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204-102
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. 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 W-09A Reservoir Abandonment Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-102 50-029-21947-01-00 341J ADL 0047453 17505 Conductor Surface Intermediate Liner Liner 9006 80 3226 14601 277 3289 14241 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" 8525 27 - 107 27 - 3253 25 - 14636 14359 - 14636 14209 - 17498 2720 27 - 107 27 - 2639 25 - 8747 8591 - 8747 8507 - 9004 14241 2260 4760 6820 10530 14241 5020 6870 7740 10160 No Perforations 3-1/2" 9.2# 13Cr80 22 - 14198N/A Structural 4-1/2" Baker S3 Packer No SSSV Installed 14137, 8468 Date: Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY 8/22/2025 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.08 09:49:30 - 08'00' Torin Roschinger (4662) By Grace Christianson at 10:57 am, Aug 08, 2025 325-467 AOGCC witnessed tag TOC. AOGCC witnessed CMIT-TxIA. DSR-8/14/25 June 1,2026 X X 10-407 A.Dewhurst 13AUG25JJL 8/13/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.27 08:37:07 -08'00'08/27/25 RBDMS JSB 082725 Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 Well Name:W-09A Permit to Drill:204-102 Current Status:Not Operable, Suspended API Number:50-029-21947-01 Estimated Start Date:August 22, 2025 Rig:SL, EL, CT Reg. Approval Req’std?10-403 Estimated Duration:5 Days Regulatory Contact:Abbie Barker Sundry Number: First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M) Second Call Engineer:Hunter Gates (215) 498-7274 (M) Current Bottom Hole Pressure:3,600 psi @ 8,800’ TVDss 7.87 ppg | Regional SBHP Max Anticipated Surface Pressure:2,720 psi Based on 0.1 psi/ft gas gradient Last SI WHP:344 psi 5/12/2023 Min ID:2.813” @ 2,107’ MD X-nipple Impassible restriction at ~12,242’ Max Angle:100 deg @ 15,284’ MD >70 Deg Inclination:~14,950’ MD Last Tag:EL tag at 14,225’ ELM Brief Well Summary: W-09A is an Ivishak well that has been suspended since 2006. The well was sidetracked in August 2004 but unfortunately it was not possible to access the liner to perforate. It was suspected that there was a cement obstruction at the liner top or severely buckled pipe due to efforts taken to work the liner to bottom. Attempts with the rig and post rig with service coil to mill through the obstruction were unsuccessful and ultimately led to inadvertently milling a hole into the 3-1/2” liner by 9-5/8” casing annulus. A camera run in October 2004 confirmed a hole was milled through the 3-1/2” liner. In preparation for a RWO to attempt to repair the liner top, the 3-1/2” tubing was cut at 14,136’ ELM in August 2005. It was ultimately deemed that the RWO was too risky to pursue due to the risk of buckled pipe below the obstruction which would still preclude the well from being perforated. W-09A was suspended and has been since August 2006. The well is secure with no perforations and a cement / pipe obstruction in the liner. The well is mechanically sound as proven by a CMIT-TxIA against the 3-1/2” liner, 5-1/2” x 9-5/8” liner hanger / cement, and 9-5/8” casing. Due to coiled tubing staffing constraints, Hilcorp is 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. Hilcorp is requesting a temporary extension of the existing suspensions on the condition that progress is being made to reservoir P&A the wells by the suspension renewal submission due date of 8/28/25. To comply with this requirement, Hilcorp is planning to have Sundries for this work submitted prior to 8/28/25. Objective: The objective of this program is to place a lateral plug across confining layers above the Ivishak reservoir from ~14,240’ – 12,150’ MD. Cement Info: 3-1/2” Liner: Cemented with 68 bbls 15.8 ppg Class ‘G’ cement. 5 bbls of excess cement was circulated out to surface. Based on excess cement circulated to surface and cement cuttings found when milling through the 3-1/2” liner and into the 3-1/2” x 9-5/8” annulus, cement is estimated to be at the liner top, 14,221’ MD. 5-1/2” Liner: Cemented with 455 sx (95 bbls) 15.7 ppg Class ‘G’ cement. No losses reported. A CBL log run 6/28/1989 shows cement bond up into the liner lap at 14,446’ MD. Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 9-5/8” casing: Cemented with 1,444 sx (468 bbls) 13.5 ppg Class ‘G’ followed by 500 sx (104 bbls) 15.8 ppg Class ‘G’ cement. No losses reported. Assuming 30% hole washout and accounting for shoe-track volume, TOC is estimated to be at 6,870’ MD. Top of Sag River formation – 14,634’ MD (8,751’ TVD) Top of Kingak – 12,166’ MD (7,434’ TVD) Current Status: Not Operable. Suspended. Recent Integrity: > 05/12/23: CMIT-TxIA passed to 2424 psi. > 05/11/23: CMIT-TxIA fail > 08/02/20: Suspended well inspection w/AOGCC > 10/28/15: Suspension renewal approved > 06/07/14: Suspended well inspection w/ AOGCC > 09/11/10: Suspended well inspection w/ AOGCC > 09/02/05: CMIT TxIA Passed to 3500 psi > 08/28/05: MITOA FAILED; LLR = 2 bpm @ 1350 psi > 08/26/05: Jet cut tbg @ 14,134' > 08/25/05: Pulled TTP and tbg calipered > 08/21/05: TTP Set @ 14183' MD; MITT Passed to 2000 psi > 08/19/05: Pull TTP from 14183' > 08/01/05: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3000 psi, All LDS cycled OK. > 07/31/05: Set TTP @ 14183' MD > 10/31/04: Ran memory video camera > 08/17/04: Rig MIT-T Passed to 3500 psi, MITIA Passed to 3500 psi WBL Steps: 1 S DRIFT TO TOP OF OBSTRUCTION 2 E PUNCH HOLES ACROSS TUBING TAIL 3 F CIRCULATE IN DIESEL AND CMIT-TXIA 4 C LAY IN LATERAL CEMENT PLUG FROM TOP OF OBSTRUCTION (~14,240’ MD) UP TO 12,150’ MD 5 S AOGCC WITNESSED TAG TOC 6 F AOGCC WITNESSED CMIT-TXIA TO 2,750 PSI Procedural Steps: Slickline 1. Drift to top of obstruction at ~12,240’ MD w/ sample bailer. a. Note that the tubing has not been drifted below the jet cut since it was executed on 8/26/2005. It is possible the 3-1/2” tubing shifted inside of the 9-5/8” casing when the jet cut was made. Ensure there are no square shoulders on the top of the tools that could get caught on the bottom side of the jet cut. b. Reports from E-line on 8/26/2005 indicated heavy amounts of metal shavings on tools. Expect more of the same since the well does not have perforations and never produced. E-Line 1. Punch the tubing tail from 14,196’ – 14,191’ MD (just above the WLEG) and from 14,147’ to 14,141’ MD (just below the production packer. Tie into 3-1/2” tubing tally dated 8/17/2004. Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 a. Use 0 o phase, decentralized, oriented to low side, rated for 3-1/2”, 9.3#, 13Cr tubing. Fullbore 1. Pump 190 bbls diesel down the IA taking returns from the tree cap to adjacent well. At WSS discretion to rig-up flowback tank instead. a. The well was circulated out post tubing cut 9/1/2005. Tubing and IA are currently filled with diesel FP down to ~2,200’ MD and seawater below. 2. After the requested volume of diesel is pumped, jumper TBG and IA to allow diesel to U-tube. a. At this point the well will have diesel FP down to ~4,600’. The extra volume of diesel has been calculated so that ~2,500’ MD is left in the IA after coil circulates in cement. 3. Perform CMIT-TxIA to a target of 2,750 psi target. 3,000 psi max applied. Coiled Tubing 1. MIRU CTU. 2. RIH with cementing BHA w/o checks. 3. Dry tag top of obstruction at ~14,240’ MD. 4. PU 5’ and prepare to pump cement. Cement weight:15.8 ppg Bottom hole static temp:210°F Fluid Loss:60-80 cc/30 min Thickening Time:Minimum 6 hours (~2x pump time) Pump Time:~190 minutes at 1 bpm (3.2 hrs) 5. Pump the following down the coiled tubing. a. 5 bbls fresh water b. 145 bbls 15.8 ppg cement c. 5 bbls freshwater d. 1% KCl displacement 6. Allow 2-3 bbls of cement around nozzle and begin laying in cement 1:1 up to a target depth of 12,150’ MD taking returns from both the TBG and IA. a. Volume from bottom of 7” LTP to top of 7” WLEG (14,237’ – 14,196’) = 0.0383 bpf x 41’ = 1.6 bbls b. Volume of 3-1/2” x 9-5/8” annulus from bottom tubing punch (14,196’) to production packer (14,140’) = 0.0613 bpf x 56’ = 3.4 bbls c. Volume of 3-1/2” tubing from bottom tubing punch (14,196’) to production packer (14,140’) = 0.0087 bpf x 56’ = 0.5 bbls d. Volume of 3-1/2” Tubing from production packer (14,140’) to 12,150’ = 0.0087 bpf x 1,990' = 17.3 bbls e. Volume in IA from tubing cut (14,136’) to 12,150’ = 0.0613 bpf x 1,986’ = 122 bbls f. Total pipe volume to be filled = 144.8 bbls g. FB pumped enough diesel into the IA to leave it freeze protected down to ~2,500’ after 122 bbls of cement have been circulated in. 7. After all cement has exited the nozzle, close in Tuning & IA returns. Begin pulling out of hole pumping pipe displacement. Ensure tubing is freeze protected down to 2,500’ MD. 8. Wash tree and BOPs. There will likely be a small amount of hydrostatic imbalance between the Tubing and IA. Trap this pressure on the well. 9. Breakdown cementing BHA and RDMO. Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 Slickline 1. WOC ~5 days. Drift and tag TOC –AOGCC Witnessed Fullbore 1. WOC ~5 days. CMIT-TxIA to target pressure of 2,750 psi. Max applied of 3,000 psi –AOGCC Witnessed Attachments – x Current Wellbore Schematic x Proposed Wellbore Schematic x Tie-in Log/Tubing Tally x Sundry Change Form Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 Current Wellbore Schematic: 204-102 Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 Proposed Wellbore Schematic: 204-102 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 W-09A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-102 50-029-21947-01-00 17505 Conductor Surface Intermediate Liner Liner 9006 80 3226 14601 277 3289 14241 20" 13-3/8" 9-5/8" 5-1/2" 3-1/2" 8525 27 - 107 27 - 3253 25 - 14636 14359 - 14636 14209 - 17498 27 - 107 27 - 2639 25 - 8747 8591 - 8747 8507 - 9004 14241 2260 4760 6820 10530 14241 5020 6870 7740 10160 No Perforations 3-1/2" 9.2# 13Cr80 22 - 14198 N/A Structural 4-1/2" Baker S3 Packer 14137 8468 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 0047453 22 - 8501 N/A N/A 0 0 0 0 0 0 150 150 150 240 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 14137, 8468 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 7:28 am, Jul 11, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.10 15:22:15 - 08'00' Torin Roschinger (4662) JJL 7/21/25 RBDMS JSB 07172025 DSR-7/21/25 ACTIVITY DATE SUMMARY 7/4/2025 T/I/O = 240/150/50. Temp = SI. Suspended well inspection (AOGCC witnessed by Guy Cook). No AL & No flowline. Well house, cellar & tree are all clean. SV,MV =LOTO. WV,SSV = C. IA, OA = OTG. 11:00 Daily Report of Well Operations PBU W-09A W-09A ** SUSPENDED ** 204-102 Reservoir Abandonment Sundry Well: W-09A PTD: 204-102 API: 50-029-21947-01 Tie-In Log: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 8, 2025Subject: Changes to Approved Sundry Procedure for Well W-09ASundry #: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 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 InspectNo:susGDC250704070447 Well Pressures (psi): Date Inspected:7/4/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:8/7/2006 Tubing:240 IA:150 OA:0 Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/27/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT W-09A Permit Number:2041020 Wellhead Condition The well looked to be in good condition with the expected signs of surface rust. Surrounding Surface Condition Good clean gravel pad. Some wood/debris behind the wellhouse. Condition of Cellar Cellar was clean of debris but had water in it. The water was dirty but there were no signs of hydrocarbons. Comments Location of the well was verified by a Well pad map. Supervisor Comments Photos (8) 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_W-09A_photos_gc Page 1 of 4 Suspended Well Inspection – PBU W-09A PTD 2041020 AOGCC Inspection Rpt # susGDC250704070447 Photos by AOGCC Inspector G. Cook 7/4/2025 2025-0704_Suspend_PBU_W-09A_photos_gc Page 2 of 4 Water in well cellar 2025-0704_Suspend_PBU_W-09A_photos_gc Page 3 of 4 Tubing pressure gauge 2025-0704_Suspend_PBU_W-09A_photos_gc Page 4 of 4 IA pressure gauge OA pressure gauge New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006W-WW 09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-102 6.50-029-21947-01-00 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 17505 14241 8524 14136 14241 8467 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 27 - 107 27 - 107 Surface 3227 13-3/8" 27 - 3253 27 - 2639 5020 2260 Intermediate 14601 9-5/8" 25 - 14626 25 - 8741 6870 4760 Liner 289 5-1/2" 14359 - 14648 8591 - 8753 7740 6820 Perforation Depth: Measured depth: None feet True vertical depth: None feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# 13Cr80 22 - 14198 22 - 8501 14136 8467Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Packer Liner 3277 3-1/2" 14221 - 17498 8513 - 9004 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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: Andy Ogg PBFieldWellIntegrity@hilcorp.co 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 measured9006 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A 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 047453 PBU W-09A 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 m Suspended By Samantha Carlisle at 10:08 am, Aug 21, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.21 10:02:25 - 08'00' Stan Golis DSR-8/21/2020 RBDMS HEW 8/21/2020 MGR04SEP2020 SFD 8/28/2020 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = 150/150/50. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU W-09A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:W-09A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD):2041020 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 8/7/2006 Surface Location:Section: 21 Twsp: 11N Range: 12E Nearest active pad or road:W 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: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: No. Discoloration, Sheens on pad, pits or water: None. Samples taken: None. Access road condition: Access road and pad in good condition. Photographs taken (# and description): No. 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: Tree - Swab, Flow cross with Wing, Surface Safety, Master Wellhead - TBG spool with 2 casing valves, Starting Head with 1 casing valve. Cellar description, condition, fluids: Snow/Ice Melt. Clean Water. Level below lowermost casing valve. Rat Hole: N/A. Wellhouse or protective barriers: Yes, wellhouse. Well identification sign: Yes. Tubing Pressure (or casing if no tubing): 150 psi. Annulus pressures: IA / OA = 150 psi / 50 psi. Wellhead Photos taken (# and description):Yes, (1) wellhouse and sign, (1) wellhead and tree (1) OA casing valve Work Required: None Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 10:30am Time of Departure: 10:45am Site access method: Truck/Walk. 500292194701 Re-Inspection Suspended WellTDspertiOn Review Report |nspecNo: susK4FH200803082049 Date Inspected: 8/2/2020 | Inspector: Matt Herrera Type of Inspection VVeUName: PRUDHOEBAY UNIT VVf}9A | PennbNumber: ----| 2041028 ' | � Suspension Approval: Completion Report Suspension Date: l 8/7/2006 ! Location Verified? b-11 |fVerified, How? � GPS - Subsequent Date AO5[[Notified: 7/31/2020 Operator: HUco/pNorth Slope, LLC � Operator Rep: EhcDickennan Wellbore Diagram Avail? Photos Taken? Well Pressures (psi): Tub|nE,: 150 Fluid inCellar? [] |A: 150/ ' 8PV|nstaUed? [] 0A: ---- —50 -- VR Plug(S) Installed? El Wellhead Condition Wellhead in good shape;no leaks; valves and gauges all operational. SSV still installed in closed position. ' Condition ofCellar � Good. Clean; no water; no stains or subsidence. � Surrounding Suduoe[ond|tiou Well house still over the well. Sunounding gravel clean. Noevidence ofleakage stains orsubsidence. Laterals disconnected ' and blinded off atthe header. Comments Supervisor Comments Photos (3) attached. ~' Thursday, August 20, 2020 Suspended Well Inspection — PBU W -09A PTD 2041020 AOGCC Inspection # susMFH2O0803082049 Photos by AOGCC Inspector M. Herrera 8/2/2020 LI, 1 WELL: W -09A OWpgR P�uJi—Bay IAeI ... ti �u.ry 1 11 N f -i .. U% AN NUMBER 50-0"-204 0 ydµ SUR LOCAPON NE 1 a. Sac 21 t11R. R12E ]�■1' .. LWG K-1 204-/02 2020-0802_Suspend_PBU_W-09A_mh. docx Page 1 of 2 2020-0802_Suspend_PBU_W-09A_mh. docx Page 2 of 2 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI ll • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other:Sus Well Inspection Rpt Il 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-102 3. Address: P.O.Box 196612 Anchorage, Development l Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21947-01-00 7. Property Designation(Lease Number): ADL 0047453 8. Well Name and Number: PBU W-09A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 17505 feet Plugs RECEIVED Pmeasured 14241 feet NOV �f A 4 true vertical 9006 feet Junk measured feet N 2016 Effective Depth: measured 14241 feet Packer measured 14221 feet true vertical 8524 feet Packer true vertical 8513 feetAOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 27-107 27-107 Surface 3227 13-3/8"68#L-80 27-3253 27-2639 5020 2260 Intermediate 14601 9-5/8"47#NT8OS 25-14626 25-8741 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: feet True vertical depth: feetCANNED MA 3 121;!I Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#13Cr80 22-30 [ �1 22-30 Packers and SSSV(type,measured and 3-1/2"Baker ZXP Packer 14221 8513 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,825.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 10 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipr/o�)9 Title PDC Principal Engineer Signature L/ Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 RBD II1S d(fNOV 1 6 2E1 J Submit Original Only • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad W No 09A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2041020 API Number: 500292194701 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 8/7/2006 Surface Location: Section. 21 Twsp: 11N Range: 12E Nearest active pad or road: W-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, clean gravel pad Pad or location surface: Flat gravel pad Location cleanup needed. None Pits condition: Good, Frozen Water Surrounding area condition: Good 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): 1 Photo-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: Good - Production Tree, No Flowline, Blinded Cellar description, condition, fluids' Good -Gravel Cellar, couple of hydrocarbon spots Rat Hole: N/A Wellhouse or protective barriers: Wellhouse, good condition Well identification sign: Yes Tubing Pressure (or casing if no tubing): SSV Closed no panel Annulus pressures: IA=125psi. OA=0psi 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 10 9/2016 Time of arrival: 3:26pm Time of Departure: 3:37pm Site access method: Pickup Truck • 0 00.4 0.2 0 0.4 Miles bp = ==.1. 1 i,...,62-113 W-69 '1V:9 1W 377 ,a1.1-23 1141.71 W.7171 ric I 961L ,2-15 .1W 217P8' PJ-205L 1 ,Z-148 W-23A ,. : - Z-15APE42 4z_I 5,,,p6 1 . 31W-69PB. •W- 4 W-205L 2 ,,cz- 0/- 1A A /55-25 M.00151112 VI-21A L1 01 <2-210PB1 "W-24 VVV-31 W5A „.„22:1-:'Ai.: ,,,,_2, V:205L1P81 -2 .7,3.7AP B1 W-219P B2 4'W-44 W 21c Z-20 W-2IA *-34APB15V'4 •W-30 0-32A W-18A 1V,18 .v.2c <1/11-14A W-32L114"2"' Legend Vor-B01:,PB1 ..V•17A -v., W-227P81 V1A-16. 111'1,2'1/1;,A,,SB' WPipelines(General) -15P 52 V-68PB 1 '''''"..,,„ W-02 :.:*W-35 A'?I I 15 , ,A,,-15P5' X xi,2 I.'\'''-5:I,'w.40 i/WETW //if.iti\\N. 111/-06 ...W-ISA 11A-02 7P-30 Z-39A .1.N-210 W-03A W-207/ Pipelines(Detailed) 1.'W1°2.4+W-020 KUPST-01 1.1.1 375 )",,,39 ; ,;-.... \..\\ "JA WODIAPB1 i.'. W-04 "A SI X <12.28 (Id', W-203L 2 —\l I 71-203 0/...7,03L 1 / ,,,,,, ‘.. ,. ii 08 'r, --\\.\(r / ".?W 4' w ,,, ''''''''4t ,...,.„ , ,,, ,, , s —\1.0,,I ' ---I2c11,1 2-7 I -.//V45 'N ' 2.,38A • \ ' IlV SEEILEEN 2 —I 11111k '1-45a 41r4%;C- :5 ig i 0.0311 l nknm,n -- -06A / , AW-06 -05AL1 '.',Yr' su2ic01c11 l'Irelinc, \I W-05AL I PB1 1 / . , 4.Z-18 46W-11 / / '1 P-16A XiN-.38 )11P 113 112 7 P-16APE .5512 VI-09A 4WENOUWOIA 1.4 ,NA 10 0WENOMWO1 .. :,7 1-MI,-09 yy_,op i) ....,i\A ‘ W-09APB i -... 