Northing: 5948541 .48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W ~~ Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-25 Slot Name: 25 Y-25 ~ Well Position: +N/-S 369.16 ft Northing: 5948849.82 ft Latitude: 70 16 3.666 N +E/-W -3094.04 ft Easting : 644648.28 ft Longitude: 148 49 49.050 W Position Uncertainty: 0.00 ft ~ Wellpath: Plan 5, Y-25A Drilled From: Y-25 Tie-on Depth: 11 297.00 ft Current Datum: 37:25 10/29/1988 0 0:00 H eight 78 .70 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 9/2/2008 Declination: 23.00 deg Field Strength: 57672 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ~-- ft ft deg II 29.70 0.00 0.00 225.00 -- Plan: Plan 5 ___ - Date Composed: 9/3/2008 - ~ copy Mary's plan 5 Version: 1 Principal: Yes ~- Tied-to: From: Definitive Path --.~ Targets j Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec i Dip. Dir. I----- _ ft ft ft ft, ft _ - ---- Y-25A Fault 1 78.70 1437.98 -5852.17 5950174.99 638770.00 70 16 17.786 N 148 52 39.423 W j -Polygon 1 78.70 1437.98 -5852.17 5950174.99 638770.00 70 16 17.786 N 148 52 39.423 W -Polygon 2 78.70 2072.82 -5834.97 5950809.99 638775.00 70 16 24.029 N 148 52 38.936 W i -Polygon 3 78.70 2632.95 -5834.21 5951369.99 638765.00 70 16 29.538 N 148 52 38.927 W -Polygon 4 78.70 2072.82 -5834.97 5950809.99 638775.00 70 16 24.029 N 148 52 38.936 W Y-25A Fault A 78.70 2683.99 -6928.51 5951399.98 637670.00 70 16 30.031 N 148 53 10.792 W ~ -Polygon 1 78.70 2683.99 -6928.51 5951399.98 637670.00 70 16 30.031 N 148 53 10.792 W -Polygon 2 78.70 1789.66 -6715.64 5950509.98 637900.00 70 16 21.237 N 148 53 4.570 W -Polygon 3 78.70 276.85 -6589.68 5948999.98 638055.00 70 16 6.360 N 148 53 0.864 W i ; -Polygon 4 78.70 1789.66 -6715.64 5950509.98 637900.00 70 16 21.237 N 148 53 4.570 W Y-25A Polygon 78.70 2440.67 -6707.13 5951160.98 637896.00 70 16 27.640 N 148 53 4.339 W -Polygon 1 78.70 2440.67 -6707.13 5951160.98 637896.00 70 16 27.640 N 148 53 4.339 W !, j -Polygon 2 78.70 692.09 -6440.66 5949417.98 638196.00 70 16 10.445 N 148 52 56.537 W -Polygon 3 78.70 1029.66 -6101.08 5949761.98 638529.00 70 16 13.768 N 148 52 46.660 W ' -Polygon 4 78.70 1831.46 -6027.66 5950564.98 638587.00 70 16 21.654 N 148 52 44.541 W -Polygon 5 78.70 2106.34 -4873.07 5950861.98 639736.00 70 16 24.366 N 148 52 10.931 W -Polygon 6 78.70 2388.58 -4777.63 5951145.98 639826.00 70 16 27.142 N 148 52 8.158 W Y-25A Target 2 8978.70 2145.31 -5703.54 5950884.99 638905.00 70 16 24.743 N 148 52 35.112 W Y-25A Target 4 8983.70 1458.94 -6421.92 5950184.99 638200.00 70 16 17.987 N 148 52 56.010 W Y-25A Target 1 9018.70 2305.88 -5210.33 5951054.99 639395.00 70 16 26.326 N 148 52 20.755 W Y-25A Target 3 9038.70 1990.03 -6211.66 5950719.99 638400.00 70 16 23.212 N 148 52 49.902 W BP Alaska by Baker Hughes INTEQ Planning Report iNTEQ Company: BP Amoco Date: 9/312008 Time: 15'06:39 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Refere nce: WeIL Y-25, True North Site: PB Y Pad Vertical (TVD) Reference: 37:25 10!29/1988 00:00 7 8.7 Well: Y-25 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Wellpath: Plan 5, Y-2 5A SurveyCalcn}ationMethod: Minimum Curvature Db: Oracle Targets - - - __ Map Map <_ -_ Latitude ---> < - Longitude --> Name Description TVA +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip.. Dir. ft - ft ft ft ft --- - Y-25A Target 5 9058.70 962.36 -6346.44 - 5949689.99 638285.00 70 16 13.104 N 148 52 53.801 W Annotation MD TVD ~ _ - ft ft 11297.00 8992.10 TIP 11300.00 8992.79 KOP 11320.00 8997.17 End of 9 Deg per 100' DLS 11433.58 9008.90 4 11583.58 9008.90 5 11733.58 9001.29 6 11933.58 8985.33 7 1 12133.58 8979.35 8 12383.58 9000.69 9 12578.58 9032.75 10 12664.24 9039.42 11 12964.24 9023.58 12 13164.24 8994.52 13 13264.24 8985.20 14 13564.24 9015.96 15 13787.68 9059.