'SEE1LEEN , , 1533111:1 P-218 \ .P-07. I, Author: ......iCAL VI-07A 14 November,2016 BP1\catrgl c BP Exploration(Alaska)Inc AU rights reserved Thls map is Informatonal in nature and Is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska-gis.bpweb.bp.com warranties as to accuracy,completeness or use for any purpose • • N C � O > i Q E 2 Q. 2 cin 5 j O O• � M O °- a)aa) I.L = 0 •_� U U Q cn a) a) Q- E - a a� a) 5 0 Ci) z CO L1.1 � N Q >- O to m F- U • • m co O O O O O M M O N O ( U +ro O N 3 0 00 LO CO o r- o-) r co O co N- co Lc)N- O CO f� O I,- CO N CO O) CO ":1- 1.0 O CO N N N N 1.0t[) N CO CO CD co CO CO CO I� N 0 O O (D V co M ct V' M r r r V ice+ Q Q) o O "4- (NI N N V C r r • co• I- 0. Lo � ooao ° coco 00 0O U CI U -II— JJM C N Z M r N C CON r-- N O _ • N w � - - U CV O ch C1 0 0 00O C co N CO N O — CD J M M W H C ' U W W � � Q � CD O o a CC Z Z w W w W m O J H Z_ _Z D U U) Z J J H TREEH 41/16" O�� • WELLHEAD= FMC1/1P- ACTUATOR= OTIS KB. ELEV= 90.66' ** SUSPENDED ** BF. ELEV= 53.96' KOP= 904' Max Angle= 61 @ 9500' Datum MD= 14882' Datum TV D= 8800'SS I I 2,107' H3 1/2"'X'landing nipple, ID=2.813" Imo. 13-3/8"CSG,68#, — GAS LIFT MANDRELS L-80,ID=12.415" 3,264' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2158 2000 40 MMG DV RK 5 4300 3185 59 MMG DCK RK 4 6685 4480 55 MMG DV RK 3 8969 5730 57 MMG DV RK 2 11385 6980 56 MMG DV RK 1 14086 8449 59 MMG DV RK ' '— 14,114' _13 1/2"'X'landing nipple, ID=2.813" I t•,/\/N 14136' ELM _I TBG CUT(08/26/05) X-- 14,136' I- 9 5/8"X 4 1/2"Baker S-3 Packer I I 14,163' 43 1/2"'X'landing nipple, ID=2.813" I I 14,183' —3 1/2'"X'landing nipple, ID=2.813" N___.----- 14,198' _13 1/2",9.2#, 13Cr-80,VAMTOPtubing XO 3 1/2"to 7"WLEG H 14,198' 14209' TIEBACK TOP I 14221' H 7"X 95/8"BKR ZXP LNR TOP PKR w/TBS,HMC LNR HNG XO 3 1/2"LNR Top 5-1/2"Liner — 14359' l t•_•4*414 J 14241' CTM _I TOC OR OBSTRUCTION(08/31/04) A;ss•� 9-5/8",474,NS- 1 80S, ID=8.681" 14638' 14,648' Window exit in 5 1/2"liner from eilitill .., Whipstock set on EZSV Marker joint H 14,685' External casing pkr H 14,937' EX X 17,498' —I3 1/2",9.2#,L-80,IBT-M solid liner External casing pkr --I 15,153' g PBTD —I 15300' 5-1/2"Liner, 174, — .000. L-80,ID=4.892" 15428' 11111111 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/02/89 DFF ORIGINAL COMPLETION 08/26/05 GJB/TLH TBG CUT WELL: W-09A 09/04/01 RN/TP CORRECTIONS PERMIT No: 01/26/04 RMO/TLP MINIMUM ID CORRECTION API No: 50-029-21947-01 04/26/04 dew Proposed Completion SEC 21,T11N,R12E, 1437'SNL&1194'WEL 08/27/05 JAF/TLH TOC OR OBSTRUCTION(8/31/04) 08/27/05 JLM/TLH CORRECTIONS 0 BP Exploration(Alaska) I INW/ItI.‘141, op,1 All 11% iii I II 3 I 1 3 1 11 ,f' I I , , , :,,, .., ....... ,, JCAUT } .M.; ., WELL: W-09A . , ,,,, ,'''4`, . ,„ { �� . { CTN9411.# WVSI+n®S,YY 9,4 # OPERATOR Bi,EifW>+4Afa.>H a�WCx 5� } t fi4Xt %Ni liE 14.Sao 21 Tt41 RUE .x Y lXYN.LYIG�OCATPFAAkF 204N12 1 }, a ..p I u i rS' r 3S 3 , I,. ; , t • g v rryye .. P }�.ry, rt,+� . r. • if '" F, " F' .. r+ t. t� ,i • • 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 W-09A Oper.Rep: J.Stephens PTD No.: 2041020 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: ioshua.steohens(Dbp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 08/07/06 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 125 OA 0 Condition of Wellhead: Good condition,wing valve,master valve,SSV closed&hydraulics disconnected.Outlet is blinded.A few hydrocarbon"spots"in steel , cellar box. Condition of Surrounding Surface Level gravel pad with some frozen puddles&road access,no visible hydrocarbon residue.Some wood,trash,piping&metal parts. - Location: Wellhouse in good condition. Follow Up Actions Needed: Clean hydrocarbon residue from cellar. Comments: Well identified by pad map and well sign permanently attached to wellhouse.Mr Stephens took photos at my direction&they are attached to his report. Attachments: none SCANNED JUN 0 8 20i7" REVIEWED BY: Insp.Supry 3 e- ItItOIIt Comm PLB 12/2015 2016-1010_Suspend_PBU_W-09Ajj.xlsx •', OF i wP / •, s THE STAT• T4� Alaska Oil and Gas of Conservation Commission 333 West Seventh Avenue *,;r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 C4 ,,,,,, Main: 907.279.1433 ALAS— Fax: 907.276.7542 www.ao cc.alaska. ov iCAMNE) NOV a 2014 5 g g Ryan Daniel Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. &"t) y- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU W-09A Sundry Number: 315-586 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, Cathy P oerster Chair DATED this dilly of October, 2015 Encl. RBDMS' NOV 0 2 2015 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend N7 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ElRepair Well 0 Re-enter Susp Well 0 Other 57v5pf-h5/ l0 • 07- r-e I/I ]?Lr-eI/I tl tfQ / 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-102 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development I I 99519-6612Stratigraphic 0 Service 0 6. API Number: 50-029-21947-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECF I V E EJ Will planned perforations require a spacing exception? Yes 0 Nom PBU W-09A 9. Property Designation(Lease Number): 110. Field/Pools: SEP 2 1 201 5 ADL 0047453• PRUDHOE BAY,PRUDHOE OIL' 10 2d` ( s 1 11. PRESENT WELL CONDITION SUMMARY � iv Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): J n Q 17501 . 9005 • 14241 8524 14241 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"Conductor 27-107 27-107 Surface 3227 13-3/8"68#L-80 27-3253 27-2639 5020 2260 Intermediate 14601 9-5/8"47#NT8OS 25-14626 25-8741 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): Packers and SSSV Type: 3-1/2"Baker ZXP Packer Packers and SSSV MD(ft)and TVD(ft): 14221, 8513.66 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development LI Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0- 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned o Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is tru and on/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 Pep /1/7 j- COMMISSION USE ONLY C Conditions of approval:Notify Commission so that a representative may witness Sundry Number: r_ 315- `R Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 4p:F ✓'4-I / 3 9ro,.htzd e'[sv�. f %z e1- P or) alc✓c1Dprv1tt,-t of a. pg4 ✓�lq h ,mar Sv5pcvl0/cd frv-e1/5 1 ,'11-h r10 itf�rc ti-1--;11'1-1 wh1-ch i7ri'`'95 flirty lAz-LlS CIO 5cr to 6t. b 1-7G1b{1 p-,--1.e• i-1- prior to pot c✓ cle Cei-wr.vi 155 n iN9 • IPA- nl4 K 1-0 ioz• dCVG/onto/ c - d Gcjnrcv-e 1-4,1•-0U9,11 the L'o3-i-+nn 1`55ia.-1 by 12/31i/& . Spacing Exception Required? Yes 0 No f� Subsequent Form Required: in cm-,, 4f h ,7vre /""o e � with +,tply thls re./1„.ir-e n-�t � vi. t- 1 ,1I 1`✓r ✓ezi/44.-iz fhi5 -pry )4_ n APPROVED BYTHE Approved by: / '"" COMMISSIONER COMMISSION Date:/6_28_/$ VTI- ,,,z,"„-- ORIGINAL o/z,/!SORIGINAL RBDMS NAV @ 2 2157 IP% Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /0. Lei./r • S RECEIVED bp BP Exploration(Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells SEP 2 1 2015 Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 AOGCC August 28, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well W-09A (PTD # 2041020) 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 W-09A on 06/07/2014 (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 W-09A was suspended on 8/07/2006. 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 secure with no perforations and a cement/ pipe obstruction in the the liner 14241' MD. The well is mechanically sound as proven by a CMIT TxIA pressure test after fishing attempts ended. Based on these conditions and the inspection on 06/07/2014 Prudhoe Bay Unit well W-09A 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 W-09A 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, S Douglas A. 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 W-09A (PTD 2041020) Technical Justification for Renewal of Suspended Status August 28, 2015 Well History and Status Prudhoe Bay Unit well W-09A (PTD 2041020) was suspended on 8/07/2006 after leaving a fish in an obstruction in the sidetrack liner. The well is secure with no perforations and a cement/ pipe obstruction in the the liner 14241' MD. The well is mechanically sound as proven by a CMIT TxIA pressure test after fishing attempts ended. 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 W-09A 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= 125/125/0 psi recorded on 6/07/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for W-09A 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 Well Name: Prudhoe Bay Unit W-09A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2041020 API Number 500292194701 Operator: BP EXPLORATION(ALASKA)INC Date Suspended: 8/7/2006 Surface Location Section: 21 Twsp: 11N Range: 12E Nearest active pad or road Prudhoe Bay Unit W-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: graded pad/clean Pad or location surface: Good Location cleanup needed: No Pits condition, water/Ice/snow good condition Surrounding area condition Good Water/fluids on pad. None Discoloration,Sheens on pad,pits or water: No Samples taken. NO Access road condition. good/graded/smooth Photographs taken(#and description): No 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: FMC well head CIW tree good condition No flowline Cellar description,condition fluids, good Rat Hole: N/A Wellhouse or protective barriers Wellhouse Well identification sign: yes Tubing Pressure(or casing if no tubing). SSV is closed TBG is cut 125 psi Annulus pressures: IA=125 psi OA=60 psi Wellhead Photos taken(#and description). (4)tree(1)sign (2)wellhouse Work Required None Operator Rep(name and signature) Laurie Climer AOGCC Inspector: Lou Grimaldi Other Observers: Kevin Parks Inspection Date 6/7/2014 AOGCC Notice Date 6/6/2014 Time of arrival 1:30 PM Time of Departure: 1.50 PM Site access method: Truck • • TREE= 41!16 WELLHEAD= F/i/C W-09A AC1LA1OR= OTIS '`` KB ELEV BF ELEV= 53 96 KOP= 904' Max Anykl= 61 995X0 Datum MD= 148M' Datum 1V D= 8800 SS I I I 2,10T H3 1/2"'V Landing niiple,0=28131 I:=1 13-18'CSG,684 — 3.264' GAS LET MANDRELS L-60 ID= 12.415' ST MD TVD DEV TYPE VLV LATCH PCP, DA TE 6 2158 2030 40 MING DV R< 5 4300 3185 59 WAG (XX FE 4 6685 4480 55 MSG DV FK 3 8969 5730 57 WAG DV RK 2 11385 6980 56 MMG DV FK 1 14088 8449 59 V. DV FK I II— -I 14,114' 1_13 1/2"'X landing rippc,0=2.81T I 14138ELM 1_1118G CUT(08/26/05)I ..7, 14,1 36' H9 5,8"X4 1/2'Baker S-3 Foam I I 14,163' 143 1/2"'X'landiig nipple,D=2813" I I 14,183' 143 1/2—X'WOO()nipple,ID=2 813' 1 14,19, 1_13 1/2",9.20,13C7-80,VAM IC, , /7 1 X03 1to r WLEG H 14,191? 1-k 14209' ::ACK TCP 1----1 14221' HT X 9 Sir 13KR ZXPLkft TOPPKR w/lES 141.4C LNR 149G X0 31/2'LW I I Top 5-12-I-1,11: H 14359' I '177171 I j 1 14241'CTM 1_1 TOC CR OBSTRICTCM(M/31/04) I 1 . ,.,.., . ...40 vAttt 9.5,9' 474.l.'.,- 146 38' 1 85S,ID=8 Eel' from 14,648, set__ exit i..,5 1/7 Inv et on I "OW Pill H 14.685' 1 4P____. ON I External zasing per r 14.93T I Z II*4 = 1 * I I1 17A98' 1_43 1/7,9.21i,L-80,eT-1.4 solid liner I I External caseng per H 15,152r I Ire , 1121 FBTD 15300' °AV liSSI 5-12"Lie .170. — Otiatt.a.ii L-80.ID=4 892" 154.213' DA IE. REV BY COMMENTS EA TE FEV BY CONVENTS FRLIDFOE BAY LINO 07/02189 OFF ORIGNAL COMPLETION 08126,05 GJ3/R14 TBG CLX 38a1. W-043A 09/04.01 RN'lP GURREC1 DNS PERMIT M. 3112604 RtderILP fiiNIMUM ID CORRECTION API No. 50-329-2194 04/26104 dew Proposed Completion 98221,11111.13 R12E 1437'SNL&1194 a 3812705 JAFTTLH TOC OR U13S 1 RUCT ON(8131X14) 08,27K15 .LAVILH WRRECTUNS I BP Btploration(Alaska) • • m Q, 0CD 00, 0 M (ON(fl15 � N O N VCO U U) O O O O i N N- 7 O CO m LO CO C` O CO N- O LO CO N- N CO O Co i H CO I` LC) O CO N N N LC) in Co Co 4-1 a) co CO COCO f— NO) V O V CO M (fl V I� (0) I 1 1 ++ Q QQ) CO C ti N- LC) O N N N V V _ T- T- • W O CO CO U - I E J J Z .N N c ( 01N- O _ cri U bo -- N o N Lr) Ch Lc) rn r N- C)O N O CO C CO N N 0 JCO V- CO Ch W O)O _ H W ' U W U Z D W W W O D H Z Z U U) =, TREE=. 41/16 • • WELLHEAD= FMC iito9A ACTUATOR= OTIS KB. ELEV= 90.66 " SUSPENDED ' BF. ELEV= 53.96' KOP= 904' Max Angle= 61 @ 9500' Datum MD= 14882' Datum TVD= 8800'SS I i 2,107' - 3 1/2"'X'landing nipple, ID=2.813" I 4.1 13-3/8"CSG,68#, 3264' GAS LIFT MANDRELS L-80, ID=12.415" ' ST MD TVD DEV TYPE' VLV LATCH PORT DATE 6 2158 2000 40 MMG DV RK I-V - 5 4300 3185 59 MMG DCK RK 4 6685 4480 55 MMG DV RK 3 8969 5730 57 MMG DV RK 2 11385 6980 56 MMG DV RK 1 14086 8449 59 MMG DV RK I 1 14,114' _3 1,2"'X'!arcing 8,polo ID=2 8" 3" /•/\/\ 14136' ELM _JTBG CUT I:I8,26/05) ><1 14,136' 14,5,3" X 4 1:2"Baker S-3 Packer I I 14,163' _..J3 1'2"'X'la^d,re nipple ID=2813" I I 14,183' .J3 1/2"'X'landing nipple.ID=2.813" 14,198' 43 1/2 ,9.2#, 13Cr-80,VAM TOP tubing X0 3 1/2"to 7"WLEG - 14,198' I---.. ..- "N_____------ I I ---- 14221142Hr.0'9' TIEBACK TOP I X 9 5/8"BKR ZXP LNR TOP PKR w/TBS,HMC LNR HNG X0 3 1/2"LNR Top 5-1/2"Liner H 14359' MO j t :•4$ I 14241' CT M LITOC OR OBSTRUCTION(08/31/04) I .• 4 t• . 44-4. . 9-5/8 ,474, NS- - 14638' ! 80S, ID=8.681" Window exit in 5 1/2"liner from 14'648. -Whipstock set on EZSV Marker joint H 14,685' 0 External casing pkr H 14,937' X1 „. 0, --....„ 4' ,.., ,. 0 --- 17,498' _13 1/2",9.24.L-80, IBT-M solid liner External casing pkr - 15,153' r5;<' '','' PBTD -I 15300' •••./..• 5-1/2"Liner, 174, - ....... 15428' 1000. L-80, ID=4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/02/89 OFF ORIGINAL COMPLETION 08/26/05 GJB/TLH TBG CUT WELL: W-09A 09/04/01 RN/TP CORRECTIONS PERMIT No: 01/26/04 RMO/TLP MINIMUM ID CORRECTION , API No: 50-029-21947-01 04/26/04 dew Proposed Completion SEC 21,T11N, R12E, 1437'SNL& 1194'WEL 08/27/05 JAF/TLH TOC OR OBSTRUCTION(8/31/04) 08/27/05 JLM/TLH CORRECTIONS 0 BP 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 would 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.loepp( 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.Loepr, alaska.gov CONFIDENTIALITY NOTICE: his 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.Loepo@alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [mailto:Ryan. ,Obp.ca ] 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) [ .o:victoria.loeppOalaska.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 [inailto:Oliver.Sternicki@bc.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 wo Oobal,..*.orgapnex Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickia,bp.com From: Loepp, Victoria T(DOA) rnailto:victoria.loeop@ 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.Loepp(a.a laska.q ov 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.Loeno@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.Sternicki@bp.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 WC) global Weft Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(a�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@alaska.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 S-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.Loeppalaska.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 ctoria.Loepp@alaska.gov 4 • • Lmage Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~- - ~ ©~, Well History File Identifier ar anizing (done> ^ Two-sided III IIIIIIIIIII IIIII ^ Rescan Needed ~~~ IIIIII~~~~ 111111 9 RESCAN Color Items: ^ Greyscale Items: DIG TAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria ^ Logs of various kinds: ^ Other:: Date: Date: ~iuiuiiiiiuiliii ~1~ ~~--~-- O Scanning Preparation ~ x 30 =~ ~ v + =TOTAL PAGES (Count does not include cover sheet) 1/~/~ BY: Maria Date: Q' l ~ /f~Q /s/ , r r Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: _~/ YES NO BY: Maria Date: / $ ~ ~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU W -09A Oper. Rep: Jack Winslow PTD No.: 2041020 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 08/07/06 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed - Photos Taken? Yes IA 140 by Operator OA 60 Condition of Wellhead: Well house in place, full tree with closed SSV, flow line removed and blinded. Condition of OK Surrounding Surface Location: Follow Up Actions none Needed: I I Attachments: None REVIEWED BY: Insp. Supry Jg 7 IU17C f( Comm PLB 08/2010 2010- 0911_Suspend_PBU_W- 09A_cs.xls DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2041020 Well Name/No. PRUDHOE BAY UNIT W-09A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21947-01-00 MD 17501 TVD 9005 Completion Date 8/7/2006 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su DATA INFORMATION 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 / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ ~ D Asc Directional Survey 15728 17505 9/14/2004 IIFR ~~ Directional Survey 15728 17505 9/14/2004 IIFR ~D D Asc Directional Survey 14607 16323 9/14/2004 IIFR P61 .. ~~, R pt Directional Survey 14607 16323 9/14/2004 IIFR P61 .. ,, ~ i ~D D Asc Directional Survey 14607 16323 9/14/2004 MWD P61 ~F~t / Directional Survey 14607 16323 9/14/2004 MWD PB1 ,~~ EI~ D 12649 Gamma Ray 14596 17439 Open 9/28/2004 MWD, EWR4,ROP, GR pt LIS Verification 14596 17439 Open 9/28/2004 MWD, EWR4,ROP, / GR,DSN 12649 6tD C Lis 13727 Induction/Resistivity 14636 17505 Open 2/22/2006 ROP DGR EWR plus Graphics / PB 1 14636- 16323 ROP DGR EWR plus Graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? 1~P~4-- Analysis ~~ Y / N Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~/ N r1 J Comments: DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2041020 Well Name/No. PRUDHOE BAY UNIT W-09A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21947-01-00 MD 17501 TVD 9005 Completion Date 8/7/2006 Completion Status SUSP Current Status SUSP UIC N Compliance Reviewed By: Date: ~.~vEQ STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM SION ~..~;!; ~ 8 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOC~~u~~ Oii ~~ Cas Cons Commission ~nchora ~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended ^ WAG zoAaczs.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One .Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) tnc. 5. Date Comp., Susp., or Aband. 8/7/2006 12. Permit to Drill Number 204-102 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/26/2004 13. API Number 50-029-21947-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/8/2004 14. Well Name and Number: PBU W-09A 1437 SNL, 1194 WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 1308' SNL, 5200' WEL, SEC. 33, T11 N, R12E, UM 8. KB Elevation (ft): 78.66' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 943' SNL, .1951' WEL, SEC. 32, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 17430 + 8985 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5958820 Zone- ASP4 10. Total Depth (MD+TVD) 17501 + 9005 Ft 16. Property Designation: ADL 047453 TPI: x- 608223 y- 5948332 Zone- ASP4 Total Depth: x- 606186 y- 5948668 Zone- ASP4 11. Depth where SSSV set (Nipple) 2108' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR / RES 22. CASING, LINER AND CEMENTING RECORD CASING SETT{NG DEPTH MD SETT{NG DEPTH TVD HOLE AMOUNT SIZE VVT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 13-3/8" 68# L-80 Surface 3264' Surtace 2650' 17-1/2" 4500 cu ft Coldset II 9-5/8" 47# NT80S Surface 14638' Surface 8753' 12-1/4" 3212 cu ft Class'G' 5-1/2" 17# L-80 14359' 1463 ' 8596' 8747' 8-1/2" 536 cu ft Class'G' 3-1/2" 9.2# L-80 14209' 17498' 8507' 9004' 4-3/4" 371 cu ft Class'G' 23 Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SEr MD PACKER SET MD None -Unable to Re-Enter 3-1/2", 9.2#, 13Cr80 14198' 14137' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect with 160 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A -Unable to Perf Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PfeSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips "none". r None AT ~ o~Gv~~D~ ~~ ~~6 /~?~ g/ d~~ ~(~,~ V IF FJ7 Form 10-407 Revised 12/ 0 A`"~ ` ~ ~` ` ~ ~ g S ~ i NTINUED ON REVERSE SIDE ~ ~ auG ~ ~ zoos {r~~'t r 28 GEOLOGIC MARK 29. ORMATION TESTS Include and brie y summarize test results. List intervals tested, Nanne MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 14623' 8739' None Shublik A 14661' 8761' Shublik B 14748' 8808' Shublik C 14803' 8835' Shublik D 14833' 8851' Eileen 14848' 8858' Sadlerochit 14902' 8885' 45N 15006' ' 8915' Sadlerochit 15337' 8885' Sadlerochit 15527' 8890' Sadlerochit 16555' 8880' Sadlerochit 16715' 8880' 45N 17078' 8904' 45P 17140' 8917' 44N 17180' 8927' 44P 17187 8929' 43N 17374' 8972' 43P 17382' 8974' 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ( Signed Terrie Hubble ~ Title Technical Assistant Date ` ~/~ 7 ~ (p PBU W-09A 204-102 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Thomas Schaefer, 564-4685 Permit No. / A royal No. INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. 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: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE = 4 1 / 16" WELLHEAD= FMC ACTUATOR = OTIS KB. ELEV = 90.66' BF. ELEV = 53.96' KOP = 904' Max Angle = 61 @ 9500' Datum MD = 14882' Datum TVD = 8800' SS L-80, ID = 12.415" 3,264' XO 3 1/2" to 7" WLEG ~-~ 14,198' Top 5-1/2" Liner 14359' 9-518°, a7#, Ns- 14638' 80S, ID = 8.681" Marker joint 14,685' External casing pkr 14 937' External casing pkr 15,153' STD 15300' 5-1/2" Liner, 17#, L-80, ID = 4.892" 15428' -09A Com Ilion p FROM DRLG -DRAFT ** SUSPENDED ** 2,107' 3 1 /2" 'X' landing nipple, ID = 2.813" GAS LIFT MANDRELS ST MO TVD DEV TYPE VLV LATCH PORT DATE 6 2158 2000 40 MN1G DV P,K 5 4300 3185 ~9 MMG DCK RK 4 6685 4480 55 MMG DV RK 3 8969 5730 57 MMG DV RK 2 11385 6980 56 MMG DV RK 1 14086 8449 59 MMG DV RK 14,114' ~ 3 1 /2" 'X' landing nipple, ID = 2.813" ' 14136' ELM TBG CUT (08/26/05) 14,136' 9 5/8" X 4 1/2" Baker S-3 Packer 14,163' 3 1/2"'X' landing nipple. ID= 2.813" 14,183' 3 1/2"'X' landing nipple. ID = 2.813" 14,198' 3 1/2", 9.2#, 13Cr-8Q VAMTOPtubing 14209' TIEBACK TOP 14221' 7" X 9 5/8" BKR ZXP LNR TOP PKR w / TBS, HMC LNR HNG XO 3 1 /2" LNR 14241' CTM IJ TOC OR 14,64$' Window exit in 5 1/2" liner from Whipstock set on EZSV • "~ ,~ ~ _~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07102189 DFF ORIGINAL COMPLETION 08/26/05 GJBITLH TBG CUT 09/04/01 RN/TP CORRECTIONS 01/26/04 RMO/TLP MINIMUM ID CORRECTION 04126/04 dew Proposed Completion 08/27/05 JAF/TLH TOC OR OBSTRUCTION (8/31/04) 08/27/05 JLM/TLH CORRECTIONS 17,498' 3 1/2", 9.2#. L-80, IBT-M solid liner PRUDHOE BAY UNff WELL: W-09A PERMff No: API No: 50-029-21947-01 SEC 21, T11N, R12E, 1437' SNL & 1194' WEL BP F~cploration (Alaska) BP Exploration Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date From - To I Hours Task Code '~, 7/2/2004 12:00 - 15:00 ~ 3.00 ~ RIGU ( P 15:00 - 15:30 0.50 WHSUR P 15:30 - 17:00 1.50 WHSUR P 17:00 - 17:30 0.50 WHSUR P 17:30 - 18:00 0.50 WHSUR P 18:00 - 19:00 1.00 WHSUR P 19:00 - 23:00 4.00 WHSUR P 23:00 - 23:30 23:30 - 00:00 7/3/2004 00:00 - 01:00 01:00 - 01:30 0.50 WHSUR P 0.50 WHSUR P 1.00 WHSUR P 0.50 ~ WHSUR ~ P 01:30 - 02:30 02:30 - 05:00 05:00 - 08:30 08:30 - 09:00 09:00 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 18:30 18:30 - 19:00 19:00 - 00:00 1.00 WHSUR I'I P 2.50 BOPSUF{ P 3.501 BOPSURP 0.50 BOPSU P 1.50 PULL 1.00 PULL 0.50 PULL P 1.50 PULL P 0.50 PULL P 0.50 PULL 4.00 PULL P 0.50 PULL P 5.00 PULL P Spud Date: Start: 7/2/2004 End: Rig Release: 8/18/2004 Rig Number: Page 1 of 24 NPT Phase Description of Operations PRE Move rig from W-11 to W-09. Spot rig over W-09. Shim and berm rig. RU over W-20. Spot slop tank. RIG ACCEPTED C~ 15:00 hrs. DECOMP Pre-spud mtg with all rig personnel. DECOMP Take on seawater. RU on tree and annulus to circulate wellbore. DECOMP PJSM with DSM and rig personnel on pulling BPV. DECOMP RU DSM lubricator. Pull BPV. RD DSM. Tbg and annulus on vacuum. DECOMP Reverse circulate freeze protect out of tubing, 3bpm C~ 375 psi DECOMP Mix and pump 50 bbl detergent pill. Displace well with 1000 bbl seawater, 5.5 bpm ~ 580 psi. Recovered: 150 bbl diesel DECOMP RD and blow down lines. DECOMP Bleed off well. Flow check -Static DECOMP Install TWC, unable to pressure test. Pull TWC and change out seal ring. Re-install TWC and pressure test to 1000 psi from below. DECOMP PJSM with FMC and rig personnel on nippling down tree and adapter flange. DECOMP ND tree and adapter flange. DECOMP NU BOPE. Install HCR valves. Hook up choke & kill lines to HCR valves. NU riser & flow line. DECOMP RU test equipment. Test ROPE - 250/3500 psi, annular 250/3500 psi. All tested for 5 min Hi/Low. Witness of test waived by John Spaulding - AOGCC. DECOMP Blow down lines and RD BOP test equipment. LD test joint. DECOMP RU casing tongs and Camco spooling unit. DECOMP RU DSM lubricator and pull TWC. RD DSM lubricator. DECOMP RIH with landing joint and TDS crossover, screw into tbg hanger 10-1/2 turns. BOLDS. PU 180k string weight and unseat tbg hanger. Up weight w/ tbg 154k. Pull hanger to floor. DECOMP RU circulating head and lines to 4-1/2" tbg. CBU, 10 bpm 650 psi. DECOMP Monitor well -static. PJSM on pulling and laying down 4-1/2" tbg. DECOMP Breakout and LD landing joint. Terminate control lines. Breakout and LD tbg hanger. DECOMP POH, laying down 4-1/2" tbg, spooling up dual 1/4" control Tines with Camco spooling unit. Recovered: 57 -joints 4-1/2" tbg Control line 3 -stainless steel bands. 29 -control line bands. 1 -Otis SSSV assembly. 3 - 4-1/2" tbg pups. DECOMP RD Camco spooling unit. LD Otis 4-1/2" SSSV assembly. DECOMP POH, laying down 4-1/2" tbg and completion jewelry. Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal Well Name: W-09 Page 2 of 24 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date From - To i Hours '~' Task I Code ~ NPT Phase Description of Operations 7/3/2004 19:00 - 00:00 5.00 PULL P DECOMP Midnight: 235 jts laid down. 7/4/2004 00:00 - 04:30 4.50 PULL P DECOMP Continue POH laying down 4-1/2" tbg and completion jewelry. Recovered: 357 -joints 4-1/2" tbg 3 -GLM assemblies 1 - 19.35' cut joint of tbg Tubing stub ~ 14220' KB 04:30 - 06:00 1.50 PULL P DECOMP RD 4-1/2" tbg equipment. Clear tools & scrub rig floor. 06:00 - 07:00 1.00 BOPSU P DECOMP RIH with test joint and set test plug, RU test equipment. RILDS on test plug. Test lower 2-7/8" X 5" variable pipe rams to 250 psi / 3500 psi. BOLDS and pull test plug. Install wear bushing. RD test equipment. 07:00 - 07:30 0.50 FISH P DECOMP PJSM with BOT and rig personnel on picking up BHA #1. 07:30 - 09:30 2.00 FISH P DECOMP PU AND MU BHA #1 to retrieve K-anchor. 09:30 - 11:30 2.00 FISH P DECOMP RIH with BHA #1 picking up DP from pipe shed. 11:30 - 13:00 1.50 FISH P DECOMP Rig service, cut and slip drill line 13:00 - 00:00 11.00 FISH P DECOMP Continue RIH with BHA #1 picking up DP from pipe shed. Midnight depth: 11319' 00:00 - 03:00 3.00 FISH P DECOMP Continue RIH with BHA #1 picking up DP from pipe shed. 03:00 - 03:30 0.50 FISH P DECOMP Stage pumps to 4.5 bpm Q 700 psi and establish baseline parameters: P/U 215k Ibs S/O 140k Ibs ROT 174k Ibs I Torque 8.5k ft-Ibs ~ 40 rpm Wash down from 14170', engage fish at 14202. Continue down, no-go after swallowing 9 ' of tbg. Slack off to 125k. Pick up to 320k and trip jars to set grapples. Grapples slipped after putting 15 turns RH torge into tbg. Pick up to 350k and trip jars to set grapples. K-anchor jarred free. RIH and tag up to verify K-anchor is free. 03:30 - 05:00 1.50 FISH P DECOMP CBU, 10 bpm ~ 2920 psi. 05:00 - 13:30 8.50 FISH P DECOMP POH with K-anchor. 13:30 - 16:00 2.50 FISH P DECOMP LD BHA #1 and fish Recovered: 4 - 4-1/2" tbg pups 1-GLM 1 -Landing Nipple 1 -Cut joint of tbg K-anchor Total length = 68.65' 16:00 - 16:30 0.50 FISH P DECOMP PJSM with BOT and rig personnel on picking up and running packer retreival BHA. 16:30 - 17:30 1.00 FISH P DECOMP PU and MU BHA #2, packer picker 17:30 - 23:00 5.50 FISH P DECOMP RIH with BHA #2, break circulation every 30 stands. 23:00 - 23:30 0.50 FISH P DECOMP Stage pumps to 5.5 bpm @ 1030 psi and establish baseline parameters: Printed: 8/23/2004 9:23:01 AM BP Exploration Page 3 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date !From - To Hours I Task Code !. NPT Phase ! Description of Operations 1 I ! i 7/5/2004 23:00 - 23:30 0.50 FISH P DECOMP P/U 230k Ibs S/O 144k Ibs ROT 177k Ibs Torque 9k ft-Ibs @ 50 rpm Wash down from 14191', engage fish at 14258. Continue down, no-go after packer picker running 7' below the top of the packer. Pick up to 250k to verify the grapples are below the packer. Bottom of packer picker at 14274', mill at 14267'. 23:30 - 00:00 0.50 FISH P DECOMP Mill packer from 14267'. WOB = 5-10klbs RPM = 90-100 Torque = 8-16k FtLb 6 bpm @ 1100 psi P/U 230k S/0144k ROT 177k 7/6/2004 00:00 - 07:30 7.50 FISH P DECOMP -Continue milling packer from 14267' to 14270'. - Utilizing pump rates from 0 - 8 bpm and rotary speeds from 90 - 150 rpm. - Torque = 8-16k FtLb 07:30 - 09:30 2.00 FISH P DECOMP -Monitor well -pump hi vis sweep & circulate hole clean. 09:30 - 15:30 6.00 FISH P DECOMP - POH to BHA w/ packer. - Packer hanging up in casing collars. 15:30 - 17:30 2.00 FISH P DECOMP - UD BHA & packer assy. 17:30 - 18:30 1.00 FISH P DECOMP - R/U & test 9 5/8" casing to 3500 psi for 30 min.. - 12.5 bbls to pressure up casing. 18:30 - 20:30 2.00 FISH P DECOMP - M/U 9 5/8" Fast Drill Bridge Plug & BHA. 20:30 - 22:00 1.50 FISH P DECOMP -RIH w/ Fast Drill to 2800'. 22:00 - 22:30 0.50 FISH P DECOMP -Set Fast Drill w/ 38 RH turns & shear w/ 60K up wt. - Ensure Fast Drill set w/ 25K do wt. - Close pipe rams & test casing to 3500 psi for 5 min. 3.0 bbls to pressure up casing. Open pipe rams. 22:30 - 00:00 1.50 FISH P DECOMP - POH w( Fast Drill setting tool. 7/7/2004 00:00 - 01:30 1.50 FISH P DECOMP - POH w/ bridge plug setting tool & rack back BHA. 01:30 - 02:30 1.00 FISH P DECOMP -RIH w/ 9 5/8" mechanical casing cutter to 2800' to displace well to 9.5 ppg brine before making cut at -2200'. 02:30 -04:00 1.50 FISH P DECOMP -Displace S!W w/ 9.5 brine in 9 5/8" x DP annulus @ 5 BPM C~ 870 psi. 04:00 - 07:30 3.50 FISH P DECOMP -Attempt to locate collars w/ 150 psi pump pressure w/o success. Cut 9 5/8" casing ~ 2200'. - Close annular preventer & circulate 40 bbl soap sweep followed by 9.5 brine & displace freeze protect from 13 3/8" x 9 5/8" annulus. 07:30 - 09:00 1.50 FISH P DECOMP - POH & UD 9 5/8" casing cutter. 09:00 - 14:00' 5.00 FISH P DECOMP -Pull wear ring, N/D BOP stack & tubing spool. - Unable to remove bushing from tubing spool. - Pulled primary packoff from casing stub. - Tack weld slips to casing. 14:00 - 16:00 2.00 FISH P DECOMP - N/U new tubing spool & BOPE. 16:00 - 17:30 1.50 FISH P DECOMP - M/U spear assy & latch 9 5/8" casing. Unseat 9 5!8" casing slips w/ 45K overpull. Pull 9 5/8" casing to floor. Weld on emergency slips did not hold, leaving slips in hole. Printed: 8/23/2004 9:23:01 AM BP Exploration Page 4 of 24 Operations Surnmary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date From - To Hours I, Task Code' NPT Phase bescription of Operations 7/7/2004 16:00 - 17:30 1.501 FISH P DECOMP -Flow check showing well static. 17:30 - 19:30 2.00 FISH P DECOMP -Drain stack. - Open top & bottom ram doors & retrieve slip body & all 4 segments. 100 % recovery. 19:30 - 20:00 0.50 FISH P DECOMP -PJSM - R/U casing handling equip't. 20:00 - 00:00 4.00 FISH P DECOMP - POH & UD 9 5/8" casing. - Connections difficult to break - utilizing steam, hammers, & hi torque casing tongs. - Flow check & hole fill showing well static. 7/8/2004 00:00 - 05:00 5.00 FISH P DECOMP - POH & UD 9 5/8" casing. - Recovered 55 jts, 33' partial jt, & 15 centralizers. - Flow check & hole fill showing well static. 05:00 - 05:30 0.50 FISH P DECOMP - P/U jt. # 1 - B/O & UD spear assy. 05:30 - 07:00 1.50 FISH P DECOMP -Clean & clear rig floor of casing tools. 07:00 - 09:30 2.50 FISH P DECOMP - M/U 12 1/4" bit & 13 3/8" casing scraper &RIH. Tag 9 5/8" casing stump C~ 2200'. 09:30 - 10:00 0.50 FISH P DECOMP - CBU @ 10 BPM 670 psi. 10:00 - 12:30 2.50 FISH P DECOMP -Monitor well -pump dry job - POH & UD BHA. 12:30 - 14:00 1.50 FISH P DECOMP - M/U 13 3/8" Fast Drill Bridge Plug &RIH - set ~ 2102' - Attempt to test 13 3/8" casing. Pumped 2 bbl ~ 340 psi & leaked. 14:00 - 15:30 1.50 FISH P DECOMP - POH & UD setting tool. - Clean floor. 15:30 - 18:00 2.50 FISH P DECOMP - M/U RTTS, RIH to 60', & break circ. - Set RTTS C~ 60' & test above to 800 psi -leaked. Test below to 2000 psi & held. - Pull up to 50' & set RTTS. Test below to 2000 psi & held. - POH & UD RTTS. 18:00 - 20:00 2.00 FISH N DFAL DECOMP - M/U 13 3/8" cutting assy &RIH. Locate collar @ 69'. - P/U to 50' & start cutting 13 3/8" casing. 90 RPM, TO 3K, & various pump rates from 3 BPM - 4.5 BPM, 1250 psi - 2500 psi. - No torque increase for 45 min - staedy C~3 3K. Knives on cutter not protruding enough to cut through casing. 20:00 - 21:30 1.50 FISH P DECOMP - POH & remove stop from casing cutter to allow full extension of knives. - RIH & cut casing (~ 50'. 85 RPM, TO 3K - 7K, 3 BPM, 1170 psi. 21:30 - 22:00 0.50 FISH P DECOMP - POH & UD cutting assy. - Some cement on knives indicating cement behind 13 3/8" casing. 22:00 - 00:00 2.00 FISH P DECOMP -PJSM • N/D BOPE & tubing spool. 7/9/2004 00:00 - 00:30 0.50 FISH P DECOMP - N/D BOPE & tubing spool. 00:30 - 01:30 1.00 FISH P DECOMP RIH w! 13 3/8" spear assy & attempt to pull & jar casing free w/o success. Made 5 attempts to jar free - P/U wt up to 375K. 01:30 - 02:00 0.50 FISH P DECOMP POH & UD spear. 02:00 - 03:30 1.50 FISH P DECOMP M/U cutting assy & swap pistons to allow cutting operations w/o circulating. RIH to 1' below 13 3/8" mandrel hanger. Make cut w/ 70 RPM, TQ 5K - 15K, 1050 psi w/ no flow. 03:30 - 05:30 2.00 FISH P DECOMP Attempt to P/U fish w/ 30K overpull w/o success. POH & UD cutting assy. M/U spear & engage fish & pull free w/ 200K. Printed: 8/23/2004 9:23:07 AM BP Exploration Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date From - To I Hours Task Code 7/9/2004 03:30 - 05:30 ~ 2.00 ~ FISH P 05:30 - 08:30 3.00 FISH P 08:30 - 11:00 2.50 FISH P 11:00 - 12:00 I 1.001 FISH I P 12:00 - 14:00 2.00 FISH N 14:00 - 15:00 1.00 FISH P 15:00 - 17:00 2.00 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 20:00 2.00 FISH P 20:00 - 23:00 I 3.001 FISH I P 23:00 - 00:00 1.00 FISH P 7/10/2004 00:00 - 01:00 1.00 FISH P 01:00 - 02:30 , 1.50 FISH P 02:30 - 07:00 I 4.501 FISH I P 07:00 - 08:00 1.00 FISH P 08:00 - 09:30 1.50 CASE P 09:30 - 10:00 I 0.501 CASE I P 10:00 - 11:00 1.00 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 14:30 2.00 CASE P 14:30 - 17:00 I 2.501 FISH I P 17:00 - 17:30 0.50 FISH P 17:30 - 19:00 1.50 FISH P 19:00 - 19:30 0.50 CASE P 19:30 - 21:30 2.00 CASE P 21:30 - 22:00 i 0.501 CASE I P Start: Rig Release: Rig Number: NPT Phase ~; Spud Date: 7/2/2004 End: 8/18/2004 Page 5 of 24 Description of Operations DECOMP Disengage spear & UD fish in cellar. POH & UD spear assy. Pin hole found 4" below mandrel hanger in 13 3/8" pup jt. DECOMP P/U & M/U 16" wash pipe & handling equip't. DECOMP Wash over 13 3/8" casing w/ 16" wash pipe to 61' RKB. Firm cement -wash over C~ 2.7 BPM, 70 psi POH w/ wash pipe. DECOMP Cut eye holes in 13 3/8" casing stub. Pull & UD 19.43' casing stub. RREP DECOMP Repair blower motor shroud on TD. DECOMP M/U jt of DP on top of wash pipe & wash from 61' to 80'. No cement. DECOMP POH w/ wash pipe & break connections. Connections tight. DECOMP Clean & clear floor of 16" wash pipe tools & equip't. DECOMP R/U Schlumberger E-line & RIH w/ 8 strand string shot. Locate collar (~ 69' & fire string shot. R/D Schlumberger & keep on location until back off complete. DECOMP P/U 13 3/8" back off assy &RIH. Set bottom anchor w/ 1500 psi pump pressure. Pressure up to 2000 psi & ensure top anhor set. Bottom of top anchor set @ 60'. Back off 13 3/8" casing w/ 1200 psi. Back out a full 5 revolutions. Release Schlumberger once back off confirmed. DECOMP POH & UD back off assy. DECOMP Continue POH & UD back off assy & stand back DC's. DECOMP M/U &RIH w/ 13 3/8" spear assy. Engage spear into 13 3/8" casing stub & back out 6 revolutions w/ neutral wt. POH w/ 18.24' casing stub. DECOMP R/U to run 13 3/8" casing. Cut off old 20" landing ring & weld on new 20" landing ring. Clean & prep new wellhead equip't. DECOMP P/U spear & 13 3/8" casing stub & break out. UD same. DECOMP RIH w/ screw in sub, 19.83' 13 3/8" L-80 68# pup jt, & one 37.65' L-80 68# 13 3/8" jt on jt of 4" DP. Tag collar & screw into 13 3/8" w/ 12.5K fUlbs tq. P/U 200K to ensure M/U. DECOMP Pressure test 13 3/8" casing -test failed -communication between 20" & 13 3/8". DECOMP Back off the top jt. of 13 3/8" casing & UD same. DECOMP Clear & clean floor -mobilize HOWCO for RTTS. DECOMP Lubricate rig -Service TD & blocks. DECOMP M/U &RIH w! 13 3/8" RTTS & set C~ 72'. Test 13 3/8" casing below to 1500 psi - OK POH & UD RTTS. DECOMP P/U 13 3/8" spear &RIH. Engage pup jt & screw in sub & B/O w/ neutral wt & LH rotation. POH & UD pup jt & screw in sub. Found bow spring centralizer bands jammed inside screw in sub between pin end of pup jt & wall of screw in sub. DECOMP RIH w/ 11" magnet to 75' & POH. No metal found on magnet. DECOMP RIH w/ 12 1/4" bit to 75' & circulate 5 BPM for 1 minute to clean up threads on casing collar. POH & UD bit. DECOMP R/U to run 13 3/8" casing. DECOMP RIH w/ screw in sub, 21.53' L-80 68# 13 3/8" pup jt, & 37.65' L-80 68# jt 13 3/8" casing. Tag collar @ 69' & screw into 13 3/8" w/ 12.5K ft/Ibs tq. P/U 150K to ensure M/U. Pressure test 13 3/8" casing to 2500 psi for 10 minutes -good test. DECOMP R/U to cement 13 3/8" casing by running two jts 1" inside 20" x 13 3/8" annulus. Tag up on cement 65' from ground level w/ 1 ". R/U cementers. Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date From - To I Hours Task I Code 7/10/2004 22:00 - 23:30 1.50 REMCM P 23:30 - 00:00 0.50 CASE P 7/11 /2004 00:00 - 00:30 0.50 ~ CASE P 00:30 - 04:30 4.00 04:30-12:30 ~ 8.OO~WHSUR~P 12:30 - 14:00 I 1.501 WHSUR I P 14:00 - 15:30 I 1.501 W HSUR I P 20:30 - 20:30 1.00 BOPSU~ P 21:30 - 22:30 I 1.001 CASE I P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 FISH P 7/12/2004 00:00 - 01:30 1.50 FISH P 01:30 - 03:30 2.00 FISH P 03:30 - 05:00 1.50 FISH P 05:00 - 07:00 2.00 FISH P 07:00 - 07:30 0.50 FISH P 07:30 - 09:30 2.00 I FISH P 09:30 - 11:00 ~ 1.50 (FISH ~ P 11:00 - 13:30 2.50 (FISH P 13:30 - 14:30 1.00 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 16:30 1.50 FISH P 16:30 - 17:30 1.00 FISH P 17:30 - 18:00 0.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P Page 6 of 24 Spud Date: Start: 7/2/2004 End: Rig Release: 8/18/2004 Rig Number: NPT Phase II Description of Operations DECOMP PJSM - Test lines to 500 psi & pump 11 bbls. 15.7 ppg Arctic Set I cement. DECOMP Suck out cellar & clean out landing ring. Center up 13 3/8" to set 13 3/8" emergency slips. DECOMP P/U 13 3/8" 100K over & set emergency slips. S/O casing. DECOMP Cut 13 3/8" casing & UD. Weld on transition nipple -pre-heat w/ hot head & wrap w/ insulation. UD casing tools. General housekeeping on rig. DECOMP Allow transition nipple to cool down w/ hot head. Notes: While waiting on transition nipple to cool rig crew per#ormed the following: Full inspection & maintenance of TD. Plumbing in new # 1 boiler. Plumb lines for chemical shack. Load & prep 9 5/8" casing. DECOMP Test weld on transition nipple w/ nitrogen -failed. Weld C~3 leak & retest to 1340 psi -good test. DECOMP Install FMC starting head & tubing spool & pressure test metal to metal seal to 1000 psi -good test. DECOMP N/U BOPE. DECOMP R/U test equip't & install test plug. Body test BOPE to 250 psi / 3500 psi. Pull test plug. DECOMP Close blind rams & test 13 3/8" casing to 2500 psi for 30 min - good test -bleed off pressure & open blind rams. DECOMP Install wear bushing. DECOMP M/U 12 1/4" BHA for drilling 13 3/8" Fast Drill Bridge Plug. DECOMP RIH to 2052' w/ 12 1/4" drilling assy. DECOMP M/U std. 4" DP pipe to TD. Off bottom parameters - S/O wt 84K, up wt 84K, Rot wt 84K, 2.5K Tq. Pump rate - 5 BPM 180 psi. Wash down & tag bridge plug ~ 2111'. Drill bridge plug w/ 25 - 35K wt on bit, 80 - 90 RPM, 3 - 9K Tq, 5 BPM 180 psi. Chase bridge plug to top of 9 5/8" casing stub ~ 2200' & resume drilling. DECOMP POH w/ 12 1/4" drilling assy. DECOMP C/O 12 1/4" bit for 8 1/2" bit & RIH to 2200'. DECOMP Attempt to enter 9 5/8" stub w/ various rotary speeds w/ 8 1/2" bit w/o success. DECOMP POH - UD bit & boot baskets. Clean boot baskets -small amounts of CBP. DECOMP Clear floor - P/U bullnose & 8 1/2" tapered string mill & RIH to 2200'. DECOMP Engage remnants of 13 3/8" CBP inside 9 5/8" casing stub ~ 2003'. Attempt to work through w/ various rotary speeds w/o success. DECOMP POH. DECOMP UD bullnose & string mill -inspect same - P/U 6 3/4" junk mill. DECOMP RIH w/ 6 3/4"junk mill. Mill on CBP remnants for 1 1/2 minutes & CBP fell. Chase CBP remnants to 2710'. DECOMP POH w/ 6 3/4" mill. DECOMP UD mill assy & clear floor. DECOMP PJSM - R/U Sclumberger E-line. DECOMP RIH w/ E-line & locate 9 5/8" collar on first full jt below stub C~1 2242'. Fire 8 strand string shot C~ 2242'. POH & R/D Printed: 8/23/2004 9:23:01 AM BP Exploration Page 7 of 24 Operations Summary Report Legal Well Name: W-09 Common W ell Name: W-09 Spud Date: Event Nam e: REENTE R+COM PLET E Start : 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: L1ate -- - _ _ From - To ! I Hours ~~I Task I ~ Code ~; NPT '~, Phase a; - Description of Operations ~ 7/12/2004 _ 19:00 - 20:00 1.00 _ FISH P - - DECOMP - -- _ _ __ Schlumberger. 20:00 - 21:00 1.00 CASE P DECOMP Close blind rams & perform infectivity test through kill line. Pump C~ 1 BPM for 4 bbls - pressure broke over @ 1120 psi. & decreased to 750 psi. Increase pump rate to 3 BPM 820 psi & pumped additional 16 bbls. Bled off 1 bbl back to trip tank. 21:00 - 23:00 2.00 FISH P DECOMP P/U & M/U 9 5/8" back off BHA. 23:00 - 00:00 1.00 FISH P DECOMP RIH w/ 9 5/8" back off assy to 1796' 7/13/2004 00:00 - 01:30 1.50 FISH P DECOMP RIH w/ 9 5/8" back off assy & set bottom anchor w/ 1200 psi & S/O. Confirm bottom anchor set. Increase pressure to 2500 psi & S/O to neutral wt & confirm top anchor set. Bleed off pressure. Pressure up on drill string & back off 9 5/8" casing ~ 2242'. Casing backed out w/ 1650 psi. Bleed off pressure. Continue to cycle pump until casing backed out a full 5 revolutions. 