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/1DOft deg/100ft deg - _ --- _ - 11297.00 76.50 282.20 8992.10 2290.70 -4932.12 0.00 0.00 0.00 0.00 11300.00 76.58 282.23 8992.79 2291.31 -4934.97 2.84 2.67 1.00 20.04 11320.00 78.14 281.31 8997.17 2295.29 -4954.07 9.00 7.80 -4.60 330.00 11433.58 90.00 274.54 9008.90 2310.77 -5065.71 12.00 10.44 -5.96 330.00 11583.58 90.00 256.54 9008.90 2299.16 -5214.65 12.00 0.00 -12.00 270.00 11733.58 95.77 239.47 9001.29 2243.34 -5353.00 12.00 3.85 -11.39 289.00 11933.58 93.25 263.41 8985.33 2180.41 -5540.63 12.00 -1.26 11.97 95.00 12133.58 90.13 239.60 8979.35 2117.42 -5728.82 12.00 -1.56 -11.91 263.00 12383.58 80.27 268.07 9000.69 2048.44 -5965.19 12.00 -3.94 11.39 110.00 12578.58 81.07 244.37 9032.75 2002.90 -6150.65 12.00 0.41 -12.16 270.00 12664.24 90.00 239.25 9039.42 1962.58 -6225.81 12.00 10.42 -5.98 330.00 12964.24 95.86 203.66 9023.58 1741.90 -6421.07 12.00 1.95 -11.86 280.00 1 13164.24 100.62 179.88 8994.52 1549.68 -6461.39 12.00 2.38 -11.89 283.00 i, 13264.24 90.09 185.67 8985.20 1450.42 -6466.25 12.00 -10.53 5.79 151.00 13564.24 78.47 151.36 9015.96 1162.64 -6408.70 12.00 -3.87 -11.44 250.00 13787.68 79.73 178.64 9059.00 952.83 -6352.60 12.00 0.56 12.21 90.00 Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft': deg/100ft ft _ deg _ - 11297.00 76.50 282.20 8913.40 2290.70 -4932.12 5951045.15 639673.43 __ 0.00 1867.77 0.00 MWD 11300.00 76.58 282.23 8914.09 2291.31 -4934.97 5951045.72 639670.57 2.84 1869.35 20.04 MWD j 11320.00 78.14 281.31 8918.47 2295.29 -4954.07 5951049.33 639651.39 9.00 1880.04 330.00 MWD ~ 11400.00 86.49 276.52 8929.17 2307.53 -5032.31 5951060.06 639572.94 12.00 1926.71 330.00 MWD ~ 11433.58 90.00 274.54 8930.20 2310.77 -5065.71 5951062.65 639539.49 12.00 1948.04 330.64 MWD ~~ 11500.00 90.00 266.57 8930.20 2311.41 -5132.07 5951062.03 639473.13 12.00 1994.51 270.00 MWD j 11583.58 90.00 256.54 8930.20 2299.16 -5214.65 5951048.19 639390.81 12.00 2061.56 270.00 MWD 11600.00 90.64 254.68 8930.11 2295.08 -5230.55 5951043.80 639375.00 12.00 2075.69 289.00 MWD ~ 11700.00 94.51 243.31 8925.60 2259.35 -5323.64 5951006.30 639282.61 12.00 2166.78 288.99 MWD ( 11733.58 95.77 239.47 8922.59 2243.34 -5353.00 5950989.72 639253.57 12.00 2198.86 288.48 MWD 11800.00 95.03 247.44 8916.33 2213.81 -5412.10 5950959.07 639195.05 12.00 2261.53 95.00 MWD 11900.00 93.72 259.40 8908.67 2185.42 -5507.49 5950928.85 639100.24 12.00 2349.06 95.75 MWD BP Alaska by Baker Hughes INTEQ Planning Report iNTEQ Company: BP _ __ Amoco - - -- Date: 9!3!2008 Time: 15:06:39 Page: 3 Field: Prudhoe Bay Go-ordinate(NE) Reference: Well: Y-25, True North Site: PB Y Pad Vertiesl,(TVD) Reference: 37:25 10/29!1988 00:00 78.7 Well: Y-25 Seetion (VSO Reference: Well (O.OON,O.OO E,225.OOAzi) ~' Wellpath: Pla n 5, Y-25A Survey Calculation Method: Minimum Curvature Db: Oracle Survey -- _ _ _ __ MD Intl Azim SS TVD N/S E!W MapN MapE DLS VS TFO Tool ft - deg deg. ft ft - ft ft ft deg/100ft ft deg a 