01:30 - 02:00 0.50 FISH P DECOMP Drop ball & shear open pump out sub w/ 2000 psi. Pump dry job 02:00 - 03:00 1.00 FISH P DECOMP POH to BHA. 03:00 - 05:00 2.00 FISH P DECOMP UD DC's, back off tool, & rack back 3 stands of DC's. 05:00 - 07:00 2.00 FISH P DECOMP Clear rig floor & P/U 9 5/8" spear assy. C/O grapple & M/U spear assy. 07:00 - 08:00 1.00 FISH P DECOMP Cut & slip 98' of drilling line. Lubricate rig. 08:00 - 09:00 1.00 FISH P DECOMP RIH to 2200' & engage fish w/ spear. Complete back off w/ neutral wt. 09:00 - 11:30 2.50 FISH P DECOMP POH & UD fish & spear assy' Recovered 1 full jt of 9 5/8" casing & 4.80' 9 5/8" stub w! turbolator. 11:30 - 12:00 0.50 CASE P DECOMP R/U casing tools for running 9 5/8" casing. 12:00 - 12:30 0.50 WHSUR P DECOMP Pull wear ring 12:30 - 17:00 4.50 CASE P DECOMP PJSM for running casing. Run a total of 55 jts 9 5/8" casing - 21 jts 47# L-80 BTC-Mod on bottom & 34 jts 40# L-80 BTC on top. M/U 9 5/8" 9K fUlbs torque. 17:00 - 17:30 0.50 CASE P DECOMP M/U x-overs & 5' DP pup & M/U to TD. 17:30 - 18:00 0.50 CASE P DECOMP Tag 9 5/8" casing stump & screw into w/ 9 5/8" casing. M/U w/ 9K fUlbs tq. S/O wt 117K. Pull test to 50K over-okay. Pressure test 9 5/8" casing to 3500 psi for 10 min. -good test. 18:00 - 20:00 2.00 CASE P DECOMP PJSM -Pump out stack & disconnect flowline. Break out BOP stack below tubing spool. P/U stack & secure w/ bridge cranes. 20:00 - 22:00 2.00 CASE P DECOMP P/U 80K & set 9 5/8" emergency slips. 22:00 - 23:30 1.50 CASE P DECOMP Cut 9 5/8" casing w/ mechanical cutter & dress up stub. 23:30 - 00:00 0.50 CASE P DECOMP UD cut off 9 5/8" stub. 7/14/2004 00:00 - 02:00 2.00 WHSUR P DECOMP M/U 9 5/8" packoff & running tool on test jt &RIH. Packoff hanging up -pull packoff. Obstruction in lower pipe ram cavity. Partially close lower rams & allow ram to push out metal. Run through stack w/ tee bar on tugger & knock metal free. Recovered 9 5/8" turbolator. RIH w/ 9 5/8" packoff & running tool on test jt & set packoff. 02:00 -04:30 2.50 WHSUR P DECOMP N/U BOP stack, flowline, & turnbuckles. Test 9 5/8" packoff to 2400 psi -good test. P/U & B/O x-overs from 9 5/8" cut off jt. UD same. Install test plug. 04:30 - 05:00 0.50 WHSUR P DECOMP Body test BOP stack to 250 psi !3500 psi. 05:00 - 06:00 1.00 WHSUR P DECOMP Pull test plug & install wear ring. R/U to test casing 06:00 - 06:30 0.50 CASE P DECOMP Pressure test 9 5/8" casing to 3500 psi for 30 min & chart - good test. Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Page 8 of 24 Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations __ 7/14/2004 106:30 - 07:30 07:30 - 08:00 08:00 - 10:00 1.00 I CLEAN ~ P 0.50 CLEAN P 2.00 CLEAN P 10:00 - 14:30 4.50 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 20:00 5.00 CLEAN P 20:00 - 21:00 1.00 CLEAN P 21:00 - 23:00 I 2.00 I CLEAN I P DECOMP P/U jars & bumper sub, break out spear assy & VD spear. P/U junk baskets & M/U 8 1/2" bit. DECOMP Lubricate rig. DECOMP RIH to 2718' & tag junk. M/U TD -wash & push junk from 2713' to 2791'. Off bottom parameters - 7 BPM 550 psi, P/U wt 88K, S/O wt 80K, ROT wt 80K, 80 RPM 3.5K fUlbs. Tq. DECOMP DECOMP DECOMP DECOMP DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 7/15/2004 00:00 - 05:30 5.50 CLEAN P DECOMP 05:30 - 06:30 1.00 CLEAN P DECOMP 06:30 - 07:30 1.00 CLEAN P DECOMP 07:30 - 08:30 1.00 CLEAN P DECOMP 08:30 - 09:00 0.50 CLEAN P DECOMP 09:00 - 09:30 0.50 CLEAN P DECOMP 09:30 - 15:00 5.50 CLEAN P DECOMP 15:00 - 22:00 7.00 CLEAN P DECOMP 22:00 - 22:30 ~ 0.501 CLEAN P DECOMP 22:30 - 00:00 1.50 CLEAN P DECOMP 7/16/2004 00:00 - 01:30 1.50 CLEAN P DECOMP 01:30 - 02:30 1.00 CLEAN P DECOMP 02:30 - 07:30 5.00 CLEAN P DECOMP Note: Freeze protect 13 3/8" x 9 5/8" OA w/ Littlle Red Services out of critical path. PJSM -Test lines to 2500 psi -pump 141 bbls 9.3 ppg # 4 diesel @ 3 BPM, 900 psi. 500 psi on OA once job complete. Drill junk &CBP from 2791' to 2797' w/ 5K to 15K on bit, 100 RPM, Tq 5K, pump rate 8 BPM 580 psi. Plug fell down hole while drilling ~ 2797'. Pump 20 bbl hi -vis sweep &circ surface to surface ~ 9.5 BPM 820 psi. Sweep brought back small amounts of CBP rubber. Continue RIH w/ 8 1/2" drilling assy on 4" DP to 14343'. M/U TD & wash from 14343' & tag junk / CBP ~ 14352'. 3 BPM 260 psi. Off bottom parameters w/ pump - 5 BPM 730 psi, P/U wt 250K, S/O wt 135K, ROT wt 175K w/ 60 RPM 10 K ft/Ibs Tq. Drill junk !plug from 14352' to 14353.5' w/ 5K to 10K wt on bit, 80 RPM, 10K to 14K fUlbs Tq, pump rate 4:8 BPM 530 psi. Stalled top drive w/ 20K ~ 14353.5'. P/U off bottom & slowly rotated back down & stalled out again ~ 14353.5'. Estimated 5 1/2" liner top. Pump 40 bbl hi-vis sweep &circ surface to surface @ 9.5 BPM 2660 psi. Rotate @ 110 RPM & reciprocate. Pump dry job & B/D TD. POH from 14353' to 13236'. POH from 13236' to BHA w/ 8 1/2" drilling assy. B/O & VD 6 1/4" DC's. B/O & VD BHA. Empty junk baskets - 2 lbs. of metal & rubber. Clear floor of tools. R/U to to run 4 3/4" x 3 1/2" BHA. Lubricate rig & inspect TD. PJSM - M/U slim hole tools. P/U & M/U BHA Shallow test MWD. RIH w/ 4 3/4" milling assy from 581' to 14287' filling every 30 stands. Float sub in string for MW D collar. M/U TD & screw into stand 144. Off bottom parameters w/ pump - 3.5 BPM 1300 psi, P/U wt 210K, S/O wt 142K, ROT wt 172K w/ 9K fUlbs. Tq. Wash down & tag junk /plug C~ 14351'. Mill on junk /plug from 14351' to 14355' w/ 1 K to 5K wt on mill, 3.5 BPM 1260 psi, 60-70 RPM, 9K - 11 K ft/Ibs. Tq. Continue milling on junk from 14355' to 14362' w/ 2K-5K wt on mill. 3.5 BPM 1460 psi, 60 - 70 RPM, 9K - 11.5K ft/Ibs Tq. Junk /plug fell ~ 14362'. Work through TOL x 5 to ensure clear of junk. Wash down from 14362' to 14576' Cif 3.5 BPM 1510 psi. M/U singles & tag junk ~ 14605'. Milling on junk from 14605' to 14612' w/ 1 K - 15K wt on mill, 1 BPM 800 psi, 2 BPM 1000 psi, 3.5 BPM 1450 psi, 60 - 80 RPM 9.5K - 11.5K ft/Ibs. Tq. No progress made last 1.5 hrs. milling. Printed: 8/23/200a 9:23:01 AM BP Exploration Operations Summary Report ..Page 9 of 24 Legal WeII Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date ;From - To 'Hours ', Task ~ Code ' NPT ', Phase- ! Description of Operations ,` 7/16/2004 07:30 - 08:00 0.50 CLEAN P DECOMP P/U drill string & increase pump rate to 3.5 BPM 1150 psi. Lost 300 psi pump pressure. Tq. decreased to 8.5K fUlbs. Lost MWD signal -cycle pump in attempt to regain signal w/o success. Possible twist off or washout. 08:00 - 15:00 7.00 CLEAN P DECOMP POH looking for washout. 15:00 - 18:00 3.00 CLEAN P DECOMP UD BHA including 3 1/2" DC's. Could not break connection on MW D hang off collar. Attempted to B/O w/ 6000 ft/Ibs Tq. UD collar & sent to Sperry Sun for B/O. Recovered 100% BHA & no drill string washout. Junk mill completely worn -pressure loss possibly due to worn mill & bad MWD. 18:00 - 19:00 1.00 CLEAN P DECOMP Clear & clean rig floor. 19:00 - 22:00 3.00 CLEAN P DECOMP M/U BHA w/ new 4 3/4" junk mill. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH w/ 4 3/4" milling assy to 5255'. 7/17/2004 00:00 - 05:00 5.00 CLEAN P DECOMP Continue RIH w/ 4 3/4" milling assy filling every 35 stands from 5255' to 14265'. Off bottom parameters C«? 14265' - 4 BPM 1060 psi, P/U wt 200K, S/O wt 140K, ROT wt 168K @ 50 RPM, 7.5K fUlbs Tq. 05:00 - 06:00 1.00 CLEAN P DECOMP Wash down from 14265' to 14612' ~ 5 BPM 1600 psi. Tagged junk @ 14612'. 06:00 - 08:30 2.50 CLEAN P DECOMP Mill junk from 14612' to 14619' w/ 2 - 5K on mill, 60 - 75 RPM, 7.5K - 9K ft/Ibs Tq, 5 BPM 1690 psi. 08:30 - 10:00 1.50 CLEAN P DECOMP Wash & push junk from 14619' to 14720' ~ 5 BPM 1600 psi. 10:00 - 12:30 2.50 CLEAN P DECOMP Mill junk from 14720' to 14725' @ 5 BPM 1600 psi, 6K - 8K wt on mill, 80 RPM 10K fUlbs Tq, 12:30 - 13:00 0.50 CLEAN P DECOMP Dress off top of cement (~ 14725' w/ 5 BPM 1600 psi, 5K - 10K wt on mill, 100 RPM, 9K fUlbs. TQ Set 30K down on plug x 3 to ensure solid bottom for whipstock. 13:00 - 14:00 1.00 CLEAN P DECOMP CBU @ 7 BPM 2100 psi. Cement cuttings on B/U. 14:00 - 17:00 3.00 CLEAN P DECOMP Clean out pits for taking on mud. 17:00 - 18:30 1.50 CLEAN P DECOMP Fill pits w/ 8.4 ppg flo-pro mud. 18:30 - 21:30 3.00 CLEAN P DECOMP PJSM w/ Drilling Sup'v, Tool Pusher, Mud Engineer, Rig Crews, & Truck Drivers for displacement. Pump 40 bbl hi-vis sweep followed by 180 bbls flo-pro mud C~3 7.5 BPM 3400 psi, rotating C~? 80 RPM's & reciprocating. Shut down pump & drop opening dart for circ sub -pump dart down @ 2 - 2.6 BPM, 700 - 850 psi. Circ sub opened w/ 1800 psi after pumping 60 bbls. Increase pump rate to 15 - 18 BPM, 2700 - 3150 psi, 80 RPM's & reciprocating. 21:30 - 23:00 1.50 CLEAN P DECOMP CBU ~ 15 BPM 2770 psi, 80 RPM & reciprocating. 23:00 - 00:00 1.00 CLEAN P DECOMP Pump dry job - B/D TD & POH wet 7/18/2004 00:00 - 00:30 0.50 CLEAN P DECOMP Service TD & lubricate rig. 00:30 - 01:00 0.50 CLEAN P DECOMP POH wet. 01:00 - 02:00 1.00 CLEAN P DECOMP Pump dry job -monitor well - B/D TD 02:00 - 09:00 7.00 CLEAN P DECOMP POH w/ 4 3!4" milling assy to BHA. 09:00 - 13:00 4.00 CLEAN P DECOMP B/O & VD 4 3/4" BHA. Clean out junk baskets -recovered 1 gal. of small metal pcs & pcs of CBP. 13:00 - 14:00 1.00 CLEAN P DECOMP Clear tools & clean rig floor. 14:00 - 15:00 1.00 CLEAN P DECOMP R/U test equip't for testing BOPE. Pull wear ring -install test plug & test jt. 15:00 - 20:00 5.00 BOPSU P DECOMP Pressure test ROPE to BP & AOGCC Regs. 3500 psi H / 250 psi L for 5 min. Test witnessed by AOGCC Rep John Crisp. 20:00 - 20:30 0.50 BOPSU P DECOMP R/D test equip't -pull test plug -install wear ring. 20:30 - 21:00 0.50 DECOMP Lubricate rig & service TD. Printed: 8/23/2004 9:23:01 AM BP Exploration Page 10 of 24 Operations Summary Report Legal Well Name: W-09 Common W ell Name: W-09 Spud Date: Event Nam e: REENTE R+COM PLET E Start : 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date ', From - To I Hours ! Task '~ Code ~~ ' i NPT Phase i, l ! Description of Operations 7/18/2004 21:00 - 22:30 1.50 BOPSU P ~_ _- - __ DECOMP -_ _ __ _ _ Install modified flow nipple. 22:30 - 00:00 1.50 CASE P DECOMP R/U test equip't to test casing. Pressure test 9 5/8" casing x 5 1/2" liner to 3500 psi for 30 min. -good test. 7/19/2004 00:00 - 00:30 0.50 EVAL P DECOMP PJSM w/ Schlumberger & rig crew. R/U sheaves & E-line 00:30 - 04:30 4.00 EVAL P DECOMP Run GR &CCL on E-line w/ 4.5" gauge ring & junk basket. Hung up Q TOL & worked through. Could not get past 14610'. Made several attempts w/o success. POH & clean out junk basket. 2 pcs rubber & 1 pc of metal. Largest pc of rubber measuring 6" x 2". All pcs appear to be from CBP. 04:30 - 07:30 3.00 EVAL P DECOMP RIH w/ GR &CCL on E-line w/ 4.5" gauge ring & junk basket. Went through TOL w/ no problem, but could not get past 14610'. Made several attempts to work through 14610' w!o success. Logged up through TOL. POH 07:30 - 11:00 3.50 EVAL P DECOMP Remove gauge ring & junk basket. RIH w/ GR &CCL. Tagged up ~ 14609' & worked through to 14725' Logged up to 14100' w/ GR &CCL. 11:00 - 15:00 4.00 EVAL P DECOMP M/U new CCL, gauge ring, & junk basket w/o GR RIH to 14610' & tagged up. Attempt to work through for 1.5 hrs. w/o success. POH w/ E-line. R/D E-line. 15:00 - 18:30 3.50 CLEAN P DECOMP P/U & M/U 4 3/4" string mill BHA. 18:30 - 19:30 1.00 CLEAN P DECOMP Slip & cut 114' drilling line. 19:30 - 00:00 4.50 CLEAN P DECOMP RIH to 9673' filling every 30 stands. 7/20/2004 00:00 - 02:30 2.50 CLEAN P DECOMP Continue RIH w/ 4 3/4" string mill to 14301', tilling pipe every 30 stands. 02:30 - 03:30 1.00 CLEAN P DECOMP M/U TD and establish off bottom parameters: P/U 205K S/O 140K ROT 175K Torque 8.5k fUlbs 2 bpm Q 700 psi. 03:30 - 04:00 0.50 CLEAN P DECOMP RIH & tag up at 14611'. P/U and attempt to break circulation, drill string plugged off, pressured up string to 2500 psi. Attempt to unplug by pressuring up, bleeding off, & moving string w/o success. 04:00 - 09:00 5.00 CLEAN P DECOMP Mill from 14611' to 14622' with no pump. WOM 2 - 7 klbs 80-100 RPM Torque 9k fUlbs 09:00 - 09:30 0.50 CLEAN P DECOMP 09:30 - 10:00 0.50 CLEAN P DECOMP 10:00 - 11:00 1.00 CLEAN P DECOMP 11:00 - 11:30 0.50 CLEAN P DECOMP 11:30 - 12:30 1.00 CLEAN P DECOMP 12:30 - 13:00 0.50 CLEAN P DECOMP 13:00 - 18:30 5.50 CLEAN P DECOMP 18:30 - 20:30 2.00 CLEAN P DECOMP 20:30 - 21:00 0.50 CLEAN P DECOMP 21:00 - 21:30 0.50 CLEAN P DECOMP Fell through obstruction with the string mill at 14619'. Reamed through from 14600' to 14640' 5 times. PU to 14600' and RIH to 14640' without rotating 5 additional times. RIH to TD C~ 14725'. Set down at 14725' 2 times with 20k. POH to 14330 and work through liner top 2 times. RIH to TD at 14725' w/o problems. POH from 14725' to 14330' Drop dart and attempt to open circ sub w/o success. POH with wet 4" DP. Service top drive, tube rig. Continue POH with wet 4" DP. LD BHA #21, mill assembly Clean and clear rig floor. PJSM with Schlumberger and rig personnel on rigging up and Printed: 8!23/2004 9:23:01 AM BP Exploration Page 11 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date ~ From - To ~ Hours Task ~ Code ~ NPT - I_ ' i 7/20/2004 21:00 - 21:30 0.50 CLEAN P 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 7/21/2004 00:00 - 00:30 0.50 CLEAN P 00:30 - 03:00 I 2.501 CLEAN I P 03:00 - 05:00 I 2.001 CLEAN 1 P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 11:00 2.00 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30- 13:00 0.50 STWHIP P 13:00 - 17:30 4.50 STWHIP P 17:30 - 00:00 6.50 STWHIP P Spud Date: Start: 7/2/2004 End: Rig Release: 8/18/2004 Rig Number: Phase Description of Operations DECOMP running slick line. DECOMP RU slick line to run junk basket gauge ring. DECOMP Run 4.75" gauge ring and junk basket on slick line. DECOMP RIH with 4.75" gauge ring and junk basket, unable to get below tight spot at 14611'. POH, 1 cup rubber and fiberglass from composite bridge plugs recovered from junk basket. DECOMP MU up additional weight bar above junk basket. RIH with 4.75" gauge ring and junk basket for attempt #2. Still unable to get below tight spot at 14611'. POH, 1 cup rubber and fiberglass recovered from junk basket. DECOMP MU junk basket with 4.66" gauge ring and a roller stem. RIH to TD ~ 14724' SLM. PU and work through 14600' to 14724' 6 times. DECOMP POH with slick line. Recovered 2 cups metal shavings and small pieces of metal from junk basket. DECOMP RIH with 4.66" gauge ring and junk basket, work through from 14600' to 14724' SLM. DECOMP POH with gauge ring and junk basket. Recovered 2 cups paraffin, metal shavings and pieces of composite bridge plugs. DECOMP RIH with 4.66" gauge ring and junk basket, work through from 14600' to 14724' SLM 6 times. DECOMP POH with gauge ring and junk basket. Recovered a few small pieces of composite bridge plugs and 2 small metal cuttings. DECOMP RD Schlumberger slickline. WEXIT PJSM with BOT, Sperry and all rig personnel on picking up and running whipstock and MWD tools. WEXIT PU and MU BHA #22, whip stock and mill assembly. Shallow test MWD tools WEXIT RIH with whipstock, limit running speed to 1-1/2 to 2 minutes per stand. Fill DP, circulate a DP volume and check MWD tools every 30 stands. 7/22/2004 i 00:00 - 05:30 i 5.50 ~ STW H I P ~ P 05:30 - 08:00 2.50 STWHIP P 08:00 - 08:30 0.50 STWHIP P 08:30 - 18:00 I 9.501 STWHIPI P Midnight depth: 8369' WEXIT RIH to 14320' with whipstock and milling assembly, limiting running speed to 1-1/2 to 2 minutes per stand. Fill DP, circulate a DP volume and check MWD tools every 30 stands. WEXIT Wash down from 14320'to 14705' with whipstock and milling assembly. P!U 195k S/O 140k 4 bpm ~ 1540 psi WEXIT Orient whipstock face to 40L. RIH and set down at 14725'. Set trip anchor with 25k down weight. Pull up 10k over string weight to verify anchor set. Set down 30k to shear mills free. TOW - 14636' BOW - 14648' WEXIT Mill window from 14636' to 14639'. WOM = 3-5 klbs RPM = 50 Torque off Btm = 8.5k FtLb, Torque on Btm = 9.5k FtLb BPM = 4 ~ 1430 psi on Btm, Printed: 8/23/2004 9:23:01 AM BP Exploration Page 12 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date li From - To !Hours ~I Task Code NPT Phase ', Description of Operations 7/22/2004 08:30 - 18:00 9.50 STWHIP P WEXIT P/U 195k S/O 140k ROT 168k By 1300 hrs made 3'. Started varying parameters in an attempt I to increase penetration rate. 18:00 - 19:30 1.50 STWHIP N DFAL WEXIT 19:30-00:00 4.50 STWHIP N DFAL WEXIT 7/23/2004 00:00 - 03:00 3.00 STWHIP N DFAL WEXIT 03:00 - 03:30 0.50 STWHIP N DFAL WEXIT 03:30 - 05:00 1..50 STWHIP N DFAL WEXIT 05:00-06:00 1.00 STWHIP N DFAL WEXIT 06:00 - 06:30 0.50 FISH N DFAL WEXIT 06:30 - 07:00 0.50 FISH N DFAL WEXIT 07:00 - 09:30 2.50 FISH N DFAL WEXIT 09:30 - 10:00 0.50 FISH N DFAL WEXIT 10:00 - 16:00 6.00 FISH N DFAL WEXIT 16:00 - 17:00 I 1.001 FISH I N I DFAL I W EXIT 17:00 - 17:30 I 0.501 FISH I N I DFAL W EXIT WOM 10-12 klbs RPM = 100 Torque = 9.5k FtLb BPM = 3 C~ 1100 psi WOM 15-25 klbs RPM = 140 Torque = 7.5k FtLbs BPM = 0 Still unable to make any footage, conferred with town drilling staff and the decision was made to POH with the milling assembly. POH to 5' above top of whipstock. Drop dart to open circ sub. CBU, 13 BPM ~ 2800 psi POH with milling assembly. Midnight depth: 6976' Continue POH with milling assembly. PJSM with BOT, Sperry and all rig personnel on laying down BHA #22, milling assembly. Change out tongs and elevators. LD BHA #22. Clean and clear rig floor. 2-7/8" PAC X 2-3/8" IF crossover parted at the pin leaving both mills in the hole, total length 5.77'. Top of fish @ 14633.2' Clear and clean rig floor. PJSM with BOT and all rig personnel on making up fishing BHA. Bring fishing BHA to rig floor. MU BHA #23, fishing assembly a 4-11/16" overshot with 3-1/8" grapple Rig service. RIH to 14309' with overshot assembly on 4" DP. Fill DP and break circulation every 35 stands. MU top drive and wash down from 14309' to 14630'. P/U 195k S/O 138k 2 bpm ~ 600 psi RIH to 14633'. Stack 15k on fish with 100 psi increase in pump pressure. PU with 30k overpull, fish engaged. Work drillstring from 120k to 250k 6 bpm ~ 1500 psi. Start jarring at 225k, PU 40K ove, continue increasing jar Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Page 13 of 24 Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 7/23/2004 17:00 - 17:30 0.50 FISH N DFAL WEXIT weight by 5k until fish came free after jarring at 250k and pickuing up to 290K. P/U 198k S/O 140k 17:30 - 00:00 6.50 FISH N DFAL WEXIT POH with overshot and fish. 7/24/2004 00:00 - 01:00 1.00 FISH N DFAL WEXIT 01:00 - 03:00 2.00 FISH N DFAL I WEXIT 03:00 - 03:30 0.50 FISH N DFAL WEXIT 03:30 - 04:00 0.50 STWHIP N DFAL WEXIT 04:00 - 05:30 I 1.501 STWHIPI N I DFAL I WEXIT 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT 07:00 - 08:00 1.00 STWHIP N DFAL WEXIT 08:00 - 13:00 5.00 STWHIP N DFAL WEXIT 13:00 - 14:00 1.00 STWHIP N DFAL WEXIT 14:00 - 00:00 10.001 STWHIPI P 7/25/2004 ~ 00:00 - 01:30 I 1.50 I ST W H I P ~ P 01:30 - 02:00 I 0.501 STWHIPI P 02:00 - 03:00 I 1.001 STWHIPI P WEXIT WEXIT Midnight depth: 1300' Continue POH with overshot and fish. LD BHA #23. Recovered: starter mill and string mill, total length 5.77' Clean and clear rig floor. PJSM with BOT, Sperry and all rig personnel on picking up and running milling BHA. PU and MU window milling BHA #23, with HTC high speed diamond mill and 3-5/8" SperryDrill 0.0 degree motor. RIH with mills, breaking circulation every 35 stands. PJSM. Cut and slip drilling line RIH with milts to 14329, breaking circulation every 35 stands MU top drive and wash down from 14329' to 14632'. P/U 205k S/O 137k 3 bpm @ 1000 psi Mill window from 14636' to 14647'. WOM = 4-7 klbs RPM Surf= 50, DH = 255 Torque on Btm = 6k-Sk FtLb BPM = 3.6 C~3 1550 psi on Btm, P/U 205k S/O 138k ROT 168k Continue milling window and from 14647' to 14648'. Drill new hole to 14662' for FIT. Recovered 6 Ibs metal cuttings with the consistency of steel wool. WOM = 4-5 klbs RPM Surf= 40, DH = 245 Torque on Btm = 7k-8k FtLb BPM = 3.6 @ 1650 psi on Btm, P/U 205k S/O 138k ROT 168k TOW - 14636' BOW - 14648' WEXIT Work through window while circulating 100 bbls, 3.8 BPM C~3 1350 psi, to clean up new hole and 5-1/2" liner. WEXIT ~ Pull mills above whipstock and perform 10.0 ppg EMW FIT: TMD = 14642' TVD = 8755' MW = 8.45 PP9 Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Contractor Name: DOYON Rig Name: DOYON 16 Date From - To Hours ' Task !Code ! NPT 7/25/2004 02:00 - 03:00 1.00 STWHIP P 03:00 - 04:30 1.50 STWHIP P 04:30 - 05:00 0.50 STWHIP P 05:00 - 08:00 3.00 STWHIP P 08:00 - 10:00 2.00 STWHIP P 10:00-10:30 0.50 STWHIP P 10:30-16:30 6.00 STWHIP P 16:30-19:00 2.50 STWHIP P 19:00 - 19:30 0.50 STWHIP P 19:30 - 20:00 0.50 STWHIP P 20:00 - 20:30 0.50 STWH-P P 20:30 - 00:00 7!26/2004 00:00 - 00:30 00:30 - 06:30 3.50 STWHIP P 0.50 STWHIP P 6.00 STWHIP P 06:30 - 12:30 12:30 - 13:00 13:00 - 00:00 6.00 STWHIP P 0.50 STWHIP P 11.001 DRILL I P Page 14 of 24 Spud Date: Start: 7/2/2004 End: Rig Release: 8/18/2004 Rig Number: i Phase Description of Operations WEXIT Surf press = 705 psi WEXIT Drop dart and pump open circ sub at 3.6 bpm. Circulate to clean hole, 12 BPM @ 3420 psi. WEXIT POH, placing circ sub at 5-1/2" liner top. WEXIT Pump and circulate around 40 bbl hi-vis sweep, 12 bpm Q 3450 psi. CBU X 3 WEXIT Pump and circulate around 20 bbl Super Lift sweep, 11 bpm 3300 psi. Total metal cuttings recovered = 6 Ibs WEXIT Monitor well -Static. Blow down top drive. WEXIT POH with milling assembly. WEXIT Monitor well -static. LD Milling BHA. WEXIT Clean and clear rig floor. MU ported sub and flush BOP stack. WEXIT Rig service. WEXIT PJSM with Sperry and all rig personnel on picking up and running directional BHA. WEXIT PU and MU BHA #25, directional assembly. WEXIT Shallow test MWD tools. WEXIT RIH with directional BHA picking up 102 joints of 2-7/8" SWDP from pipe shed. Fill DP and test MWD after picking up 50 joints. WEXIT Continue RIH with BHA #24 on 4" DP. Break circulation and check MWD every 35 stands. WEXIT Orient tool to 40L and RIH with no rotation or pump to 14660. P/U 190k S/O 137k ROT 165k PROD1 Directional drill 4-3/4" production hole from 14662' to 14810'. Sliding 100% to build angle. WOB = 8-10 klbs RPM Surf= 0, DH = 204 GPM = 150 C~3 2150 psi on Btm, 2000 psi off Btm P/U 190k S/O 137k ROT 165k Ream through tight spot 14785', circulate 20 bbl hi-vis sweep around while reaming. 7/27/2004 i 00:00 - 06:00 6.00 i DRILL P AST last 24 hrs. = 9.25 hrs. ART last 24 hrs. = 0.00 hrs. PROD1 Directional drill 4-3/4" production hole from 14810' to 14913'. Sliding 100% to build angle. WOB = 5-10 klbs RPM Surf = 0, DH = 204 GPM = 150 ~ 2400 psi on Btm, 2200 psi off Btm P/U 195k S/O i40k ROT 165k 06:00 - 08:00 I 2.001 DRILL I N I DPRB I PRODi Unable to build angle required for well plan. After the surveys were corrected it was determined that there was an unknown tool face offset error, the tool face was 60-90 degrees left of scribe. POH to above window at 14629' and circulate, 143 gpm Printed: 8!23!2004 9:2301 AM BP Exploration Page 15 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To~; W-09 W-09 REENTE DOYON DOYON Hours ' R+COM 16 Task ~ PLET Code '. E NPT '~ Start Rig Rig Phase ~ Spud Date: : 7/2/2004 End: Release: 8/18/2004 Number: Description of Operations 7/27/2004 06:00 - 08:00 2.00 DRILL N DPRB PRODi 2050 psi. Confer with town drilling and geology teams, it was determined to POH and pick up a 1.83 degree motor, and revise the directional plan allowing the well to be landed approximately 40' lower TVD. 08:00 - 09:30 1.50 DRILL N DPRB PROD1 POH placing the circ sub at the 5-1/2" liner top. Drop dart and pump circ sub open with 4300 psi. 09:30 - 12:00 2.50 DRILL N DPRB PROD1 Circulate hi-vis sweep around, 420 gpm @ 3600 psi and 40 rpm 12:00 - 12:30 0.50 DRILL N DPRB PROD1 Monitor well -static 12:30 - 17:00 4.50 DRILL N DPRB PROD1 POH to 3320' racking back 4" DP. 17:00 - 20:30 3.50 DRILL N DPRB PROD1 Monitor well -static. Continue POH racking back 2-7/8" SWDP 20:30 - 22:30 2.00 DRILL N DPRB PROD1 LD BHA #25. Download MWD tools. Offset shifted. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 MU BHA #26. PU 1.83 degree motor and a 4-3/4" Smith MDT2850YPX bit. Orient and scribe MWD. 7/28/2004 00:00 - 01:00 1.00 DRILL N DPRB PROD1 MU 1 jt of 2-2/8" SWDP and shallow test MWD. 01:00 - 03:30 2.50 DRILL N DPRB PROD1 RIH with 2-7/8" SWDP, break circulation every 35 stands and test MWD. 03:30 - 07:30 4.00 DRILL N DPRB PRODi Continue RIH to 10029' with 4" DP, break circulation every 35 stands and test MWD. 07:30 - 08:00 0.50 DRILL N DPRB PROD1 Rig service. 08:00 - 10:30 2.50 DRILL N DPRB PRODi Continue RIH to with 4" DP, break circulation every 35 stands and test MWD. 10:30 - 00:00 13.50 DRILL P PROD1 Directional drill 4-3/4" production hole from 14913' to 15192', sliding as required. WOB = 8-12 klbs RPM Surf= 45, DH = 204 GPM = 150 ~ 2400 psi on Btm, 2020 psi off Btm P/U 195k S/O 140k ROT 170k Backream each stand and take 30' surveys. Pump sweeps around every 200' or as required to clean hole. AST last 24 hrs. = 8.97 hrs. ART last 24 hrs. = 0.78 hrs. 7/29/2004 00:00 - 00:00 24.00 DRILL P PRODi Directional drill 4-3/4" production hole from 15192' to 15730', sliding as required. WOB = 10-20 klbs ~ RPM Surf= 45, DH = 204 GPM = 155 C~ 2300 psi on Btm, 2040 psi off Btm P/U 207k S/O 130k ROT 167k Backream each stand and take 30' surveys. Pump sweeps around every 200' or as required to clean hole. AST last 24 hrs. = 16.40 hrs. ART last 24 hrs. = 2.17 hrs. 7/30/2004 00:00 - 21:00 21.00 DRILL P PROD1 Directional drill 4-3/4" production hole from 15730' to 16323', sliding as required. WOB = 7-20 klbs Printed: 8/23/2004 9:23:01 AM BP Exploration Page 16 of 24 Operations Summary Report Legal Well Name: - W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 7/30/2004 00:00 - 21:00 21.00 DRILL P PROD1 RPM Surf= 45, DH = 210 GPM = 156 @ 2300 psi on Btm, 2160 psi off Btm Torque 9.7k FtLbs on Btm, 9.Ok FtLbs off Btm P/U 215k S/O 127k ROT 167k Backream each stand and take 30' surveys. Pump sweeps around every 200' or as required to clean hole. ROP dropped off at 16320', decision made to trip for bit. 21:00 - 00:00 3.00 DRILL N DFAL PROD1 Circulate 20 bbl weighted, hi-vis sweep out of hole, 165 gpm 2500 psi. Moderate returns with sweep. 7/31/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD1 Continue circulating 20 bbl weighted, hi-vis sweep surface to surface, 165 gpm @ 2500 psi. Moderate returns with sweep. 00:30 - 00:45 0.25 DRILL N DFAL PROD1 Monitor well -static 00:45 - 01:30 0.75 DRILL N DFAL PRODi POH placing the circ sub at the 5-1/2" liner top. 01:30 - 04:30 3.00 DRILL N DFAL PRODi Drop dart and pump circ sub open. Circulate at max rate of 420 gpm C~3 3310 psi. Circulate hi-vis sweep surface to surface. 04:30 - 05:00 0.50 DRILL N DFAL PROD1 Monitor well -static. POH, 5 stands to 14,000 05:00 - 06:00 1.00 DRILL N DFAL PROD1 Cut and slip 107' of drill line. 06:00 - 11:30 5.50 DRILL N DFAL PRODi Slug DP and POH to SWDP at 3400' 11:30 - 12:00 0.50 DRILL N DFAL PROD1 Rig up double stack power tongs for 2-7/8" SWDP. 12:00 - 14:00 2.00 DRILL N DFAL PROD1 POH standing back 2-7/8" SWDP. 14:00 - 16:00 2.00 DRILL N DFAL PROD1 LD BHA #26. Down load MWD. Mud motor parted, leaving bit and -0.5' of the shaft in the hole 16:00 - 16:30 0.50 BOPSU P PRODi Pull wear bushing and install test plug. 16:30 - 20:30 4.00 BOPSU P PRODi Test ROPE to 3500 psi/250 psi, test annular to 2500 psi/250 psi Witness of BOP test waived by Chuck Scheve with AOGCC. 20:30 - 21:00 0.50 BOPSU P PROD1 Pull test plug. Install wear bushing. RD test equipment. 21:00 - 21:30 0.50 DRILL P PROD1 Rig Service 21:30 - 00:00 2.50 DRILL N DFAL PROD1 PU BHA #27, 1.5 degree motor and Smith PDC bit. Upload MWD 8/1/2004 00:00 - 01:00 1.00 DRILL N DFAL PROD1 MU 1 stand of SWDP and shallow test MWD. 01:00 - 03:30 2.50 DRILL N DFAL PROD1 RIH with SWDP. Fill DP every 35 stands and test MWD. RD 2-7/8" tongs. 03:30 - 10:00 6.50 DRILL N DFAL PROD1 Continue RIH to 12520' with 4' DP. Fill DP every 35 stands and test MWD. 10:00 - 12:30 2.50 DRILL N DFAL PROD1 Wash down from 15630' to 16080'. Packing off, worked through tight spot from 15630' to 15740'. Pull 40k over on PU. Work through until no problems. 12:30 - 13:30 1.00 STKOH N DFAL PRODi Orient tool low side and trench from 16035' to 16080'. 13:30 - 17:00 3.50 STKOH N DFAL PROD1 Time drill, 1 "/min, from 16080' to 16100'. WOB = 0 klbs RPM Surf= 0, DH = 207 GPM = 156 ~ 2400 psi on Btm, 2400 psi off Btm P/U 215k S/O 130k Did not pick up differential pressure or WOB. Unable to kickoff at 16100' 17:00 - 19:00 2.00 STKOH N DFAL PROD1 POH and trench from 16069' to 16100'. 19:00 - 00:00 5.00 STKOH N DFAL PROD1 Time drill, 1 "/min, from 16100' to 16117' WOB = 0-4 klbs Printed: 8!23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Start: 7/2/2004 Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date I From - To Hours Task Code I'~ NPT ', Phase - - --_ ~_ - 8/1/2004 19:00 - 00:00 5.00 STKOH ~ N ~ DFAL ~ PROD1 8/2/2004 100:00 - 00:45 0.751 STKOH N I DFAL PROD1 00:45 - 01:00 0.25 STKOH N DFAL PROD1 01:00 - 02:00 1.00 STKOH N DFAL PROD1 02:00 - 14:00 12.00 STKOH N DFAL PROD1 14:00 - 15:00 1.00 STKOH N DFAL PROD1 15:00 - 18:00 3.00 STKOH N DFAL PROD1 18:00 - 00:00 6.00 STKOH N DFAL PROD1 8/3/2004 00:00 - 00:30 0.50 STKOH `N DFAL PROD1 00:30 -04:30 4.00 STKOH I N DFAL PROD1 04:30 - 04:45 I 0.251 STKOH I N 04:45 - 11:00 6.25 STKOH N 11:00 - 12:00 1.00 STKOH N 12:00 - 13:30 1.50 STKOH N 13:30 - 14:30 1.00 STKOH N 14:30 - 16:00 1.50 STKOH N 16:00 - 17:30 1.50 STKOH N 17:30 - 19:30 2.00 STKOH N 19:30 - 00:00 4.50 STKOH N 8/4!2004 00:00 - 01:30 I 1.501 STKOH N 01:30 - 02:00 0.50 STKOH N 02:00 - 06:00 4.00 STKOH N 06:00 - 12:00 6.00 STKOH N 12:00 - 13:00 1.00 STKOH N 13:00 - 15:00 2.00 STKOH N 15:00 - 18:00 3.00 STKOH N DFAL I PROD1 DFAL PROD1 DFAL PROD1 DFAL PRODi DFAL PROD1 DFAL PRODi DFAL PRODi DFAL PROD1 DFAL PROD1 DFAL PRODi DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PRODi DFAL PROD1 DFAL PROD1 Page 17 of 24 Spud Date: End: Description of Operations RPM Surf= 0, DH = 207 GPM = 156 ~ 2460 psi on Btm, 2410 psi off Btm P/U 215k S/O 130k Continue time drilling from 16117' to 16135'. Picked up 0-100 psi differential pressure and -8k WOB. WOB = 0-8 klbs RPM Surf= 0, DH = 207 GPM = 156 @ 2550 psi on Btm, 2460 psi off Btm P/U 215k S/O 130k Shut down pumps PU and RIH trying to find new hole. Still unable to sidetrack. Orient tool low side and trench from 16095' to 16116' Time drill from 16116 to 16167'. 1-1/2 min per inch for the first 2', 1 min per inch to 16167'. Shut down pumps PU and RIH trying to find new hole. Still unable to sidetrack. POH to 16120'. Orient tool low side and trench from 16020' to 16080' Trench from 16075' to 16120'. Adjusted depths after conferring with Anchorage drilling staff. P/U 210k S/O 130k Cont troughing f/i 6,075' - 16,120' Time drilling from 16120' to 16130'. 2 minutes per inch for the first 2', !min per inch to 16130'. WOB = 0-8 klbs RPM Surf= 0, DH = 160 GPM = 118 @ 1790 psi on Btm, 1710 psi off Btm P/U 210k S/O 130k Shut down pumps PU and RIH trying to find new hole. Still unable to sidetrack. Flow CK wel{, POOH t/3320' RU 2 7/8" equip. POOH SW DP t/2900' POOH w/2 7/8" DP Handle BHA, DN Motor & bit PU motor & bit. Orient, download/upload MWD. MU BHA. Lay down pony collar. MU BHA. Shallow test MWD. RIH w/2 7/8" SWDP. Fill pipe & check MWD. RIH filling pipe & checking MWD every 35 stands. UP - 185K DN - i25K RIH (/13,369' to 16,053'. No problems going through liner top or window (tight spot at 15,222' /worked through w/o pumps). Orient MWD for "troughing" work Trenching for open-hole sidetrack f/16,090'-16,130' (148 gpm) Time drilling (/16,130' - 16,149' PU 215K S/O 130K Time drill f/16,149' to 16,152'. Attempt to find bridge. RIH to 16,247'. No bridge. Pull up to 15,710'. Attempt to trough. Hole tight 0315,728' to 15,730'. Packing off. Clean hole. Trough from 15,710' to 15,745'. Printed: 8/23/2004 9:23:01 AM BP Exploration Page 18 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: i Date From - To Hours Task Code NPT Phase I .Description of Operations 8/4/2004 18:00 - 00:00 6.00 STKOH N DFAL PROD1 Time drill from 15,745' to 15,756' TMD (TVD - 8888'). 8/5/2004 00:00 - 01:45 1.75 STKOH N DFAL PROD1 Continue to time drill f/15,756' to 15,767'. 01:45 - 02:30 0.751 STKOH N DFAL PRODi Drilling f/15,767' to 15,798' 02:30 -04:00 1.50 STKOH N DFAL PROD1 04:00 - 11:00 7.00 STKOH N DFAL PROD1 11:00 - 12:00 1.00 STKOH N DFAL PROD1 12:00 - 13:30 1.50 STKOH N DFAL PROD1 13:30 - 14:30 1.00 STKOH N DFAL PROD1 14:30 - 17:00 2.50 STKOH N DFAL PRODi 17:00 - 19:00 2.00 STKOH N DFAL PRODi 19:00 - 20:00 1.00 STKOH N DFAL PROD1 20:00 - 20:30 0.50 STKOH N DFAL PROD1 20:30 - 00:00 3.50 STKOH N DFAL PRODi 8/6/2004 00:00 - 02:30 2.50 STKOH N DFAL PROD1 02:30 - 03:00 0.50 STKOH N DFAL PRODi 03:00 - 12:00 9.00 i STKOH N DFAL PROD1 12:00 - 22:30 10.50 STKOH N DFAL PROD1 22:30 - 00:00 1.50 STKOH P PROD1 8/7/2004 100:00 - 12:00 12.00 ~ STKOH P 12:00 - 00:00 I 12.001 STKOH I P PU Wt 215k SO Wt 130k AST= .75 hrs ADT= .75 hrs Take survey to verify inclination (confirmed KO @ 15,760'). Work pipe through sidetracked section - OK. Flow check well. POOH to SWDP (3304'). Continue to POOH. Stand-back 2 7/8" SWDP. PJSM. POOH w/2 7/8" SWDP. Handle BHA. Break bit. Lay down motor. Function rams. PU motor & pony collar. MU bit. Orient down-load/upload MWD. MU BHA. Shallow test MWD. RIH w/2 7/8" SWDP. Fill pipe test MWD. PJSM & cut drilling line. Calibrate depth control f/MWD. Check flow. RIH. Fill pipe. Check MWD every 35 sands. Up-150K Down-100K RIH f/10,605' to 15,588'. Fill each 35 stands, check MWD. Orient into new hole (/15749 to 15,798'. Drilling ahead f/15,799' to 16,100'. AST 3.69 ART 2.75 ADT 6.44 Continued drilling to 16,323' (end Trouble Time). Continued drilling f/16,323' to 16,351'. AST 6.13 ART .7 ADT 6.83 PROD1 Directionally drilled f/16,351' to 16,642' TMD. AST = 4.24 ART = 4.27 ADT = 851 PRODi Directionally drilled f/16,642' to 17,070' TMD. (Up Wt = 185K / Dn Wt = 140K ! Rt Wt = 166K) AST = 4.84 ART = 3.91 ADT = 8.75 Total bit time = 30.53 Printed: 8/23/2004 9:23:01 AM BP Exploration Page 19 of 24 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To II W-09 W-09 REENTE DOYON DOYON Hours ' R+COM 16 Task PLET Code'; E NPT Start Rig Rig Phase Spud Date: : 7/2/2004 End: Release: 8/18/2004 Number: Description of Operations 8/7/2004 12:00 - 00:00 12.00 STKOH P PROD1 Jar #15051023 = 102.79 8/8/2004 00:00 - 11:00 11.00 STKOH P PROD1 -Drill directional in 4 3/4" hole from 17,070' to 17,501' MD. - Final survey @ 17456' MD, 8993' TVD, Incl 74.06 deg, Az 312.98. AST 4.33 hrs ART 3.29 hrs ADT 7.62 hrs 11:00 - 14:00 3.00 STKOH P PROD1 - POH from 17501' to 14629'. - Dry wipe tight spots from 17285' to 17245', 17090', 16323', & from 15860' to 15820'. Max overpull of 40K. 14:00 - 14:30 0.50 STKOH P PROD1 -Clear & clean rig floor. - PJSM 14:30 - 16:00 1.50 STKOH P PRODi -Slip & cut drilling line. 16:00 - 17:00 1.00 STKOH P PROD1 -Lubricate rig - Sevice TD & drawworks. 17:00 - 20:30 3.50 STKOH P PRODi -RIH from 14629' to 17501'. - Wash & ream tight spots 15423' to 15493', & 16410' to 16769' ~ 3.5 BPM 2200 psi, 40 RPM's 20:30 - 00:00 3.50 STKOH P PRODi -Pump 40 bbl hi-vis sweep @ 3.5 BPM 2700 psi, 40 RPM's & reciprocating. 8/9/2004 00:00 - 02:00 2.00 STKOH P PROD1 -Continue circulating hi-vis sweep. Sweep brought back 20% excess sand. Circulate additional 1/4 B/U until shakers cleaned up. 02:00 - 03:00 1.00 STKOH P PROD1 -Pump & spot liner running pill w/ 18 gal beads, 2 sx flo vis, 3 sx nut plug, & 1 drum lubetex. 03:00 - 05:00 2.00 STKOH P PROD1 - POH from 17501' to 14534'. Hole slick & appears to be in good condition. 05:00 - 08:00 3.00 STKOH P PROD1 -Drop dart & open circulating sub. - Pump 40 bbl hi-vis sweep @ 10 BPM 3670 psi. 08:00 - 15:00 7.00 STKOH P PROD1 -Drop rabbit & POH w! 4" DP from 14534' to 3317'. 15:00 - 19:30 4.50 STKOH P PROD1 - C/O to 2 7/8" handling equip't. - Monitor well -static. -POH&L/D27/8"DP1 xi. 19:30 - 21:00 1.50 STKOH P PROD1 - UD BHA & download MWD. 21:00 - 22:00 1.00 STKOH P PROD1 -Clear & clean rig floor. 22:00 - 23:00 1.00 CASE P PROD1 -PJSM - R/U 3 1/2" tubing handling equip't. 23:00 - 00:00 1.00 CASE P PROD1 -PJSM -Run 3 jts 3 1/2" 9.2# L-80 IBT-M tubing. M/U Tq 2300 ft/Ibs. - Fill pipe & check floats -okay. 8/10/2004 00:00 - 06:00 6.00 CASE P PROD1 Continue running 3 1/2" 9.2# L-80 IBT-M liner. Total 3,255 ft. 106 jts 06:00 - 06:30 0.50 CASE P PROD1 MU 7" x 9 5/8" Flex Lock hanger and ZXP pkr assy. 06:30 - 14:00 7.50 CASE P PROD1 Con't RIH w/ 3 1/2" liner on 4" DP from derrick at controlled running speeds. 14:00 - 15:00 1.00 CASE N RREP PROD1 Repair hyd fitting on TDS 15:00 - 16:00 1.00 CASE P PROD1 Con't RIH w/ 3 1/2" liner to 14,322 ft at controlled running speeds. 16:00 - 16:30 0.50 CASE P PRODi Circ 1.5 x liner volume. 4 BPM ~ 1020 psi 16:30 - 17:00 0.50 CASE P PRODi MU cmt head. Hang same in derrick 17:00 - 18:00 1.00 CASE P PRODi Con't run w/ 3 1/2" liner in open hole to 15,478 ft. 18:00 - 00:00 6.00 CASE P PROD1 Wash down 3 1/2" liner 15,478 ft to TD C~3 17,501 ft 8/11/2004 ~ 00:00 - 00:30 0.50 CASE P PROD1 - MU cmt head out of derrick. Printed: 8/23/2004 9:23:01 AM BP Exploration Page 20 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start: 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date 'From - To Hours '~ Task ;Code ~~~ NPT Phase ; Description of Operations __ ~- 8/11/2004 00:00 - 00:30 0.50 CASE P PROD1 00:30 - 01:30 1.00 CASE P PROD1 - Circ 3 1/2" Liner & reciprocate same. - P/W 190k - S/W 120k - Stage up pump - ICP 1 BPM 750 psi, FCP 4.5 BPM 1970 psi. 01:30 - 03:00 1.50 CEMT P PROD1 -PJSM w/ cementers & rig crew. - Continue circulating & reciprocating C~ 4.5 BPM 1900 psi while cementers batched up slurry. 03:00 - 05:00 2.00 CEMT P PROD1 -Pump 5 bbis water & test lines to 4500 psi. - Pump 15 bbls CW 100, 25 bbls 9.5 ppg spacer followed by 68 bbls 15.8 ppg latex cement. - Wash line & drop plug. Chase plug w/42 bbls pert pill. Switch over to rig pump & bump plug w/ 135 bbls mud, 3500 psi. - Set 35K on hanger to ensure set -bleed off pressure & check floats -floats holding. 05:00 - 06:00 1.00 CASE P PRODi -Work 14 RH turns in string & pressure up to 1000 psi. - P/U on string & kick on pump once pressure started decreasing. Pump 50 bbls @ 9 BPM 2000 psi. - Slow pump to 2 BPM & set packer. Slack off 70K x 2 to set packer -packer did not shear. Rotate string & slack off 45K & observed indication of shear. Repeat sequence to ensure packer set. 06:00 - 07:00 1.00 CASE P PROD1 - CBU & 10 BPM 2000 psi. Divert 60 bbls to slop tank. Approx 5 bbls cement returned. 07:00 - 07:30 0.50 CASE P PROD1 - R/D & UD cement head & lines. 07:30 - 10:30 3.00 CASE P PROD1 -Displace well to S/W C~3 5.5 to 7 BPM 1000 psi 30 RPM. Displacing by feeding mud pump via tiger tank - 7 BPM max rate. 10:30 - 13:00 2.50 CASE P PROD1 - POH from 17501' to 10000'. 13:00 - 13:30 0.50 CASE P PROD1 -Serviced Rig 13:30 - 18:30 5.00 CASE P PROD1 - POH from 10000' to liner hanger running tool. 18:30 - 19:00 0.50 CASE P PRODi -Make service breaks & UD liner hanger running tool. - Dog sub sheared. 19:00 - 19:30 0.50 CASE P PROD1 -Clear & clean floor. 19:30 - 20:30 1.00 CASE P PRODi -Close blind rams, pressure tested 9 5/8" casing x 3 1/2" liner to 3,500 psi f/ 30 min. - Bled down pressure, Open rams, B/D kill line. 20:30 - 21:30 1.00 CASE P PRODi -PJSM w/ Schlumb & rig crew for R/U & handling pert guns. - R/U to run pert guns. 21:30 - 00:00 2.50 CASE P PROD1 - M/U &RIH w/ 2" pert guns & 2 1/16" CS Hy DP to 916'. 8/12/2004 00:00 - 04:30 4.50 CASE P PROD1 -Continue RIH w/ 2" pert guns #35 through #84 & 37 jts 2 1/16" CS Hy DP. - R/D 2 1/16" handling tools & R/U 4" tools. - RIH w/ first stand 4" DP. 04:30 - 06:00 1.50 CASE P PROD1 -Slip & cut drilling line. 06:00 - 10:30 4.50 CASE P PRODi -Continue RIH w/ 2" pert guns on 4" DP to 14235'. - P/U wt 165K, S/O wt 120K. - Tagged up C~? 14235'. 10:30 - 12:00 1.50 CASE P PRODi -Attempt to work through tight spot C~ 14235' with & without rotation w/o success. Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date i From - To W-09 W-09 REENTER+COMPLETE DOYON DOYON 16 Hours ! Task I Code I 8/12/2004 10:30 - 12:00 1.50 CASE P 12:00 - 17:00 5.00 CASE N 17:00 - 17:30 0.50 CASE N 17:30 - 00:00 6.50 CASE N Start: 7/2/2004 Rig Release: 8/18/2004 Rig Number: NPT I Phase PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 8/13/2004 00:00 - 00:30 0.50 CASE ~N DPRB PROD1 00:30 - 01:00 0.50 BOPSU P PROD1 01:00 - 03:30 2.50 BOPSU P PROD1 03:30 - 04:00 0.50 BOPSU P PROD1 04:00 - 05:00 1.00 CASE N DPRB PROD1 05:00 - 11:30 6.50 CASE N DPRB PROD1 11:30 - 12:00 0.50 CASE N DPRB PRODi 12:00 - 17:30 5.50 CASE N DPRB PROD1 17:30 - 18:00 0.50 CEMT N DPRB PROD1 18:00 - 00:00 I 6.001 CEMT I N I DPRB I PROD1 8/14/2004 ~ 00:00 - 07:00 07:00 - 10:00 10:00 - 16:00 16:00 - 17:00 17:00 - 00:00 8/15/2004 00:00 - 03:00 03:00 -04:30 7.00 ~ CEMT I N ~ DPRB ~ PRODi Page 21 of 24 Spud Date: End: Description of Operations - 5 RPM & 10K max wt stacked on guns. - POH w/ 2" pert guns on 4" x 2 1/16" DP from 14235' to 3328'. - C/O to 2 1/16" handling equip't. - POH w/ 4" DP, 2 1/16" DP, & 76 of 84 2" pert guns. UD 2 1/16" DP & 2" pert guns. - First 11 jts of 2 1/16" CS Hy DP below 4" DP bent. - First 10 pert guns below 2 1/16" CS Hy DP w/ bent or missing capsule rings. - Sent 13 guns back to Schlumberger for charge realignment & adaptor inspection. - Total of 6 capsule rings & 2 retainer rings left in hole. - POH & UD 8 2" pert guns. - Pull bowl protector -install test plug - R/U test equip't. - Test BOPE per BP & AOGCC Regs to 250 psi / 3500 psi for 5 / 5 min. Witness of BOP test waived by AOGCC Rep Jeff Jones. - R/D test equip't -pull test plug -install bowl protector. - Bring 2 3/4" BHA components to rig floor & strap same. - M/U &RIH w/ 2 3/4" BHA. - R/D 2 1/16" handling equip't & R/U 4" handling equip't. - Break circ ~ 10SPM 540 psi. - RIH w/ clean out assy on 4" DP to 14194'. - Establish milling parameters as follows: - W/O pump - P/U wt 162K S/O wt 115K - W/pump C~3 1 BPM 790 psi P/U wt 164K S/O wt 120K. -Tag cement @ 14232' & made no progress for 2.5 hrs. Motor stalled several times - 2.5K max wt on bit - 1 BPM 800 psi. - Mill cement from 14232' to 14241' in 1.5 hrs w/ same drilling parameters as above. - Mill cement from 14241' to 14245' in 2 hrs. Motor stalled several times. 