11933.58 93.25 263.41 8906.63 - 2180.41 - -5540.63 _ 5950923.20 639067.20 _--- 12.00 -- 2376.03 - 96.67 -- -- MWD 12000.00 92.25 255.49 8903.44 2168.27 -5605.79 5950909.82 639002.29 12.00 2430.69 263.00 MWD 12100.00 90.67 243.59 8900.89 2133.39 -5699.28 5950873.15 638909.49 12.00 2521.46 262.62 MWD 12133.58 90.13 239.60 8900.65 2117.42 -5728.82 5950856.62 638880.27 12.00 2553.64 262.32 MWD 12200.00 87.41 247.09 8902.08 2087.66 -5788.11 5950825.72 638821.56 12.00 2616.62 110.00 MWD 12300.00 83.41 258.45 8910.11 2058.16 -5883.13 5950794.41 638727.13 12.00 2704.66 109.84 MWD ~ 12383.58 80.27 268.07 8921.99 2048.44 -5965.19 5950783.11 638645.29 12.00 2769.56 108.93 MWD 12400.00 80.27 266.07 8924.77 2047.61 -5981.34 5950781.97 638629.15 12.00 2781.57 270.00 MWD 12490.99 80.51 255.00 8940.00 2032.88 -6069.69 5950765.55 638541.11 12.00 2854.46 270.34 Y-25A T 12500.00 80.56 253.90 8941.48 2030.50 -6078.25 5950763.00 638532.60 12.00 2862.19 272.19 MWD 12578.58 81.07 244.37 8954.05 2002.90 -6150.65 5950734.02 638460.75 12.00 2932.91 272.37 MWD 12600.00 83.30 243.07 8956.96 1993.50 -6169.67 5950724.26 638441.91 12.00 2953.00 330.00 MWD 12664.24 90.00 239.25 8960.72 1962.58 -6225.81 5950692.27 638386.39 12.00 3014.55 330.18 MWD ~i 12700.00 90.74 235.02 8960.48 1943.18 -6255.83 5950672.30 638356.74 12.00 3049.50 280.00 MWD 12800.00 92.79 223.19 8957.39 1877.87 -6331.25 5950605.56 638282.59 12.00 3149.02 279.97 MWD 12900.00 94.72 211.32 8950.81 1798.60 -6391.56 5950525.15 638223.83 12.00 3247.71 279.61 MWD ~~ 12964.24 95.86 203.66 8944.88 1741.90 -6421.07 5950467.90 638195.41 12.00 3308.67 278.83 MWD 13000.00 96.81 199.45 8940.94 1708.86 -6434.13 5950434.61 638182.99 12.00 3341.27 283.00 MWD 13100.00 99.25 187.59 8926.92 1612.78 -6457.26 5950338.11 638161.71 12.00 3425.57 282.54 MWD 13164.24 100.62 179.88 8915.82 1549.68 -6461.39 5950274.95 638158.80 12.00 3473.10 280.87 MWD 13200.00 96.86 181.98 8910.39 1514.36 -6461.97 5950239.62 638158.90 12.00 3498.49 151.00 MWD ~ 13264.24 90.09 185.67 8906.50 1450.42 -6466.25 5950175.62 638155.85 12.00 3546.72 151.32 MWD 13300.00 88.62 181.64 8906.90 1414.75 -6468.52 5950139.91 638154.26 12.00 3573.56 250.00 MWD ' 13400.00 84.58 170.32 8912.85 1315.35 -6461.55 5950040.68 638163.14 12.00 3638.91 250.05 MWD ' ~' 13500.00 80.75 158.85 8925.66 1219.91 -6435.27 5949945.77 638191.24 12.00 3687.82 250.72 MWD 13564.24 78.47 151.36 8937.26 1162.64 -6408.70 5949889.02 638218.91 12.00 3709.53 252.19 MWD '; 13600.00 78.51 155.74 8944.40 1131.28 -6393.10 5949857.96 638235.11 12.00 3720.67 90.00 MWD 13700.00 78.94 167.96 8964.03 1038.27 -6362.62 5949765.57 638267.37 12.00 3764.88 89.13 MWD ', 13786.00 79.71 178.44 8980.00 954.48 -6352.64 5949681.99 638278.96 12.00 3817.08 86.73 Y-25A T 13787.68 79.73 178.64 8980.30 952.83 -6352.60 5949680.34 638279.03 12.00 3818.22 84.78 3.5" • Nordic 1 bighole easurements are from i ~_ of bag Dowell Slaps Blind/Shears of pipes 2 3/8" combi ram/slips Mud Cross cross variable bore pipe 3 1/2"-2 7/8" of pipe/slips 2 3/8" combi ram/slips ab Valve U BAG 7 1 /16" 5000psi TOTs 7 1/16" 5000psi Mud Cross 7 1 /16" 5000psi TOTS 7 1/16" 5000psi Flow Tee Alaska Department of NaturalResources Land Administration System Page 1 of7~( i • a i +,, _; ,,,~, , ;r.., ~~ - ~ ~h; I; ~;;c~~;rs C~arc~ State Cabins l~~tur~~ ~~~1 s Alaska DNR Case summary ~-- File Type ADL File Number: 2$287 ~ Printable Case Fi.l..e.._Summary See Township, Range, Section and Acreage? __ New Search ~'~ Yes ~'° No __ ~ _~.