3K max wt on bit - .8 BPM - 1.2 BPM, 750 psi - 1100 psi. - Continue milling cement from 14245' to 14250' w/ .8 BPM - 1.2 BPM, 750 psi to 1100 psi. No progress made for 2 hrs ~ 14249'. 3.00 CEMT N DPRB PROD1 -Continue milling cement @ 14250' -vary parameters -rotate string C~ 5 RPM , 3K ft/Ibs Tq. Vary pump rates w/ & w/o rotary .5 BPM 600 psi, 1 BPM 1000 psi, 1.7 BPM 1400 psi. No progress made. 6.00 CEMT N DPRB PROD1 -Time drill cement from 14250' to 14251'. Vary parameters & pump rates .5 BPM 600 psi, 1 BPM 1000 psi, 1.7 BPM 1400 psi. - Conferred w/ Anchorage team -decision made to run completion w/ rig and coil unit to perform clean out & perforations after rig moves off. 1.00 CEMT N DPRB PROD1 -Drop ball & open upper circ sub -monitor well -pump dry job. 7.00 CEMT N DPRB PROD1 - POH & UD 4" DP 1 x 1. - Check hardbanding on DP while POH & separate same after UD. Will send to API for hardbanding. 3.00 CASE N DPRB PROD1 -Continue POH w/ 4" DP & UD 1 x 1. 1.50 CASE N DPRB PROD1 -RIH w/ 37 stands 4" DP trom derrick for UD. Printed: 8/23/2004 9:23:01 AM BP Exploration Operations Summary Report Legal WeII Name: W-09 Common Well Name: W-09 Event Name: REENTER+COMPLETE Start: 7/2/2004 Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date ~ From - To 'i Hours Task Code ~ -- --_ 8/15/2004 04:30 - 08:30 4.00 CASE N 08:30 - 09:00 0.50 CASE N 09:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 17:00 17:00 - 22:30 22:30 - 23:00 23:00 - 00:00 8/16/2004 00:00 - 00:30 00:30 - 01:30 Page 22 of 24 Spud Date: End: NPT Phase. ' Description of Operations DPRB PRODi -Continue POH w/ 4" DP & UD 1 x 1. DPRB PRODi - B/O x-overs & C/O from 4" handling equip't to 2 1/16" handling equip't. 4.50 ~ CASE N DPRB PROD1 - POH w/ 110 jts 2 1/16" DP & L/D 1 x 1. 0.50 CASE N DPRB PROD1 - B/O & L/D BHA. - Diamond speed mill showed wear on gauge area. Original OD was 2.8" - 2.75" after milling ops. 0.50 CASE P PRODi -Clear tools & clean rig floor. 0.50 CASE P PROD1 -Service TD, drawworks, & crown. 2.00 CASE P PROD1 -Remove pert guns from pipeshed. 5.50 BUNCO RUNCMP -Load pipeshed w/ completion jewelry. - C/O bails & elevators. - R/U tubing running equip't. 0.50 BO 1.00 RU 0.50 RU 1.00 RU 01:30 - 00:00 22.50 RU 8/17/2004 00:00 - 03:00 3.00 RU 03:00 - 05:30 2.50 RU 05:30 - 06:00 0.50 RU 06:00 - 12:00 6.00 I R 12:00 - 13:30 13:30 - 15:00 Note: Nordic #1 arrived on W Pad ~ 1900 hrs. RUNCMP -Continue RIH w/ 3 1/2" 9.2# 13CR80 Vam Top tubing. P/U w/ compensator & Torque Turn all connections. - M/U Tq 2950 fUlbs. RUNCMP - R/D compensator & R/U headpin w/ circ hose. - Wash down C~3 3 BPM 530 psi -did not see pressure increase ~ TOL. - Tag up inside of liner tie back sleeve. -P/U 3' RUNCMP -PJSM - - Displace well to S/W. RUNCMP Displace well with 150 bbls clean seawater followed by 720 bbls corrosion inhibited seawater. 3 bpm @ 400 psi 1.50 BUNCO RUNCMP Break out and LD 3-1/2" tbg jts #453 and #452. RD 3-1/2" tbg equip and RU 4-1/2" tbg equip. 1.50 BUNCO RUNCMP MU tbg hanger and landing joint. Land tbg 3.82' above no-go in liner tie-back sleeve. RILDS. - Note: Planned operation of running 8 1/2" gauge ring & junk basket on slick line prior to running tubing. Slick line crew & equip't was caught behind Nordic 1 rig move on W pad access road @ 13:30 hrs. Rig move delayed due to rig getting stuck in road. Discussed w/ Anchorage Team & decision made to eliminate slick line run & proceed w/ running tubing. P RUNCMP -BOLDS & pull bowl protector. P RUNCMP - R/U Torque Turn equip't for running tubing. P RUNCMP - PJSM for running tubing. P RUNCMP - M/U 3 1/2" tailpipe assy as follows: - WLEG, X nipple assy, lower X nipple assy, packer assy, upper X nipple assy, & GLM # 1 assy. - Bakerlok all connections below packer - P/U w/ compensator & Torque Turn all connections. M/U torque 2900 ft/Ibs. P RUNCMP - M/U &RIH w/ 404 jts 3 1/2" 9.2# 13CR80 Vam Top tubing. P/U w/ compensator & Torque Turn all connections. - M/U Tq - 2950 fUlbs. Printed: 8/23/2004 9:23:01 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 8/17/2004 ~ 13:30 - 15:00 15:00 - 15:30 15:30 - 18:00 18:00 - 18:30 BP Exploration Operations Summary Report W-09 W-09 REENTER+COMPLETE DOYON DOYON 16 Start: 7/2/2004 Rig Release: 8/18/2004 Rig Number: Page 23 of 24 Spud Date: End: I Hours ! Task I Code I NPT II Phase j Description of Operations 1.50 BUNCO RUNCMP Completion Equipment Set At The Following Depths: Item Length Depth W LEG / X Nipple w/ RHC Sleeve Assembly 23.27' 14,198.00' Lwr X Nipple Assembly 20.67' 14,154.06' 9-5/8" x 3-1/2" S-3 Packer Assembly 28.07' 14,125.99' Upper X Nipple Assembly 20.71' 14,105.28' #1 GLM Assembly 27.99' 14,077.29' 85 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,672.62' 11,404.67' #2 GLM Assembly 28.04' 11,376.63' 76 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,388.07' 8,988.56' #3 GLM Assembly 28.02' 8,960.54' 72 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,256.13' 6,704.41' #4 GLM Assembly 28.05' 6,676.36' 77 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,356.68' 4,319.68' #5 GLM Assembly w/ DCK Shr Valve 28.06' 4,291.62' 70 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,114.55' 2,177.07 #6 GLM Assembly 28.06' 2,149.01' 1 Jt 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 29.49' 2,119.52' X Nipple Assembly 20.72' 2,098.80' 69 Jts 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 2,029.50' 69.30' 3-1/2" 9.3# 13Cr80 Vam TOP Pup Jt 7.74' 61:56' 1 Jt 3-1/2" 9.3# 13Cr80 Vam TOP Tbg 30.08' 31.48' Tubing Hanger 8.98' 22.50' 0.50 BUNCO RUNCMP PJSM with BOT and all rig personnel on setting and testing packer. 2.50 BUNCO RUNCMP MU head pin to landing joint. test lines to 3500 psi. Set packer and test tbg to 3500 psi for 30 minutes. Bleed tbg pressure to 1500 psi. Test 9-5/8" X 3-1/2" annulus to 3500 psi for 30 minutes. Bleed tbg pressure shearing RP valve. After RP sheared bleed all pressure. 0.50 BUNCO RUNCMP Establish circulation both ways through shear valve to ensure it Printed: 8/23/2004 9:23:01 AM $P Exploration Page 24 of 24 Operations Summary Report Legal Well Name: W-09 Common Well Name: W-09 Spud Date: Event Name: REENTER+COMPLETE Start : 7/2/2004 End: Contractor Name: DOYON Rig Release: 8/18/2004 Rig Name: DOYON 16 Rig Number: Date ~i From - To !Hours '~ Task `Code NPT Phase, ~ Description of Operations 8/17/2004 18:00 - 18:30 0.50 BUNCO RUNCMP is fully sheared. 18:30 - 19:00 0.50 BUNCO RUNCMP RD head pin and landing joint. Set TWC valve and test from below to 1000 psi. 19:00 - 19:30 0.50 BOPSU P RUNCMP PJSM with all rig personnel on ND BOPE and NU tree. 19:30 - 21:30 2.00 BOPSU P RUNCMP ND riser and BOPE 21:30 - 23:30 2.00 WHSUR P WHDTRE NU tree and adapter flange. Test metal to metal seal to 5000 psi. 23:30 - 00:00 0.50 WHSUR P WHDTRE RU to test tree. 8/18/2004 00:00 - 01:00 1.00 WHSUR P WHDTRE Finish rigging up and testing tree to 5000 psi 01:00 - 01:30 0.50 WHSUR P WHDTRE RU DSM lubricator and pull TWC. RD and LD lubricator. 01:30 - 02:00 0.50 WHSUR P WHDTRE PJSM with Little Red and all rig personnel on testing lines and freeze protecting. 02:00 - 03:00 1.00 WHSUR P WHDTRE Reverse circulate 160 bbls diesel to freeze protect well. 3 bpm C~3 450 psi 03:00 -04:30 1.50 WHSUR P WHDTRE Allow well to U-tube. 04:30 - 08:00 3.50 WHSUR P WHDTRE Install BPV, test to 1000 psi from below. Secure well. RIG RELEASED @ 0800 Printed: 8/23/2004 9:23:07 AM • • Well: W-09A Accept: 07/02/04 Field: Prudhoe Bay Unit Spud: 07/26/04 API: 50-029-21947-01-00 Release: 08/18/04 Permit: 204-102 Rig: Doyon 16 POST RIG WORK 08/22/04 PULL BALL & ROD. PULL RK DGLV C~ 2111' SLM STA 6. PULL DCK VALVE IN STA# 5 ~ 4280' SLM. RAN GENERICS. 08/23/04 PULLED 3 1/2 RHC-M PLUG BODY FROM 14161' SLM. DRIFT W/ 2.74 CENT SB / SD C~ 14216' CORK TO RKB. DRILLING MUD IN SAMPLE BAILER. RDMO. 08/28/04 BLOW DOWN SHORT STRING WITH N2 ON WELL 16-16. UNABLE TO RIG UP. STAND BY FOR CRANE - REEL SWAP OPERATIONS ON NORDIC 1. 08/29/04 RIH WITH WEATHERFORD 2 3/8" PDM W/ 2.75" 5-BLADE CONCAVE MILL. DRY TAG DOWN AT 14223' CTMD. MILLED CEMENT TO 14241' CTM. UNABLE TO MAKE FURTHER PROGRESS. POOH FOR MILL SWAP. 08/30/04 START SEEING METAL IN RETURNS. POOH FOR MILL SWAP. MILL SHOWED SEVERE WEAR AROUND LEADING OUTSIDE EDGE WITH NO CENTER FACE WEAR. MILL GAUGED AT 2.63". RIH WITH 2.74" PDSM. TAG AT 14233' CTM. ATTEMPT TO MILL (CEMENT?). STALLING SAME AS RUN #1. STOP AFTER SEVERAL STALLS. PUH, CALL TOWN. DECIDE TO ABORT MILLING OPERATION. CIRCULATE BOTTOMS UP W ITH FLOPRO SWEEP. POOH. MILL SHOWED SLIGHT WEAR ON SIDES. TOOLS CAME OUT OF HOLE COVERED IN HEAVY OIL/TAR. FIRST TRIP, TOOLS CAME OUT CLEAN. RIH WITH 2" JSN. TAGGED DOWN AT 14245' CTMD. PU C~1 14240' CTMD. CIRCULATE HOLE OVER TO CLEAN FRESH WATER. POOH CIRC CLEAN WATER. FREEZE PROTECT WELL TO 3000' WITH 50/50 METH. PT WELL AT SURFACE TO 1200 PSI. LOST 61 PSI IN 10 MIN. PERFORM WEEKLY BOP TEST. RDMO. WELL READY FOR VIDEO LOG. LEAVE WELL SHUT IN. NOTIFY PAD OPERATOR OF WELL STATUS. 09/02/04 RUN DHV VIDEO LOG ON E-LINE FOR VISUAL CONFIRMATION OF OBSTRUCTION. CONFIRMED OBSTRUCTION AT 14218'. TUBING TALLY USED AS DEPTH REFERENCE. TOOLSTRING TIED INTO BOTTOM TWO X-NIPPLES AT 14163' AND 14183'. WELLBORE FLUIDS WERE TOO CLOUDY FOR GOOD VIDEO RESULTS. WELL LEFT SHUT IN, PAD OP NOTIFIED. JOB COMPLETE. 09/04/04 SECOND ATTEMPT TO RUN DHV CAMERA FOR VISUAL CONFIRMATION OF OBSTRUCTION IN WELL. CONFIRMED FOR A SECOND TIME THE OBSTRUCTION AT 14218'. TUBING TALLY USED AS DEPTH REFERENCE. TIED IN TO BOTTOM TWO X NIPPLES AT 14163' AND 14183'. FIRST DESCENT: WELL BORE DEBRIS PARTIALLY BLACKED OUT LENS BELOW FIRST MANDREL AT 2158', OBSTRUCTION ENCOUNTERED AT 4330', RETURNED TO SURFACE. SECOND DESCENT: WELL BORE DEBRIS PARTIALLY BLACKED OUT LENS BELOW FIRST MANDREL AT 2158', OBSTRUCTION ENCOUNTERED AT 2160', RETURNED TO SURFACE. THIRD DESCENT: WELL BORE DEBRIS PARTIALLY BLACKED OUT LENS BELOW FIRST MANDREL AT 2158', PASSED THROUGH OBSTRUCTIONS, DEBRIS BELOW MANDRELS AT 2158' AND 4330', TAGGED OBSTRUCTION AT 14218'. WELL LEFT SHUT IN, PAD OP NOTIFIED. RDMO. 10/24/04 RAN 3.5" X-LINE FOR DEPTH CORRECTION. LOC X-NIPPLE C~ 14103'SLM. 14114' MD. CF = 11'. CHANGE TOOL STRING OUT TO 1.25" DRIFTED W/ 1.5" CENT TO 14238' SLM (14249' MD). RAN 1.5" LIB TO 14237' SLM (14248' MD). RAN 1.75" LIB TO 14225' SLM (14236'MD). RAN 2" LIB TO 14240' SLM (14251 MD). RAN 2.3" LIB TO 14240' SLM (14251 MD). W-09A Post Rig Summary after tracking Operations Page 2 10/25/04 RAN 2.30' LIB TO 14240' SLM (14251' MD). 10/30/04 MU AND RIH W/ DHV MEMORY VIDEO CAMERA IN 2-1/2" CARRIER. 10/31 /04 RIH W/ DHV MEMORY CAMERA. TAG BTM ~ 14240' DOWN, 14234' UP. PUMP 45 BBLS METH TO CLEAN HOLE & VIDEO FROM 14215' TO 14240' CTMD. POOH. PICTURES SHOW WHAT APPEARS TO BE A PILOT HOLE AND CEMENT SHEATH OUTSIDE OF THE LINER, AS IF THE WELL WAS SIDETRACKED (BETWEEN 3 1/2" LINER AND 9 5/8" CASING) STARTING JUST BELOW THE 3-1/2" LINER TOP PACKER . RBIH W/SAME VIDEO LOG TOOL IN AN ATTEMPT TO GET PICTURES THROUGH THE NIPPLES FOR DEPTH CONTROL AND THE LINER TOP PACKER TRANSITION AREA. TAG TD ~ 14248' DN, 14243' UP WT. PUMP 72 BBLS METH TO CLEAN HOLE. VIDEO FROM 14180' TO 14238' CTMD. POOH. PICTURES INDICATE GOOD PIPE DOWN TO VICINITY OF ZXP LINER PACKER. THIS IS AS DEEP AS THE CAMERA RECORDED. BASED ON TIE-IN W ITH NIPPLES, THE CAMERA STOPPED RECORDING AT APPROX. 14207'. THESE PICTURES DID NOT OVERLAP WITH PREVIOUS CAMERA LOG, MISSING DATA FOR APPROX. 3'- 4' BETWEEN RUNS. DID NOT GET PICTURES THROUGH TRANSITION AREA AROUND THE XO TO THE 3 1/2" LINER. THE DEPTH DISCREPANCIES ON THE SECOND CAMERA RUN ARE DUE TO A COIL COMPUTER FAILURE JUST PRIOR TO THE ACTUAL PICTURE PASS. ELECTED TO RD COIL. WILL DISCUSS RUNNING REAL TIME VIDEO ON E-LINE TO LOOK AT LINER TOP AREA FOR POSSIBLE EXIT POINT/MECHANISM. JOB COMPLETE. 07/29/05 SET 3 1/2" PX PLUG BODY AND PRONG (96" OAL, 1.75 FN) AT 14,165' SLM. 08/19/05 PULLED 2.813 PX PLUG BODY AND PRONG FROM X-NIP AT 14,157' SLM. 08/21 /05 LOG PDS CALIPER FROM 14235' CTM UP AT 50' FPM, ACROSS JEWELRY TO 13500'. POOH. FREEZE PROTECT TUBING FROM 2500' WITH 22 BBLS 50/50 METHANOL. VERIFY CALIPER DATA. CORRECTED BOTTOM OF LOG WAS AT 14206'. FROM 14,206 TO THE 7" X 3/12" XO WHICH WAS AT CORRECTED DEPTH OF 14195', THREE FEET SHALLOW TO THE WELL SCHEMATIC, TO OD WAS GREATER THAN 4 1/2". CALIPER ARMS ONLY WENT TO 4 1/2". RDMO. SET 2.813 XX TTP IN X-NIP AT 14,165' SLM ,RAN 3 1/2" CK SET MIT- T TO 2000# (PASSED). 08/25/05 EQUALIZED AND PULLED 2.813 XX TTP FROM X-NIP AT 14,164' SLM. DRIFTED W/ 2.50 CENT TAG AT 14, 237' SLM, 14,256' CORK TO MD USING +19' CORK FROM LOWER X-NIP CALIPER LINER AND TBG FROM 14,223' SLM, 14,242' CORK MD TO SURFACE (GOOD DATA). 08/26/05 RAN 2.68" SCP JET CUTTER TO 14136' TO CUT TUBING 2' ABOVE S-3 PACKER. GOOD INDICATION, TBG PRESSURE DROPPED FROM 250 TO 150 PSI, IA REMAINED AT 0. BOTH SHOCK SUBS AND CENTRALIZERS WERE RECOVERED. TAGGED OBSTRUCTION AT 14225'. TIED-INTO TUBING TALLY DATED 7-2-04. DEFINITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA W Pad W-09A Job No. AKZZ3126704, Surveyed: 8 Augusf, 2004 Survey Report 26 August, 2004 Your Ref: AP1500292194701 Surface Coordinates: 5958820.04 N, 612049.08E (70° 17' 47.1870" N, 149° 05' 33.5688" IAA Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative fo Project H Reference: 958820.04 N, 112049.08E (Grid) Surface Coordinates relative to Structure Reference :1593.87 N, 2157.68 E (True) Kelly Bushing Elevation: 78.66ft above Mean Sea Level Kelly Bushing Elevation: 78.66ft above Project V Reference Kelly Bushing Elevation: 78.66ft above Structure Reference ~~~rr~-sun eat'~~LL~n~~ sErivEC~~ Survey Ref:svy4353 A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A Your Ref: API 500292194701 Job No. AK2Z3126704, Surveyed: 8 August, 2004 North Slope Alaska Measured Depth Incl. (ft) 15728.69 87.960 15745.00 86.900 15759.35 85.960 15789.15 83.110 15824.08 85.710 15857.02 15888.65 15920.03 15949.25 15979.16 16015.53 16047.26 16078.20 16112.11 16145.24 16176.70 16207.67 16242.02 16271.98 16303.99 16335.83 16367.91 16397.89 16432.04 16462.49 16493.63 16530.21 16559.29 16591.54 16623.07 16659.20 16687.04 16718.65 16750.97 16783.79 92.320 95.260 96.620 96.030 96.740 98.050 96.340 95.410 94.510 92.560 90.590 86.820 85.370 86.200 86.200 88.180 89.350 91.610 91.790 93.060 94.700 96.210 94.850 92.280 88.640 89.510 87.780 86.200 87.160 87.690 True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 273.160 8823.19 8901.85 10921.66 S 4511.29 W 5947832.34 N 607701.12E 4511.29 Tie-on Point 273.990 8823.93 8902.59 10920.64 S 4527.55 W 5947833.11 N 607684.84E 8.251 4527.55 Window Point 274.730 8824.82 8903.48 10919.55 S 4541.83 W 5947833.99 N 607670.55E 8.331 4541.83 283.880 8827.66 8906.32 10914.77 S 4571.07 W 5947838.34 N 607641.24E 32.023 4571.07 285.700 8831.07 8909.73 10905.89 S 4604.68 W 5947846.71 N 607607.50E 9.071 4604.68 286.370 8831.63 8910.29 10896.80 S 4636.32 W 5947855.33 N 607575.73E 20.169 4636.32 286.260 8829.54 8908.20 10887.93 S 4666.60 W 5947863.74 N 607545.32E 9.301 4666.60 286.630 8826.29 8904.95 10879.10 S 4696.54 W 5947872.13 N 607515.26E 4.490 4696.54 287.150 8823.07 8901.73 10870.66 S 4724.33 W 5947880.15 N 607487.34E 2.684 4724.33 285.290 8819.75 8898.41 10862.36 S 4752.87 W 5947888.03 N 607458.68E 6.620 4752.87 284.740 8815.07 8893.73 10853.01 S 4787.70 W 5947896.85 N 607423.71E 3.902 4787.70 284.240 8811.09 8889.75 10845.14 S 4818.18 W 5947904.28 N 607393.12E 5.611 4818.18 283.070 8807.93 8886.59 10837.87 S 4848.09 W 5947911.09 N 607363.11E 4.815 4848.09 283.300 8804.99 8883.65 10830.17 S 4880.98 W 5947918.31 N 607330.11E 2.739 4880.98 285.030 8802.95 8881.61 10822.08 S 4913.04 W 5947925.92 N 607297.93E 7.862 4913.04 290.170 8802.09 8880.75 10812.57 S 4943.00 W 5947934.98 N 607267.83E 17.491 4943.00 291.220 8802.79 8881.45 10801.63 S 4971.96 W 5947945.49 N 607238.71E 12.636 4971.96 293.020 8805.13 8883.79 10788.73 S 5003.71 W 5947957.91 N 607206.77E 6.719 5003.71 293.100 8807.33 8885.99 10777.02 S 5031.20 W 5947969.21 N 607179.11E 2.783 5031.20 293.990 8809.45 8888.11 10764.26 S 5060.48 W 5947981.53 N 607149.64E 2.774 5060.48 294.880 8811.01 8889.67 10751.11 S 5089.43 W 5947994.25 N 607120.50E 6.816 5089.43 298.030 8811.70 8890.36 10736.82 S 5118.14 W 5948008.11 N 607091.58E 10.472 5118.14 299.730 8811.45 8890.11 10722.35 S 5144.39 W 5948022.19 N 607065.12E 9.433 5144.39 302.020 8810.44 8889.10 10704.83 S 5173.68 W 5948039.27 N 607035.57E 6.723 5173.68 303.280 8809.15 8887.81 10688.42 S 5199.30 W 5948055.30 N 607009.71E 5.873 5199.30 303.570 8807.04 8885.70 10671.30 S 5225.23 W 5948072.02 N 606983.53E 5.348 5225.23 303.330 8803.56 8882.22 10651.23 S 5255.61 W 5948091.64 N 606952.85E 4.179 5255.61 301.850 8800.76 8879.42 10635.64 S 5279.99 W 5948106.86 N 606928.23E 6.894 5279.99 303.390 8798.76 8877.42 10618.29 S 5307.10 W 5948123.80 N 606900.87E 9.285 5307.10 305.330 8798.50 8877.16 10600.50 S 5333.12 W 5948141.21 N 606874.59E 13.081 5333.12 305.290 8799.09 8877.75 10579.62 S 5362.60 W 5948161.64 N 606844.80E 2.411 5362.60 306.450 8799.75 8878.41 10563.32 S 5385.15 W 5948177.61 N 606822.01E 7.481 5385.15 306.750 8801.40 8880.06 10544.50 S 5410.50 W 5948196.05 N 606796.39E 5.087 5410.50 304.110 8803.28 8881.94 10525.79 S 5436.78 W 5948214.36 N 606769.82E 8.679 5436.78 304.580 8804.75 8883.41 10507.30 S 5463.85 W 5948232.45 N 606742.48E 2.157 5463.85 BPXA r 26 August, 2004 -10:33 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A Your Ref: API 500292194701 Job No. AKZZ3126704, Surveyed: 8 August, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 16813.04 88.370 304.340 8805.76 8884.42 10490.76 S 5487.96 W 5948248.63 N 606718.13 E 16877.76 90.680 305.130 8806.29 8884.95 10453.88 S 5541.14 W 5948284.71 N 606664.41 E 16912.32 88.300 306.590 8806.60 8885.26 10433.64 S 5569.14 W 5948304.53 N 606636.11 E 16943.53 88.150 307.350 8807.57 8886.23 10414.88 S 5594.07 W 5948322.92 N 606610.91 E 16974.38 85.830 307.750 8809.19 8887.85 10396.11 S 5618.49 W 5948341.33 N 606586.20 E 17007.86 81.900 309.020 8812.77 8891.43 10375.44 S 5644.58 W 5948361.60 N 606559.81 E 17038.29 80.720 309.750 8817.36 8896.02 10356.36 S 5667.83 W 5948380.34 N 606536.28 E 17069.19 77.900 309.820 8823.09 8901.75 10336.93 S 5691.16 W 5948399.42 N 606512.66 E 17102.38 77.110 309.100 8830.27 8908.93 10316.33 S 5716.18 W 5948419.63 N 606487.34 E 17134.05 76.760 310.520 8837.43 8916.09 10296.58 S 5739.87 W 5948439.03 N 606463.35 E 17166.66 75.820 309.770 8845.16 8923.82 10276.16 S 5764.09 W 5948459.09 N 606438.83 E 17263.03 75.740 309.690 8868.84 8947.50 10216.45 S 5835.93 W 5948517.72 N 606366.11 E 17359.88 78.310 310.830 8890.58 8969.24 10155.46 S 5907.94 W 5948577.63 N 606293.20 E 17456.54 74.060 312.010 8913.66 8992.32 10093.38 S 5978.32 W 5948638.65 N 606221.90 E 17505.00 74.060 312.010 8926.97 9005.63 10062.20 S 6012.94 W 5948669.32 N 606186.82 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to WeA Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 17505.OOft., The Bottom Hole Displacement is 11721.91 ft., in the Direction of 210.862° (True). Dogleg Rate (°/100ft) 2.465 3.772 8.079 2.481 7.631 12.329 4.545 9.129 3.186 4.505 3.647 0.116 2.891 4.554 0.000 BPXA Vertical Section Comment 5487.96 5541.14 5569.14 5594.07 5618.49 5644.58 5667.83 5691.16 5716.18 5739.87 5764.09 5835.93 5907.94 5978.32 6012.94 Projected Survey • • 26 August, 2004 -10:33 Page 3 of 4 DrlllQuest 3.03.06.006 Halliburton Sperry-Sun Survey Reporf for PBU WOA W Pad - W-09A Your Ref: API 500292194701 Job No. AKZZ3126704, Surveyed: 8 August, 2004 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 15728.69 8901.85 10921.66 S 4511.29 W Tie-on Point 15745.00 8902.59 10920.64 S 4527.55 W Window Point 17505.00 9005.63 10062.20 S 6012.94 W Projected Survey Survev tool program for W-O9A From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 14607.14 8730.30 BP High Accuracy Gyro (W-09) 14607.14 8730.30 17505.00 9005.63 MWD+IIFR+MS (W-09A P61) BPXA • • 26 August, 2004 -10:33 Page 4 of 4 DrlllQuest 3.03.06.006 DEFINITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA W Pad W-09A PB 1 Job No. AKZZ3126704, Surveyed: 30 July, 2004 Survey Report 26 August, 2004 Your Ref: APl 500292194770 • Surface Coordinates: 5958820.04 N, 612049.08E (70° 17'47.1870" N, 149° 05'33.5688" Uh Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 958820.04 N, 112049.08E (Grid) Surface Coordinates relative to Structure Reference :1593.87 N, 2157.68E (True) Kelly Bushing Elevation: 78.66ft above Mean Sea Level Kelly Bushing Elevation: 78.66ft above Project V Reference