~___~_ ! ?~~ Meng? I Case Abstract I Case Detail I Land Abstract ., File: aUL 282217 ``~~"=' Search for Sta±us i~lat Updates 1s ~?k 09%0~''OOti Customer: 400 1 073 77 BP EXPLORATION(ALASKl~) INC PO BOX 1966]2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99519661? Case Tyke: .?~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/09/1965 Total Ades: 2560.000 Date Initiatecl.• 05/28/1965 Office of Pri~~utry Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case SuUtype: P~iS NORTH SLOPE Last Ti-ansaetion: AA-NRB ASSIGNMENT APPROVED Meridian: U Tox~n~hi~~: UI IN R~ur,~~~.~ 013E Sertic~rr~ ~, Scc~lins~,Ic~rrs~: 11=10 Seas°ch i~lats Merl~liun: l ! %~~tii~n~lrr/~. Merr~Jian: ~ 7uu~~r~~frr~~. li~riclrr~r.~ t~ 7nti~i~hiE~. 0~-?8-I96~ ***S~1LF. ~ I_l 1 I \ Kcrn~re.~ U f 31 ,S'rc~li~irr: ~S ,C~~~~liu~t .~I~~~~c~.e: 6-~(1 O l 1 N K~~i~,~c~.~ U I ~ 1. 1~~clruir: 33 .ti~e~~liun _ icrc~~~: 6-~0 U I I N !~'~nr~c~: OIaE ~r~~~i~~n: i ~ ti'c.~c~infr ,lcr~~s 6~0 Legal lcsc~~iptiu^ 'OTICE I EGAL DESCRIP7ION* CI -~-9~ TI 1 N-R13E- U,1I 2?.2~4.33, 3~l 2~ 60.00 fl ~ Et' Last updated on 09/05/2008. http://www. dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28287&... 9/5/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ I • ~- ~, ~ l s - r~r a ~ ., ~`. ~ ~ ~,.'~; ~,~~€~ pr's Search State Cabins ~~tt1~' S~D~1'~~ Alaska DN Case ur°nmar~ File Type A~~ File Number: 282ss Printable Case File_Summary See Township, Range, Section and Acreage? ~` Yes ~° No New Search LAS Men°~ ~ Case Abstract ~ Case Detail ~ Land Abstract ftlc: AllL 28285 ''`''` Search for Status Plat Updates _~~ ot:09; (_1;i~008 Custome~~: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99519661? Case Ti~pe: 7~ OIL & GAS LEASE COMP DNR Urzit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/1 ]/1965 Total Acres: 2491.000 Date Initiated.' 05/28/1965 Office ofPrintary Responsibility: DOG DIV OIL AND GAS Lastlrunsaction Date: 12/04/2006 Case Subtype: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Llei•ic~rar~~ U Township: O11N R<n~oe: OI~I: .5~c°c~tiort: ~~) Sei~i~»t_tcr~~a~: 6~(1 Plats fc~r~i~li~rrl: l_' 7uirri~Iri~~: Ol IN RajT~re: Ulil: ~'~~cliun: ,O ,1 /~~t•r~li~t~t.~ l_ ~ ~utir~~~~hf/~: U I I ~' Itu»~cr.~ 1) I ; I : .5~c~clrnir.~ ~ I Mc~ricliufi: 1 ~ 7 inrns{~i/~: 01 1 ~' Ran~~~e.~ 01 ;1: ,ti~~~~~iic~ri ~ 32 Legal Description 0~-?~-196 ~ * *S.~LE NOTICE LEGAL DESCIZIPTION* CI=I-99 TIIN-RISE-UM29,30,31,32 2-191.00 1 ~5~ ' " .ti'~~~~[iu~t .~I~~~•~s: fi(l~ .C~~~ ~iun :1 c~rc ~~: (~0 Search Last updated on 09/05/2008. http://www. dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28288&... 9/5/2008 'T'RANSMITTAL LETTER CHECKLIST WELL NAME - ,~~.~ y_~~sq PTD~ _ ~o~~ o0 /Developmeat~ ,_ Service _____ Exploratory Strati „_ Non-Conventioaal Weil -- t~pbic Test FIELD: /~~'udy0~' ~~y POOL: .e.° .~GmB' y Circle Appropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) APPLlF„S TEXT FOR APPROVAL LETTER NiClLTI LATERAL The permit is for a new wellbore se gment of existing (If last two digits in well API number, are Permit No. . AP[ No. 50-_ 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 acquired for the pilot hole must be clearly differerrtiatedain both wet! name ( PIS and API cumber (S~ = =-_.) 