Kelly Bushing Elevation: 78.66ft above Structure Reference 5~~t'~rl~-SUt'1 QtRtLLING ~~tutCL~ Survey Ref:svy4352 A Halliburton Company Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A P61 Your Ref: AP1500292194770 Job No. AKZZ3126704, Surveyed: 30 July, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 14607.14 55.570 227.020 8651.64 8730.30 10229.32 S 3833.53 W 5948534.71 N 608368.48E 3833.53 Tie-on Point MWD+IIFR+MS 14608.24 55.570 227.020 8652.26 8730.92 10229.93 S 3834.19 W 5948534.08 N 608367.82E 0.035 3834.19 14636.00 55.660 227.240 8667.94 8746.60 10245.52 S 3850.98 W 5948518.25 N 608351.27E 0.730 3850.98 Window 14672.81 55.510 224.160 8688.75 8767.41 10266.72 S 3872.71 W 5948496.72 N 608329.86E 6.914 3872.71 14706.77 57.420 221.180 8707.51 8786.17 10287.54 S 3891.89 W 5948475.62 N 608310.99E 9.226 3891.89 14739.21 58.450 218.410 8724.74 8803.40 10308.66 S 3909.48 W 5948454.24 N 608293.72E 7.902 3909.48 14769.84 60.960 215.870 8740.19 8818.85 10329.74 S 3925.44 W 5948432.92 N 608278.08E 10.881 3925.44 14802.29 59.500 213.240 8756.30 8834.96 10352.93 S 3941.42 W 5948409.50 N 608262.45E 8.350 3941.42 14831.60 59.310 208.460 8771.23 8849.89 10374.58 S 3954.35 W 5948387.66 N 608249.84E 14.052 3954.35 14862.81 60.070 204.830 8786.98 8865.64 10398.66 S 3966.43 W 5948363.40 N 608238.12E 10.332 3966.43 14898.89 62.220 198.540 8804.41 8883.07 10428.01 S 3978.08 W 5948333.88 N 608226.91E 16.387 3978.08 14929.14 67.410 195.500 8817.28 8895.94 10454.18 S 3986.07 W 5948307.60 N 608219.31E 19.416 3986.07 14961.30 73.220 196.770 8828.11 8906.77 10483.25 S 3994.49 W 5948278.40 N 608211.33E 18.444 3994.49 14993.07 81.270 194.820 8835.11 8913.77 10513.04 S 4002.91 W 5948248.49 N 608203.35E 26.035 4002.91 15025.17 87.870 193.150 8838.15 8916.81 10544.03 S 4010.62 W 5948217.39 N 608196.10E 21.202 4010.62 15055.72 93.340 192.460 8837.83 8916.49 10573.81 S 4017.39 W 5948187.51 N 608189.78E 18.047 4017.39 15089.15 95.200 194.550 8835.34 8914.00 10606.22 S 4025.17 W 5948154.99 N 608182.48E 8.356 4025.17 15121.16 94.480 199.900 8832.64 8911.30 10636.68 S 4034.62 W 5948124.40 N 608173.49E 16.805 4034.62 15154.16 93.770 201.520 8830.26 8908.92 10667.46 S 4046.26 W 5948093.44 N 608162.31E 5.348 4046.26 15187.55 95.630 210.540 8827.52 8906.18 10697.33 S 4060.84 W 5948063.35 N 608148.17E 27.492 4060.84 15219.81 98.050 211.950 8823.68 8902.34 10724.72 S 4077.45 W 5948035.73 N 608131.97E 8.666 4077.45 15250.94 99.490 215.750 8818.93 8897.59 10750.26 S 4094.58 W 5948009.93 N 608115.22E 12.920 4094.58 15283.60 100.380 222.400 8813.29 8891.95 10775.22 S 4114.85 W 5947984.67 N 608095.33E 20.240 4114.85 15315.54 97.420 222.680 8808.35 8887.01 10798.47 S 4136.18 W 5947961.11 N 608074.35E 9.308 4136.18 15347.01 91.640 224.180 8805.86 8884.52 10821.24 S 4157.74 W 5947938.02 N 608053.13E 18.971 4157.74 15377.83 87.380 229.320 8806.13 8884.79 10842.35 S 4180.17 W 5947916.58 N 608031.01E 21.657 4180.17 15409.11 86.600 234.360 8807.77 8886.43 10861.64 S 4204.73 W 5947896.92 N 608006.75E 16.282 4204.73 15439.98 87.320 240.180 8809.41 8888.07 10878.30 S 4230.65 W 5947879.88 N 607981.08E 18.971 4230.65 15473.00 89.480 245.330 8810.33 8888.99 10893.40 S 4259.98 W 5947864.34 N 607951.98E 16.906 4259.98 15504.55 88.950 252.810 8810.77 8889.43 10904.67 S 4289.43 W 5947852.64 N 607922.70E 23.766 4289.43 • • 26 August, 2004 -10:33 Page 2 of 4 DrillQuesf 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A PB1 Your Ref: API 500292194770 Job No. AKZZ3126704, Surveyed: 30 July, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 15536.51 89.200 258.390 8811.28 8889.94 10912.61 S 4320.36 W 15567.73 84.570 263.150 8812.98 8891.64 10917.61 S 4351.12 W 15600.98 84.570 264.250 8816.13 8894.79 10921.24 S 4384.02 W 15631.43 86.950 266.050 8818.38 8897.04 10923.81 S 4414.27 W 15665.00 87.720 270.230 8819.94 8898.60 10924.90 S 4447.78 W 15696.69 86.300 274.140 8821.59 8900.25 10923.69 S 4479.40 W 15728.69 87.960 273.160 8823.19 8901.85 10921.66 S 4511.29 W 15760.80 90.960 273.390 8823.50 8902.16 10919.82 S 4543.34 W 15792.67 93.490 274.440 8822.26 8900.92 10917.65 S 4575.11 W 15824.87 94.850 274.800 8819.92 8898.58 10915.06 S 4607.12 W 15856.61 95.100 274.280 8817.17 8895,83 10912.56 S 4638.64 W 15888.49 93.120 275.560 8814.88 8893.54 10909.83 S 4670.32 W 15920.70 91.540 276.600 8813.57 8892.23 10906.42 S 4702.32 W 15952.75 91.480 278.990 8812.73 8891.39 10902.08 S 4734.06 W 15984.66 90.560 281.200 8812.16 8890.82 10896.49 S 4765.47 W 16017.13 91.300 281.480 8811.63 8890.29 10890.10 S 4797.30 W 16049.12 90.490 284.100 8811.13 8889.79 10883.02 S 4828.49 W 16080.89 90.960 283.490 8810.73 8889.39 10875.45 S 4859.34 W 16113.39 92.250 284.300 8809.82 8888.48 10867.65 S 4890.88 W 16145.71 93.520 284.550 8808.19 8886.85 10859.60 S 4922.14 W Global Coordinates Northings Eastings (ft) (ft) 5947844.23 N 607891.89 E 5947838.78 N 607861.21 E 5947834.65 N 607828.37 E 5947831.64 N 607798.16 E 5947830.05 N 607764.67 E 5947830.78 N 607733.04 E 5947832.34 N 607701.12 E 5947833.70 N 607669.04 E 5947835.40 N 607637.24 E 5947837.51 N 607605.20 E 5947839.54 N 5947841.79 N 5947844.73 N 5947848.60 N 5947853.72 N 5947859.63 N 5947866.24 N 5947873.36 N 5947880.69 N 5947888.26 N 16176.60 92.690 288.740 8806.52 8885.18 10850.77 S 4951.68 W 5947896.65 N 16205.36 91.700 291.260 8805.42 8884.08 10840.94 S 4978.69 W 5947906.08 N 16239.60 90.250 295.210 8804.83 8883.49 10827.44 S 5010.14 W 5947919.11 N 16270.31 90.800 299.140 8804.55 8883.21 10813.42 S 5037.45 W 5947932.72 N 16323.00 90.800 299.140 8803.82 8882.48 10787.76 S 5083.47 W 5947957.69 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16323.OOft., The Bottom Hole Displacement is 11925.50ft., in the Direction of 205.231° (True). 607573.64 E 607541.93 E 607509.88 E 607478.08 E 607446.59 E 607414.67 E 607383.37 E 607352.41 E 607320.76 E 607289.39 E 607259.71 E 607232.57 E 607200.92 E 607173.40 E 607127.00 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 17.475 4320.36 21.250 4351.12 3.293 4384.02 9.790 4414.27 12.648 4447.78 13.111 4479.40 6.022 4511.29 9.370 4543.34 8.594 4575.11 4.368 4607.12 1.812 4638.64 7.390 4670.32 5.871 4702.32 7.457 4734.06 7.501 4765.47 2.437 4797.30 8.572 4828.49 2.424 4859.34 4.686 4890.88 4.005 4922.14 13.808 4951.68 9.408 4978.69 12.287 5010.14 12.921 5037.45 0.000 .5083.47 Projected Survey • • 26 August, 2004 - 10:33 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Reporf for PBU WOA W Pad - W-09A P61 Your Ref: AP1500292194770 Job No. AKZZ3126704, Surveyed: 30 July, 2004 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 14607.14 8730.30 10229.32 S 3833.53 W Tie-on Point 14636.00 8746.60 10245.52 S 3850.98 W Window 16323.00 8882.48 10787.76 S 5083.47 W Projected Survey Survev tool program for W-09A PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 14607.14 8730.30 BP High Accuracy Gyro (W-09) 14607.14 8730.30 16323.00 8882.48 MWD+IIFR+MS (W-09A PB1) BPXA • 26 August 2004 -10:33 Page 4 of 4 DrillQuest 3.03.06.006 s Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA W Pad W-09A MWD Job No. AKMW3126704, Surveyed: 8 August, 2004 Survey Report 27 August, 2004 Your Ref: AP1500292194701 Surface Coordinates: 5958820.04 N, 612049.08E (70° 17' 47.1870" N, 149° 05' 33.5688" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 958820.04 N, 112049.08E (Grid) Surface Coordinates relative to Structure Reference :1593.87 N, 2157.68E (True) Kelly Bushing Elevation: 78.66ft above Mean Sea Level Kelly Bushing Elevation: 78.66ft above Project V Reference Kelly Bushing Elevation: 78.66ft above Structure Reference ~1"'~'~-'S51.J1""M DRILLING SER A Halliburton Company Survey Ref: svy4354 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A MWD Your Ref: API 500292194701 Job No. AKMW3121i704, Surveyed: 8 August, 2004 North Slope Alaska Measured True Depth Incl. Azim. (ft) 15728.69 87.960 272.420 15745.00 86.900 273.990 15759.35 85.960 274.730 15789.15 83.110 282.670 15824.08 85.710 284.590 15857.02 92.320 285.280 15888.65 95.260 284.930 15920.03 96.620 285.030 15949.25 96.030 286.120 15979.16 96.740 284.390 16015.53 98.050 284.920 16047.26 96.340 284.480 16078.20 95.410 283.220 16112.11 94.510 283.140 16145.24 92.560 285.120 16176.70 90.590 287.510 16207.67 86.820 289.300 16242.02 85.370 291.600 16271.98 86.200 292.560 16303.99 86.200 295.090 16335.83 16367.91 16397.89 16432.04 16462.49 16493.63 16530.21 16559.29 16591.54 16623.07 16659.20 16687.04 16718.65 16750.97 16783.79 Sub-Sea Depth (ft) 8823.26 8823.99 8824.88 8827.73 8831.13 8831.69 8829.60 8826.36 8823.14 8819.81 8815.13 8811.16 8807.99 8805.06 8803.01 8802.15 8802.85 8805.19 8807.39 8809.51 Vertical Depth (ft) 8901.92 8902.65 8903.54 8906.39 8909.79 8910.35 8908.26 8905.02 8901.80 8898.47 8893.79 8889.82 8886.65 8883.72 8881.67 8880.81 8881.51 8883.85 8886.05 8888.17 88.180 298.230 8811.07 8889.73 89.350 298.840 8811.77 8890.43 91.610 299.670 8811.51 8890.17 91.790 300.710 8810.50 8889.16 93.060 300.950 8809.21 8887.87 94.700 300.320 8807.11 8885.77 96.210 299.880 8803.63 8882.29 94.850 299.590 8800.83 8879.49 92.280 302.260 8798.82 8877.48 88.640 303.420 8798.57 8877.23 Local Coordinates Northings Eastings (ft) (ft) 10924.98 S 4513.36 W 10924.07 S 4529.63 W 10922.98 S 4543.91 W 10918.50 S 4573.21 W 10910.31 S 4606.99 W 10901.83 S 10893.60 S 10885.54 S 10877.74 S 10869.92 S 4638.79 W 4669.26 W 4699.41 W 4727.38 W 4756.06 W 10860.79 S 10852.81 S 10845.44 S 10837.74 S 10829.66 S 10820.83 S 10811.06 S 10799.08 S 10787.85 S 10774.95 S 10760.69 S 10745.36 S 10730.72 S 10713.55 S 10697.96 S 10682.13 S 10663.87 S 10649.51 S 10632.97 S 10615.88 S 4790.95 W 4821.40 W 4851.28 W 4884.18 W 4916.24 W 4946.42 W 4975.79 W 5007.90 W 5035.58 W 5064.80 W 5093.22 W 5121.39 W 5147.54 W 5177.05 W 5203.17 W 5229.90 W 5261.41 W 5286.54 W 5314.15 W 5340.63 W Global Coordinates Northings Eastings (ft) (ft) 5947828.99 N 607699.09 E 5947829.65 N 607682.81 E 5947830.53 N 607668.52 E 5947834.57 N 607639.16 E 5947842.26 N 607605.26 E Dogleg Vertical Rate Section Comment (°/100ft) 11.606 8.331 28.192 9.237 4513.36 4529.63 4543.91 4573.21 4606.99 Tie- on Point Window Point 5947850.27 N 607573.33E 20.176 5947858.04 N 607542.75E 9.360 5947865.65 N 607512.48E 4.346 5947873.03 N 607484.39E 4.222 5947880.42 N 607455.60E 6.219 5947889.03 N 607420.58E 3.881 5947896.56 N 607390.01E 5.562 5947903.48 N 607360.02E 5.044 5947910.69 N 607327.02E 2.664 5947918.29 N 607294.84E 8.380 5947926.67 N 5947936.00 N 5947947.50 N 5947958.31 N 5947970.78 N 5947984.62 N 5947999.52 N 5948013.78 N 5948030.50 N 5948045.70 N 5948061.13 N 5948078.92 N 5948092.90 N 5948109.03 N 5948125.72 N 607264.53 E 607235.02 E 607202.74 E 607174.89 E 607145.48 E 607116.86 E 607088.45 E 607062.09 E 607032.33 E 607005.98 E 606979.01 E 606947.24 E 606921.90 E 606894.05 E 606867.31 E 9.843 13.474 7.902 4.229 7.886 11.648 4.113 8.031 3.089 4.244 5.640 4.298 4.781 11.479 12.116 4638.79 4669.26 4699.41 4727.38 4756.06 4790.95 4821.40 4851.28 4884.18 4916.24 4946.42 4975.79 5007.90 5035.58 5064.80 5093.22 5121.39 5147.54 5177.05 5203.17 5229.90 5261.41 5286.54 5314.15 5340.63 • BPXA 89.510 303.560 8799.15 8877.81 10595.94 S 5370.76 W 5948145.21 N 606836.89E 2.439 5370. 76 87.780 304.710 8799.81 8878.47 10580.33 S 5393.80 W 5948160.48 N 606813.62E 7.461 5393. 80 86.200 305.150 8801.47 8880.13 10562.25 S 5419.67 W 5948178.16 N 606787.48E 5.188 5419. 67 87.160 303.990 8803.34 8882.00 10543.94 S 5446.24 W 5948196.07 N 606760.64E 4.654 5446. 24 87.690 304.110 8804.81 8883.47 10525.59 S 5473.41 W 5948214.02 N 606733.20E 1.656 5473. 41 27 August, 2004 - 6:12 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A MWD Your Ref: API 500292194701 Job No. AKMW3126704, Surveyed: 8 August, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) 16813.04 88.370 303.550 8805.82 8884.48 10509.31 S 5497.69 W 5948229.93 N 606708.68E 3.011 16877.76 90.680 304.420 8806.36 8885.02 10473.14 S 5551.35 W 5948265.30 N 606654.49E 3.814 16912.32 88.300 305.540 8806.66 8885.32 10453.33 S 5579.66 W 5948284.69 N 606625.88E 7.611 16943.53 88.150 305.780 8807.63 8886.29 10435.14 S 5605.01 W 5948302.49 N 606600.27E 0.907 16974.38 85.830 307.120 8809.25 8887.91 10416.84 S 5629.79 W 5948320.42 N 606575.22E 8.681 17007.86 81.900 308.360 8812.83 8891.49 10396.47 S 5656.11 W 5948340.40 N 606548.60E 12.302 17038.29 80.720 309.540 8817.43 8896.09 10377.56 S 5679.50 W 5948358.96 N 606524.93E 5.453 17069.19 77.900 310.240 8823.16 8901.82 10358.09 S 5702.79 W 5948378.08 N 606501.34E 9.394 17102.38 77.110 309.290 8830.34 8909.00 10337.37 S 5727.70 W 5948398.43 N 606476.13E 3.671 17134.05 76.760 310.800 8837.50 8916.16 10317.52 S 5751.32 W 5948417.92 N 606452.22E 4.774 17166.63 75.820 310.240 8845.22 8923.88 10296.95 S 5775.38 W 5948438.13 N 606427.85E 3.334 17263.03 75.740 311.100 8868.90 8947.56 10236.06 S 5846.26 W 5948497.96 N 606356.08E 0.869 17359.88 78.310 311.890 8890.64 8969.30 10173.53 S 5916.94 W 5948559.43 N 606284.47E 2.770 17456.54 74.060 312.980 8913.72 8992.38 10110.22 S 5986.20 W 5948621.70 N 606214.27E 4.531 17505.00 74.060 312.980 8927.03 9005.69 10078.45 S 6020.29 W 5948652.96 N 606179.71E 0.000 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 17505.OOft., The Bottom Hole Displacement is 11739.63ft., in the Direction of 210.852° (True). BPXA Vertical Section Comment 5497.69 5551.35 5579.66 5605.01 5629.79 5656.11 5679.50 5702.79 5727.70 5751.32 5775.38 5846.26 5916.94 5986.20 6020.29 Projected Survey • • 27 August, 2004 - 6:12 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A MWD Your Ref: AP1500292194701 Job No. AKMW3126704, Surveyed: 8 August, 2004 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 15728.69 8901.92 10924.98 S 4513.36 W Tie- on Point 15745.00 8902.65 10924.07 S 4529.63 W Window Point 17505.00 9005.69 10078.45 S 6020.29 W Projected Survey Survev tool program for W-O9A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 14608.00 8730.79 BP High Accuracy Gyro (W-09) 14608.00 8730.79 17505.00 9005.69 MWD Magnetic (W-09A PB1 MWD) r BPXA • • 27 August, 2004 - 6:12 Page 4 of 4 DrIIIQuest 3.03.06.006 Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA W Pad W-09A PB 1 MWD Job No. AKMW3126704, Surveyed: 30 July, 2004 Survey Report 26 August, 2004 Your Ref: AP1500292194770 Surface Coordinates: 5958820.04 N, 612049.08E (70° 17' 47.1870" N, 149° 05' 33.5688" Vh Grid Coordinate System: NAD27 Alaska Sfate Planes, Zone 4 Surface Coordinates relative to Project H Reference: 958820.04 N, 112049.08E (Grid) Surface Coordinates relative to Structure Reference : 1593.87 N, 2157.68 E (True) Kelly Bushing Elevation: 78.66ft above Mean Sea Level Kelly Bushing Elevation: 78.66ff above Project V Reference Kelly Bushing Elevation: 78.66ff above Structure Reference S~E'"1'~i'~~--51,1['1 C7NitLLtN6 seFtvt ~S Survey Ref: sry4355 A Halllburton Company • • Halliburton Sperry: Sun Survey Report for PBU WOA W Pad - W-09A P81 MWD Your Ref: API 500292194770 Job No. AKMW3126704, Surveyed: 30 July, 2004 North Slope Alaska Measured True Depth Incl. Azim. (ft) 14607.14 55.570 227.020 14608.00 55.569 226.983 14636.00 55.535 225.764 14672.81 55.510 224,160 14706.77 57.420 221.180 14739.21 58.450 218.590 14769.84 60.960 215.870 14802.29 59.500 214.430 14831.60 59.310 209.990 14862.81 60.070 205.960 14898.89 62.220 198.200 14929.14 67.410 195.120 14961.30 73.220 196.520 14993.07 81.270 195.700 15025.17 87.870 194.140 15055.72 93.340 193.220 15089.15 95.200 195.480 15121.16 94.480 200.710 15154.16 93.770 203.120 15187.55 95.630 210.740 15219.81 98.050 212.120 15250.94 99.490 215.570 15?_83.60 100.380 221.660 15315.54 97.420 222.030 15347.01 91.640 223.660 15377.83 15409.11 15439.98 15473.00 15504.55 15536.51 15567.73 15600.98 15631.43 15665.00 87.380 228.810 86.600 233.740 87.320 239.470 89.480 244.540 88.950 251.880 Sub-Sea Depth (ft) 8651.64 8652.13 8667.97 8688.81 8707.57 8724.79 8740.25 8756.36 8771.28 8787.04 8804.47 8817.34 8828.17 8835.18 8838.21 8837.89 8835.40 8832.70 8830.32 8827.58 8823.74 8818.99 8813.35 8808.41 8805.93 8806.19 8807.84 8809.47 8810.40 8810.83 Vertical Depth (ft) 8730.30 8730.79 8746.63 8767.47 8786.23 8803.45 8818.91 8835.02 8$49.94 8865.70 8883.13 8896.00 8906.83 8913.84 8916.87 8916.55 8914.06 8911.36 8908.98 8906.24 8902.40 8897.65 8892.01 8887.07 8884.59 8884.85 8886.50 8888.13 8889.06 8889.49 89.200 257.480 8811.35 8890.01 84.570 262.420 8813.04 8891.70 84.570 263.620 8816.19 8894.85 86.950 265.540 8818.44 8897.10 87.720 269.670 8820.00 8898.66 Local Coordinates Northings Eastings (ft) (ft) 10229.32 S 3833.53 W 10229.80 S 3834.05 W 10245.73 S 3850.76 W 10267.20 S 3872.20 W 10288.01 S 3891.38 W 10309.11 S 3909.00 W 10330.17 S 3924.99 W 10353.19 S 3941.21 W 10374.53 S 3954.66 W 10398.32 S 3967.29 W 10427.58 S 10453.79 S 10482.91 S 10512.66 S 10543.52 S 10573.19 S 10605.48 S 10635.79 S 10666.32 S 10695.97 S 10723.30 S 10748.85 S 10773.97 S 10797.48 S 10820.47 S 10841.77 S 10861.31 S 10878.27 S 10893.76 S 10905.46 S 10913.90 S 10919.34 S 10923.36 S 10926.23 S 10927.63 S 3979.13 W 3986.96 W 3995.22 W 4003.81 W 4012.03 W 4019.25 W 4027.51 W 4037.41 W 4049.70 W 4064.75 W 4081.45 W 4098.58 W 4118.65 W 4139.70 W 4161.02 W 4183.27 W 4207.63 W 4233.35 W 4262.49 W 4291.76 W 4322.57 W 4353.25 W 4386.10 W 4416.33 W 4449.83 W Global Coordinates Northings Eastings (ft) (ft) 5948534.71 N 608368.48 E 5948534.22 N 608367.97 E 5948518.04 N 608351.49 E 5948496.25 N 608330.38 E 5948475.15 N 608311.51 E 5948453.80 N 608294.20 E 5948432.51 N 608278.53 E 5948409.24 N 608262.66 E 5948387.70 N 608249.53 E 5948363.73 N 608237.26 E 5948334.30 N 5948307.97 N 5948278.73 N 5948248.86 N 5948217.88 N 608225.85 E 608218.41 E 608210.59 E 608202.45 E 608194.69 E 5948188.10 N 5948155.69 N 5948125.24 N 5948094.53 N 5948064.66 N 5948037.08 N 5948011.28 N 5947985.86 N 5947962.05 N 5947938.74 N 5947917.10 N 5947897.21 N 5947879.87 N 5947863.95 N 5947851.81 N 608187.91 E 608180.13 E 608170.68 E 608158.85 E 608144.24 E 608127.95 E 608111.20 E 608091,51 E 608070.82 E 608049.84 E 608027.91 E 608003.85 E 607978.37 E 607949.47 E 607920.38 E BPXA Dogleg Vertical Rate Section Comment (°/100ft) 3833.53 Tie-On Point 3.593 3834.05 MWD Magnetic 3.593 3850.76 Window Point 3.593 3872.20 9.226 3891.38 7.474 3909.00 11.221 3924.99 5.923 3941.21 13.055 3954.66 11.410 3967.29 19.752 3979.13 19.472 3986.96 18.525 3995.22 25.463 4003.81 21.122 4012.03 18.156 4019.25 8.741 4027.51 16.435 4037.41 7.595 4049.70 23.416 4064.75 8.620 4081.45 11.889 4098.58 18.568 4118.65 9.338 4139.70 19.078 4161.02 21.682 4183.27 15.935 4207.63 18.682 4233.35 16.683 4262.49 23.323 4291.76 • U 5947842.91 N 607889.70E 17.537 4322.57 5947837.02 N 607859.11E 21.666 4353.25 5947832.50 N 607826.32E 3.593 4386.10 5947829.19 N 607796.14E 10.031 4416.33 5947827.29 N 607762.66E 12.501 4449.83 26 August, 2004 - 10:27 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Reporf for PBU WOA W Pad - W-09A P81 MWD Your Ref: API 500292194770 Job No. AKMW3126704, Surveyed: 30 July, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) {ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) 15696.69 86.300 273.720 8821.66 8900.32 10926.69 S 4481.45 W 5947827.75 N 607731.03E 13.526 15728.69 87.960 272.420 8823.26 8901.92 10924.98 S 4513.36 W 5947828.99 N 607699.09E 6.586 15760.80 90.960 272.430 8823.56 8902.22 10923.62 S 4545.44 W 5947829.87 N 607667.00E 9.343 15792.67 93.490 273.390 8822.32 8900.98 10922.01 S 4577.24 W 5947831.01 N 607635.18E 8.490 15824.87 94.850 272.620 8819.98 8898.64 10920.32 S 4609.31 W 5947832.21 N 607603.09E 4.850 15856.61 95.100 272.850 8817.23 8895.89 10918.81 S 4640.90 W 5947833.25 N 607571.48E 1.068 15888.49 93.120 274.170 8814.95 8893.61 10916.87 S 4672.63 W 5947834.72 N 607539.72E 7.458 15920.70 91.540 275.320 8813.64 8892.30 10914.20 S 4704.70 W 5947836.91 N 607507.61E 6.065 15952.75 91.480 277.580 8812.79 8891.45 10910.61 S 4736.54 W 5947840.03 N 607475.73E 7.052 15984.66 90.560 280.000 8812.22 8890.88 10905.73 S 4768.06 W 5947844.44 N 607444.13E 8.112 BPXA Vertical Section Comment 4481.45 4513.36 4545.44 4577.24 4609.31 4640.90 4672.63 4704.70 4736.54 4768.06 16017.13 91.300 280.670 8811.70 8890.36 10899.91 S 4800.00 W 5947849.78 N 607412.11E 3.074 4800.00 16049.12 90.490 282.720 8811.20 8889.86 10893.42 S 4831.32 W 5947855.80 N 607380.70E 6.890 4831.32 16080.89 90.960 282.250 8810.79 8889.45 10886.56 S 4862.34 W 5947862.20 N 607349.58E 2.092 4862.34 16113.39 92.250 282.820 8809.88 8888.54 10879.50 S 4894.05 W 5947868.78 N 607317.77E 4.339 4894.05 16145.71 93.520 283.530 8808.26 8886.92 10872.15 S 4925.48 W 5947875.67 N 607286.23E 4.500 4925.48 16176.60 92.690 287.330 8806.58 8885.24 10863.94 S 4955.21 W 5947883.43 N 607256.39E 12.574 4955.21 16205.36 91.700 289.520 8805.48 8884.14 10854.86 S 4982.47 W 5947892.11 N 607228.99E 8.351 4982.47 16239.60 90.250 293.280 8804.90 8883.56 10842.37 S 5014.34 W 5947904.12 N 607196.94E 11.768 5014.34 16270.31 90.800 296.920 8804.62 8883.28 10829.35 S 5042.14 W 5947916.73 N 607168.95E 11.987 5042.14 16323 00 90.800 296.920 8803.88 8882.54 10805.49 S 5089.12 W 5947939.88 N 607121.62E 0.000 5089.12 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16323.OOft., The Bottom Hole Displacement is 11943.94ft., in the Direction of 205.219° (True). Projected Survey • z 26 August, 2004 -10:27 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU WOA W Pad - W-09A P81 MWD Your Ref; API 500292194770 Job No. AKMW3126704, Surveyed: 30 July, 2004 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 14607.14 8730.30 10229.32 S 3833.53 W Tie-On Point 14636.00 8746.63 10245.73 S 3850.76 W Window Point 16323.00 8882.54 10805.49 S 5089.12 W Projected Survey Survev tool program for W-09A PB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 14608.00 8730.79 BP High Accuracy Gyro (W-09) 14608.00 8730.79 16323.00 8882.54 MWD Magnetic (W-09A P61 MWD) BPXA r • • 26 August, 2004 -10:27 Page 4 of 4 DrlllQuest 3.03.06.006 • • WELL LOG TRANSMITTAL ~~~ r~~'~ To: State of Alaska February 17, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 i"3~ Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs W-09A + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 W-09A + PS1: LAS Data & Digital Log Images: 50-029-21947-01, 70 1 CD Rom ~ir~~- ~~ a~0`t l°"L SAP % 3 ~~!0~ WELL LOG TRANSMITTAL~iaska Oil ~ Gas Cans. Commi~siurb ,gn~hnrage To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7''' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs W-09A, September 16, 2004 AK-MW-3126704 1 LDWG formatted Disc with verification listing. API#: 50-029-21947-01 _- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-Technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson. Blvd. Anchorage, Alaska 9951.8 Anchorage, Alaska 99508 ~ Date: ~~" Si • • 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well W-09f~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 15,728.69' MD Window /Kickoff Survey: 15,745.00' MD (if applicable) Projected Survey: 17,505.