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 / infect 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. "" ` "" `'" 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 IO' sample intervals throu et nines. Nat-Conventional please note the following special condition of this permit; Well production or production testing of coal bed mejhane is not allowed for frame of we n until after (Comrianv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity.lC2m~ttnv Name) must contact the Commission to obtain advance approval of such water weft testing prOIIfam. Rev: 1/112008 WELL PERMtT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOEOIL - 640150 Well Name: aRUnH~F aqY UNIT Y-25A Program DEV Well bore seg ^ PTD#:2081400 Company BP EXPLORATION (_ALAS~ ANC Iniiial Class/Type DEV I PEND GeoArea 890 Unit 11650 ONOff Shore 9_n_-_ Annular Disposal '^ Administration 1 PetmiifeaatRached- -- --- --- --- -- -- ---- --- --- NA- -- ------ -- - --- --- - - - --- - ---- - -- ----- --- 2 Lease number appropriate --- --- - -- -- -- ------ Yes ---- - -- - - -- - ----- ------ -- -- -- - - -- 3 Unique welt name and number --- -- -- --- - -- ------ -- Yes-- --- - - -- - -- - ------ - - ----- - -- - -- 4 Well located in_a-defined-pool--- ---- --- - - - -- - -- -- Yes - --- - - --- -- --- -- -- - ----- -- -- -- -- -- 5 Well locatedProperdistancefromdrillingunit_boundary----------------------- Yes------ ----.---------------------- - --- -- - -- - - ----- 6 WeII Iocaked Proper distance from otherwells - - - - - - - - ~ - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acrQageayailablein_drillinqunit_---_-___---_-__-------------- Yes------- 2560 acres•------------------------------ - -- - -- ----- - 8 If deviated, is wellt~rg plat included - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 DperatoronlyaffectedPa~Y-- -- --- -- - - ------ -- Yes-- -- -- -- -- -- -- -- - -------- ------- - -- -- -- 10 Ope~atorhas-appropriatebondinfgrce------------------------------ Yes------ BlanketBond#6194193.------------------------------------------------- 11 Petmikcanbetssgedwithoutconservatioaorder---_--_____-------- ----- Yes------- ------------------------ -- -- -- -- --- - - -- -- __- -- Appr Date 12 Petm{t-canb®issuedwiihoutadministtalive.aPProval------------------------ Yes------- -------------------------- -- - -- -- -- - - -- -- 13 Can permit be approved before 95-day_wait- - - - - - - - - - - - - Y~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 9!5(2006 14 Well located within area artd slrataauthorized ky_Injection Order# (put_10# in-comments)_(FOr_ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ _ _ _ _ _ - - _ _ - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells within 114-mile area of reviewidentified(Forsetvicewell9nly)----_-_-_____- -NA__.__-_- ---_--------------------------- -- - - - -- -- --- -- 16 Pre•produced injector. duration of pre production less than 3 monihs (For service wall only) - - -KA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven, gas-cordor_ms to AS31.05,030Q.1.A),(j.2.A-D) - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorstring-provided_.-__________--__.---___------------- NA-__--_- Conductor set-inY-25j188,131)---------------------------------------- - - 19 Su[faeecagingproteetgalkknownUSDWs----------------------------- ~------- Allaqurfersexempked,AE01.---------------------------------------- --- -- 20 CMT-v_oladequate_tacitcutate-onconducier8~surfcsg________________________ NA---___ -Surf_aceoaaingsetinY-25._-.--__-__.___.-______--___--_---__.-_____-______- 21 CMTvoladequatetefie-inlongstringkoaurfcsg---_--__--_--------------- NA---___ _ProductioncasingsetinY-25.--.______-__.__.-__---------------------- --- 22 CMT willcoyer_allknown_productivehorizons_--------------------------- Yes------ ------------------------- ----- -- -- - - -- -- -- -- --- 23 Casing designs adequate for C,TB&_Rermaf[ost_-____-_---_--___-_---- Yes------ -------------------- - -- -- -- - -- --- -- -- 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ _ Rig equipped with steel pits. NoleseNe p!t planned._ All waste-to approved disposal well(s). _ _ - - _ . - _ _ _ _ - _ 25 re-dtill,has_a10.403 for abandonment keen aRP--roved---------------------- ifa Yes------ -308-320------------------------------- -- - ----- -- -- - - 26 _ Adequate wellkore sep$ration ptop9sed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ _ Proximity analysis pert-onned, Nearest segment is P$A podion- of Y-25 and paths-diverge, Other wells in-zone. _ _ 27 Ifdiverler_required, does it rneetregulatiens_-------------------------- NA------_ .BOPsiack_willalreadY_beinplace------------------------------------------- - Appr Date 28 Dri(lingfluidprogramschematic & ec#uip fstadequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - _ -Maximum expected formation pressure 7,1-EMW._ MW planned 8.5ppg• _ - _ _ - _ - _ _ - _ _ _ _ _ - _ _ . _ _ _ - TEM 911112008 29 BOP6s._dothey-meetregulatien -- ------ -- -- -- - - --- Yes --- --- -- -- --- -- --- -- -- -- - -- -- - ------ 5h,~ ~I 30 BOPE_press ratig9 aAPtopriate; tes# to-(put prig in commeMS)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ - _ MAS?calculated at 2370 psi, 3500.Psi-BOP test planned, - - - _ _ _ _ _ _ _ _ _ - - _ _ - _ _ _ _ - _ - - - - - - - - - - ' Y" I 31 Choke_manifold complies wlAPl_RP-53 (May t34) - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work willoccu[wi#heutoperationshutdown_---------------------------- Yes----- ------------------------------------ -- -- --- -- --- 33 is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - _ - _ - _ _ _ . _ Yes - _ _ _ - _ _ H2$ is reperied at Y pad• _ Mud_ should preclude.H2S on rig._ Rig has sensors and-alarms. - _ _ - _ _ _ - _ _ . - _ 34 Mechanical-condition of wells within AQR verified (Fat service well onl - - - ya - --- --- NA- _ _ _ - _ - - - - _ - - - _ _ - _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 Permitc_anheissuedwlohydrogen_suffKlemeasutes______________________-_ No______ _Maxl•eyelH2S onY-pad is200ppm_forwellY-28,____..___-__-.-___-______.-__-______. 36 Data_presented on potential Dverpressurezories- - - - - - - - - - - - - - - - - - - - - - - - - - -KA - - - - ------------------------------------------------------ - - - - - - Appr Date 37 Seismic_anaNsi&ofshallowgaszones - --- -- ---- - -- -- --- NA-- -- --- -- -- -- -- --- -- ------- -- -------- - -- ------ ACS 91512008 3$ Seakedc~nditkonsun+ey-(ifoff-shore)--------------------------------- - NA_----- _--_-- --------------------------------------------------------------- 39 ContactnamelphoneforweeklY_Rrogressreports_[exploratoryonly]________________ _ No_-_--- --------------------- --- -~ --------- - --- --- -- ~ --- -- Geologic Engineering P blic Date: Date Date stoner C m Commissioner: o ~ Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER **** MWD 09/01/27 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/11/29 2298294 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 10900.0000: Starting De th STOP.FT 13835.0000: Ending Dept h STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: Y-25A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 16' 3.666"N 148 deg 49' 49.050"w CNN. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 29 Nov 2008 API API NUMBER: 500292188301 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 33 TOWN.N T11N RANG. R13E . PDAT. MSL EPD .F 0 . LMF DF . FAPD.F 78.7 . DMF DF . EKB .F 0 EDF .F 78.7 . EGL .F 0 Page 1 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~ r tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths, (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and any depth shifting has been waived by Cole Abel with BP Exploration (Alaska), Inc. The MwD data is the Primary Depth Control (PDC) log for Y-25A. (8) The sidetrack was drilled from Y-25 through a milled window in a 5 1/2 inch liner. Top of window 11305 ft.MD (8915 ft.TVDSS) Bottom of window 11313 ft.MD (8917 ft.TVDSS) (9) Tied to Y-25 at 11297 feet MD (8913.4 feet TVDSS). (10) No MwD tools were utilized on runs 3, 7, 8 and 9. (11) The interval from 13806 feet to 13835 feet MD (8961.4 feet to 8965.2 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(L5)400kHz-compensated Borehole Corrected (oHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 76 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and any depth shifting has been waived Page 2 tapescan.txt by tole Abel with BP Exploration (Alaska), Inc. The MwD data is the Primary Depth Control (PDC) log for Y-25A. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units Size Length 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 164 Tape File start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth units = **** FILE TRAILER **** Tape Subfile: 2 177 Minimum record length: 54 Maximum record length: 4124 10900.000000 13835.000000 0.500000 feet records... bytes. bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** Page 3 tapescan.txt !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units size Length 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 327 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 10899.750000 Tape File End Depth = 13835.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape subfile: 3 340 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/11/29 2298294 O1 Page 4 **** REEL TRAILER **** MWD 09/01/27 BHI O1 Tape Subfile: 4 Minimum record length: Maximum record length: • tapescan.txt 2 records... 132 bytes 132 bytes a Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR RPD RPS 10900.0000 78.8000 -999.2500 -999.2500 10900.5000 76.0000 -999.2500 -999.2500 11000.0000 89.7000 -999.2500 -999.2500 11100.0000 88.7000 -999.2500 -999.2500 11200.0000 100.1000 -999.2500 -999.2500 11300.0000 104.3000 -999.2500 -999.2500 11400.0000 37.3000 8.3420 8.5950 11500.0000 58.0000 6.5960 7.8560 11600.0000 56.4000 4.4130 4.3430 11700.0000 32.9000 5.6400 5.1970 11800.0000 43.1000 4.7890 4.6000 11900.0000 34.7000 11.7120 13.6390 ROP RAD RAS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 38.9000 7.3960 8.5120 93.1000 5.3520 6.2780 119.1000 4.4800 4.5970 118.4000 6.0780 5.7460 111.9000 5.1530 4.8170 107.6000 8.2310 11.4250 Page 5 tapescan.txt 12000.0000 48.4000 97.4000 7.7770 7.7870 12100.0000 71.0000 112.9000 8.4750 9.8930 12200.0000 42.8000 130.4000 5.2210 5.0930 12300.0000 38.4000 129.8000 5.8220 4.9270 12400.0000 27.0000 105.1000 6.6860 6.2060 12500.0000 27.0000 113.4000 3.7660 3.8050 12600.0000 27.0000 115.6000 4.5850 4.5400 12700.0000 30.6000 98.0000 9.9890 11.4220 12800.0000 34.8000 103.7000 10.3710 10.8390 12900.0000 39.7000 101.4000 7.4470 8.1810 13000.0000 51.4000 95.5000 6.6650 6.6930 13100.0000 55..7000 120.5000 5.8390 6.7440 13200.0000 46.0000 112.8000 8.7220 9.9770 13300.0000 107.4000 59.3000 9.6450 11.9190 13400.0000 38.9000 105.2000 9.0340 10.2340 13500.0000 36.5000 123.9000 4.0320 3.8920 13600.0000 28.9000 617.4000 3.8780 3.1340 13700.0000 25.0000 86.5000 5.7380 5.7250 13800.0000 25.5000 101.0000 -999.2500 -999.2500 13835.0000 -999.2500 113.2000 -999.2500 -999.2500 Tape File start Depth = p 10900.000000 Tape File End ~ept = 13835.000000 Page 6 i 6.2250 4.8000 4.7870 6.6310 6.8400 3.8320 4.7160 7.3830 8.1310 6.1980 6.6490 5.3950 5.7660 5.9560 6.4910 4.1030 5.1630 5.8460 -999.2500 -999.2500 8.7600 8.1700 5.8390 6.4390 7.1120 3.9000 4.7050 9.5170 10.5240 7.3250 6.5550 5.3400 8.3190 10.0140 8.6160 4.2040 4.3460 5.8020 -999.2500 -999.2500 tapescan.txt Tape File bevel spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10899.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10900.0000 78.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11000.0000 89.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11100.0000 88.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11200.0000 100.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 104.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 37.3000 38.9000 7.3960 8.5120 8.3420 8.5950 11500.0000 58.0000 93.1000 5.3520 6.2780 6.5960 7.8560 11600.0000 56.4000 119.1000 4.4800 4.5970 4.4130 4.3430 11700.0000 32.9000 118.4000 6.0780 5.7460 5.6400 5.1970 11800.0000 43.1000 111.9000 5.1530 4.8170 4.7890 4.6000 11900.0000 34.7000 107.6000 8.2310 11.4250 11.7120 13.6390 12000.0000 48.4000 97.4000 6.2250 8.7600 7.7770 7.7870 12100.0000 71.0000 112.9000 4.8000 8.1700 8.4750 9.8930 12200.0000 42.8000 130.4000 4.7870 5.8390 5.2210 5.0930 12300.0000 38.4000 129.8000 6.6310 6.4390 5.8220 4.9270 12400.0000 27.0000 105.1000 6.8400 7.1120 6.6860 6.2060 12500.0000 27.0000 113.4000 3.8320 3.9000 3.7660 3.8050 12600.0000 27.0000 115.6000 4.7160 4.7050 Page 7 i tapescan.txt 4.5850 4.5400 12700.0000 30.6000 98.0000 9.9890 11.4220 12800.0000 34.8000 103.7000 10.3710 10.8390 12900.0000 39.7000 101.4000 7.4470 8.1810 13000.0000 51.4000 95.5000 6.6650 6.6930 13100.0000 55.7000 120.5000 5.8390 6.7440 13200.0000 46.0000 112.8000 8.7220 9.9770 13300.0000 107.4000 59.3000 9.6450 11.9190 13400.0000 38.9000 105.2000 9.0340 10.2340 13500.0000 36.5000 123.9000 4.0320 3.8920 13600.0000 28.9000 617.4000 3.8780 3.1340 13700.0000 25.0000 86.5000 5.7380 5.7250 13800.0000 25.5000 101.0000 -999.2500 -999.2500 13835.0000 -999.2500 113.2000 -999.2500 -999.2500 Tape File Start Deppth = 10899.750000 Tape File End Dept h = 13835.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS • 7.3830 8.1310 6.1980 6.6490 5.3950 5.7660 5.9560 6.4910 4.1030 5.1630 5.8460 -999.2500 -999.2500 9.5170 10.5240 7.3250 6.5550 5.3400 8.3190 10.0140 8.6160 4.2040 4.3460 5.8020 -999.2500 -999.2500 Page 8