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ Date ~~ ~~ Signed - tV ~ ~ ~~l Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) • • 06-Sep-04 AOGCC Rabin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well W-09A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 15,728.69' MD Window /Kickoff Survey: 15,745.00' MD (if applicable) Projected Survey: 17,505.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date l 1 ~~r~`~~ Signed w~f Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~~~-~o~ • • 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well W-09A PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 14,607.14' MD Window /Kickoff Survey: 14,636.00' MD (if applicable) Projected Survey: 16,323.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 f i Date ~ ~' Signed Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~Ul~~~~ • • 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well W-09A PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 14,607.14' MD Window /Kickoff Survey: 14,636.00' MD (if applicable) Projected Survey: 16,323.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~~ `'I Si ned ''Uv 9 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ALASSiA OIL A1~tD G~-5 C011TSERQATIOIQ COl-II~IISSIOIQ Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,. Alaska 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 2767542 Re: Prudhoe Bay W-09A BP Exploration (Alaska) Inc. Permit No: 204-102 Surface Location: 1437' SNL, 1194' WEL, SEC. 21, TllN, R12E, UM Bottomhole Location: 941' SNL, 1969' WEL, SEC. 32, T11N, R12E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's petroleum field inspector at (907) 65 -36 7 (pager). BY ORDER 01~; THE COMMISSION DATED thi day of June, 2004 cc: Department of Fish & Game, Habitat Section w/o encl Department of Environmental Conservation w/o encl. ~~~- ~1~1z~r4 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION C MISSION ~~~4~ PERMIT TO DRILL ,~uN 204 20 AAC 25.005 ~ .. . 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ® eve opment i u~fip a Zone ^ Stratigraphic Test ^ Service ^ Development ~~~ [~~Igle Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ^ Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU W-09A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 17449 TVD 9032 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1437' SNL 1194' WEL SEC 21 T11N R12E UM 7. Property Designation: ADL 047453 Pool , , , . , , Top of Productive Horizon: 1701' SNL, 237' WEL, SEC. 32, T11N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 10, 2004 Total Depth: 941' SNL, 1969' WEL, SEC. 32, T11N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y- 5958820 Zone-ASP4 10. KB Elevation (Height above GL): 81.96 feet 15. Distance to Nearest well Within Pool W-10A is 567' away at 15,032' 16. Deviated Wells: Kickoff Depth 14655 ft Maximum Hole Angle 93 ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3518 psig Surface: 2614 psig 18. Casing Program Size Specifications Setting Depth To Bottom Quantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-3/4" 3-1/2" 9.2# L-80 IBT-M 3249 14200' 8507' .177 9032' 12 cu ft Class 'G' 7 ~ 19. PRESENT W ELL' CONDITION SUMMARY (To be comp leted for Redrill AND Re-entry Operations) Total Depth MD (ft): 15430 Total Depth TVD (ft): 9199 Plugs (measured): 14274' Effective Depth MD (ft): 15306 Effective Depth TVD (ft): 9129 Junk (measured): None Casing Length Size Cement Volume MD TVD tr r I n t r 110' 20" 110' 110' rf 3264' 13-3/8" 500 cu ft Coldset II 3264' 2650' 14638' 9-5/8" 3212 cu ft Class 'G' 14638' 8753' Pr cti 1069' S-1/2" 536 cu ft Class 'G' 14359' - 15428' 8596' - 9198' Perforation Depth MD (ft): 14906' - 15154' Perforation Depth TVD (ft): 8904' - 9044' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Thomas Schaefer, 564-4685 Printed Name Bill Isaacson Title Senior Drilling Engineer / Prepared By Name/Number: Si nature ~ _ ~ Phone 564-5521 Date ~'I ~ o~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,Z~ Z API Number: 50-029-21947-01-00 Permit Approval Date: 8 See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~ No Mud Log Require ^ Yes ~lo Hydrogen Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No Other: TES f~C ~ L C ~S~E~ ~?S f ~~C~v' C t ~. '~ d ~, c'~C1 ~!? . BY ORDER OF ~ ~ a A roved THE COMMISSION Date ~(I~°`~ Form 10-40~F'j~Kiised 2/2 3 `~ ( ~ ~ ~ (.,; ~ ~ J\ t S~/bmif In Duplicate • • Well Name: W-09A Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Horizontal Sidetrack Producer Surface Location: X = 612,049.08 Y = 5,958,820.04 Estimated 1437' FNL, 1194 'FEL Sec. 21, T11 N, R12E Umiat ~ Target Location: X = 607,913 Y = 5,947,935 TVDss 8808' Ivishak Zone 4 1701' FNL, 237' FEL Sec. 32, T11 N, R12E Umiat ~ Bottom Hole Location: X = 606,168 Y = 5,948,670 TVDss 8950' 941' FNL, 1969' FEL Sec. 32, T11 N, R12E Umiat ~ AFE Number: PBD4P2240 Ri Do on 16 Estimated Start Date: 06/1 4 O eratin da s to com lete: 28.6 _~ MD: 17,449' TVD: 9,032' BF/MS: 53' KB: 26' KBE: 81.96' Well Desi n conventional, slimhole, etc.: Horizontal Sidetrack Ob'ective: Ivishak Zone 4: 42P-46P Casing/Tubing Program Hole Size Csg/ Wt/Ft Tb O.D. Grade Conn Length Top MDlTVD Btm MDlTVD Tubin 3'/z" 9.2# 13Cr-80 VAM To 14,164' 26/26 14,190 /8,507' 4 3/4" 3'/z" 9.2# L-80 IBT-M 3,249' 14,200/8,507' 17,449'/ 9,032' Directional KOP: 14,655' MD Maximum Hole Angle: 92.93° at 15,912' MD (climb to mid 46P) ~56° at the whipstock setting depth ~90°-78° in 4 3/4" horizontal section Close Approach Well(s): One close approach well has been identified: ' ' W-10A with ctr-ctr distance of 567 at 15,032 MD This well passes major risk criteria with allowable deviation of 90'. W-10A is a normal producer with no known annular integrity issues. In addition W- 09A is tanned to kick off and drill in the o osite direction from W-10A. Surve Pro ram: MWD IFR/Cassandra. W-09A Permit to Drill Logging Program • 4 3/4" Production: Sample Catchers - as required by wellsite geologist for geosteering. Drilling: MWD Dir/GR/Res -Real time GR/Res throu hout entire interval. Open Hole: None Cased Hole: No cased hole to s re uired. Formation Markers Formation Tops (wp04) MD TVDss Press. Comments TKNG -7443 TJG -7515 TJ F -7763 TJ E -7945 TJ D -8200 TJC -8411 TJ B -8525 TSGR -8663 3396 KOP -8676 3401 TSHU 14,668 -8684 3405 TEIL 14,900 -8773 3439 + 10 uncertaint TSAD near landin 15,175 -8800 3450 ±10' uncertaint 45N near Toe 15,225 -8803 3451 ± 20' uncertaint 45P 16,830 -8815 3457 ± 20' uncertaint 44N 16,870 -8823 3460 ± 20' uncertaint 43N 16,960 -8844 3470 ± 20' uncertaint 42N 17,200 -8897 3494 ± 20' uncertaint 41 N 17,300 -8918 3503 ± 20' uncertaint 41 P 17,400 -8937 3512 ± 20' uncertaint TD 17,449 -8950 3518 ± 20' uncertaint TD Criteria: Reach planned TD to drain target area, test OWC and Maximize MI benefit unless drilling conditions deteriorate. Mud Program Section Millina Mud Properties: FloPro SF Whip Stock Window 5 1/2" 17# Densit Viscosit PV YP MBT H API FI 8.4-8.5 50-55 4-7 25-35 <3 8.5-9.0 N/C Production Mud Properties: FloPro SF 4 3/4" hole section Densit Viscosit PV YP MBT H API FI 8.4- 45-55 4-7 20-28 <3 8.5-9.0 N/C W-09A Permit to Drill • Cement Pro ram Casin Size 3'/z" 9.2#, L-80 Solid Liner • Basis: Lead: None Tail: Based on 2795' of 3'/i" x 4 3/4" open hole annulus with 40% excess + 85' shoe + 296' of 3'/z" x 5'/z" liner annulus ~ 150' liner lap + 200' DP x 7" casing annulus Tail TOC: ,20 ' D / 8508' TVD-bkb To of Liner BHST = 230°F Fluid Sequence & V mes: Pre 15bbls CW 100 Flush Spacer 25 bbls MudPUSH XL at 9.5 ppg Lead None Tail , 512 ft3, 367 acks Class G w/ Gas-Block C«~ 15.8 ppg, 1.53{3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval Maximum antici ated BHP 3518 si 7.5 p C~ 9032' TVD Maximum surface ressure 2614 si .10 psi/ft as radient to surface Kick tolerance Infinite Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin 5 1/2" Liner Test 3,500 si surface pressure Inte rit Test - 4 3/a" hole FIT Planned com letion fluids 8.6 p Seawater / 7.2 pp Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. W-09A Permit to Drill 4 W-09A Sidetrack and Complete Procedure Summary Pre-riq Operations: In preparation for the sidetrack the following pre-work has been performed: / PPPOT-IC failed test, will change out IC packoff during RWO / Tested OA to 2,400 psi -failed 7/4/03 / Functioned all tubing hanger and 9 5/8" casing pack-off lock down screws and verified free movement. Completely backed out and checked each lock down screw for breakage. Complete as of 5/29/04. / PPPOT-T complete as of 5/29/04. PPPOT-IC failed test; appears to be plastic packed; will change out IC pack-off during RWO. / MIT OA to 2,400psi, failed 7/04/2003. Crude appeared in cellar with 1,200psi applied. Remaining Work: 1. R/U and fluid pack the tubing and the tubing X 9 5/8" annulus. CMIT T X IA to 2,500psi for 30 minutes. 2. R/U slick-line. Dummy off any live GLM. 3. RIH and pull the PX plug from the `X' nipple at 14,274'md. ~ 4. R/U coil tubing. RIH and P&A the 5'/i" liner and open perforations withr'`~23 Is of 15.8ppg class `G' slurry. Leave cement top at 14,750'md. 5. R/U slick-line. Drift the 4'/z" tubing and tag TOC. Confirm sufficient clearance for the 4'/z" tubing chemical cutter (3 5/8" O.D.) to the planned cut depth of 14,220'. 6. Pressure test 9 5/8" casing against the cement plug to 3,500psi. 7. R/U E-line. RIH with tubing punch and shoot holes above and below the packer. POOH. 8. RIH w/ a 3 5/8" chemical cutter. Cut the 4 ~/z" tubing at 14,220' in an attempt to leave a 15' stub for fishing above GLM. 9. Circulate the well with clean seawater through the tubing cut. Freeze protect tubing and casing with diesel from 2,200' to surface. 10. Pressure test the well to 3,500psi. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Remove the wellhouse. Level the pad as necessary. Ria Operations: 1. MI / RU Doyon rig 16. 2. R/U lines and circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down the tree. Nipple up and test the BOPE to 3,500psi. ~ 4. Pull BPV. 5. R/U. Pull the 41h" tubing from the cut at 14,220' MD and above. 6. M/U O/S, 4 '/z" grapple/wash pipe assembly. RIH, picking up 4" drill pipe, and latch the tubing stump at 14,220'. r,, 7. Retrieve the Baker E-22 anchor seal assembly. POOH. 8. M/U a Baker PRT packer milling assembly. 9. RIH to Baker SB-3 permanent packer. Mill packer free per Baker representative. Circulate. POOH. 10. Test 9 5/8" casing to 3,500 psi. POOH. If there is a leak it will be necessary to RIH with an RTTS and locate the leak. 11. M/U a HES 9 5/8" Composite Bridge plug. RIH and set at 2,800' MD (adjust depth if leak is deeper than this configuration allows). 12. Test the 9 5/8" CBP to 3,500psi. 13. M/U a 9 5/8" casing cutting assembly, per Baker representative. 14. RIH and cut the 9 5/8" casing at 2,200' MD. POOH. 15. Circulate the casing annulus with 9.4-9.6 ppg brine. 16. Break BOP stack, PU, pull packoff and tac weld 9 5/8" slips to casing. Set stack down. /°~~ W-09A Permit to Drill 5 • ~ 17. Spear the 9 5/8" casing. POOH laying down casing from cut at 2,200'. ~'' 18. M/U a 13 3/8" casing scraper assembly. RIH to 9 5/8" casing stub. Circulate well bore clean with 9.4-9.6 brine. 19. M/U a HES 13 3/8" Composite Bridge Plug. RIH and set CBP at ~2,100'md (above casing stub). POOH. ~ 20. M/U and RIH w/ RTTS and isolate 13 3/8" leak w/ 2,500 psi. 21. M/U a 13 3/8" casing cutting assembly, per Baker representative. 22. Obtain accurate wellhead measurements in preparation for welding on a new wellhead. 23. RIH and cut the 13 3/8" casing in the middle of the first full joint below the damage. POOH. If damage is ~`° very near surface it may be possible to cut in middle of first joint. The stub must be at least 15' to allow back-off tool to engage. 24. N/D BOPE. 25. Cut off wellhead. M/U 13 3/8" casing spear assembly RIH and pull the 13 3/8". Be careful not to apply excessive overpull for risk of pulling up conductor. 26. M/U the Baker 13 3/8" casing back-off assembly. RIH and back off the cut 13 3/8" stub. POOH. If necessary rig up diverter (or 3" camlock fitting on valve welded to 20"conductor), m/u wash pipe and milling assembly. Clean out around 13 3/8" stump to clear the 13 3/8" annulus down to the casing collar. 27. M/U 13 3/8" spear assembly. RIH and recover the 13 3/8" stub. 28. M/U Baker guide sub and new 13 3/8" casing. RIH and thread into casing stump. Pressure-test the new 13 /`~ 3/8" casing to 2,500psi. 29. Set the 13 3/8" casing on slips. 30. Measure casing and prepare cellar area for making casing cut. (Minimal change in height from previous wellhead will allow for the S-riser to be used without modification.) Cut and dress the 13 3/8" casing stump. 31. Install bell nipple, new 9 5/8" casing head, and 4'/z" tubing I}ead. 32. N/U and test ROPE. Test the 13 3/8" casing to 2,500 psi j 33. R/U and perform 1"cement top job on 13 3/8" annulus. 34. M/U a 12 1/4" clean out assembly. RIH and drill up the 13 3/8" HES Composite Bridge plug. Chase junk down to the 9 5/8" casing stub at 2,200'. Circulate the well clean. POOH. 35. M/U the Baker 9 5/8" casing back-off assembly. RIH and use drill collars to push junk on top of stub down/- into and past stub. Back off the cut 9 5/8" stub. POOH. 36. M/U 9 5/8" spear assembly. RIH and recover the 9 5/8" stub. 37. Establish infectivity into OA. 38. M/U Baker guide sub and sufficient joints of new 9 5/8" casing. If OA will accept fluid injection, thread into casing collar and bullhead freeze protection into 9 5/8" X 13 3/8" annulus after the tree is nippled up.~ Otherwise freeze protect well before threading in casing collar with fuel oil weighted to 9.4-9.6 ppg. 39. Pressure-test the 9 5/8" casing to 3,500psi. 40. N/D and raise BOPE stack. `,. 41. Set the 9 5/8" casing on slips. Cut 9 5/8" casing with Wachs cutter;. Set back BOPE stack. 42. N/U and test BOPE. Test casing to 3,500 psi for 30 minutes. / 43. M/U 8 1/2" clean out assembly, RIH, and drill 9 5/8" CBP and push junk to 5 '/z" liner top at 14,359'. POOH. 44. M/U 4 3/a" mill and 9 5/8" scraper on a tapered string of 2 7/8" X 4" drill pipe complete with Gamma Ray tool. ,r 45. RIH, mill junk, and dress off P&A plug top at 14,750'md till it will accept weight. Circulate well clean. 1 Displace well to 8.5ppg Flo-Pro fluid. POOH. ~'r 46. Pressure-test the 9 5/8" casing X 5'/i" liner to 3,500psi for 30 minutes. Record test. 47. P/U and RIH with 5 1/2" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on cement plug. Shear off of whip stock. 48. Mill window in 5 1/2" liner at 14,655' MD, plus approximately 20' beyond middle of window. Circulate the well bore clean. 49. Pull up into 5 1/2" liner and conduct an FIT to 10.Oppg EMW. POOH. 50. M/U 4 3/a" Dir/GR/Res assembly. RIH, kick off and drill the 4 3/4" production section to TD of 17,450' MD ~ per directional proposal. 51. Circulate well bore clean, short trip to the window. Circulate bottoms up, spot liner running pill. POOH. 52. Run and cement a 3'/i", 9.2#, L-80 solid production liner, with the liner hanger/packer extending above the /" 5'/z" liner top, as per well plan. POOH. 53. Test the 9 5/8" casing X 3'/z" liner to 3,500psi for 30 minutes. Record the test. W-09A Permit to Drill 6 • • 54. P/U and RIH with Schlumberger 2" Powerjet TCP perforating guns on 2 1/16" tubing. Perforate ~ approximately 1,100' of Z4 interval, per subsurface team. POOH. 55. R/U and run a tapered 4 %i", 12.6# X 3 1/2", 9.2#, 13Cr-80, VAM TOP tubing completion, placing the TT into the liner top TBS at ~14,200'md. 56. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 57. Set a TWC and test from below to 1,OOOpsi. 58. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull the TWC. 59. Freeze protect the well to 2,200'. Install BPV and test to 1,OOOpsi. Secure the well. 60. Rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Retrieve the DCR shear valve. Replace with DV. W-09A Permit to Drill 7 • • Job 1: MIRU Hazards and Contingencies - The W-09A is on the East side of W-pad between W-OS and W-10. Wells are spaced on 30' centers. Therefore both the W-08 and W-10 will require shut-in and wellhouse removal for the rig move from W-20. In addition all diverter line lifts should be treated as critical lifts. - W--Pad is not an HZS site. Recent H2S data from the pad is as follows: #1 Closest S_HL Well H2S_Level W-08 NA #2 Closest SHL Well H2S Level W-10 NA #1 Closest BHL Well H2S Level _m._.~ _~ __ _, . _.. W-10 NA ___.__ #2 Closest BHL Well H2S Level u,_.~ ~~ W-11 NA _._ m_.~ .,...~,__,~ Max. Recorded H2S on Pad/Facility W-36 10 10/9/2001 - Post Permit to Drill in camp prior to spud. - IA Pressure Barriers: 1) cement P&A plug 2) wellhead/tree with BPV - OA Pressure Barriers: 1) CITOA -failed 7/4/03 -will require dispensation to proceed with repair operations 2) wellhead with double valves Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies - The perforations in W-09A have been isolated with a cement plug set during pre-rig operations. Monitor well for any signs of pressure or flows. - Note and record required PU weight to pull tubing at cut point. - NORM test all retrieved well head and completion equipment. - The existing wellhead is an FMC 13-5/8" 5K and has 4 1/2" CCL TDS running threads on the tubing hanger. Inspect the tubing hanger after ND the tree to verify the thread type and ensure the threads are in good condition. Be prepared with necessary equipment to remove. - IA Pressure Barriers: cement P&A plug with kill weight fluid above 2) wellhead/tree with BPV - OA Pressure Barriers: CITOA -failed 7/4/03 -will require dispensation to proceed with repair operations 2) wellhead with double valves Reference RP • "De-completions" RP W-09A Permit to Drill 8 • • Job 3: 13 3/8" Casing Repair Hazards and Contingencies - A 9 5/8" CBP will be set 600' below 9 5/8" casing cut and tested to provide IA integrity. In addition a 13 318" CBP with kill weight fluid above it will be used to provide further IA isolation once the 9 5/8" has been removed. - Until the 13 3/8" casing has been repaired and tested there will be no double OA barriers in place. Therefore a dispensation will be needed to proceed. - If 9 5/8" casing does not test against cement plug during pre-rig work it will be necessary to use RTTS to locate leak. A 13 3/8" RTTS will be used to locate the OA leak. Make sure to have all equipment available. - Exercise caution when pulling on 13 3/8" casing with spear so as to not damage the 20" conductor. - Assure that the 9 5/8" annulus has been circulated clean so as to remove as much hydrocarbons from the well as possible before tac welding slips to casing. - IA Pressure Barriers: 1) cement P&A plug 2) CBP in 9 5/8" casing stub - OA Pressure Barriers: CITOA -failed 7/4/03 -will require dispensation to proceed with repair operations 2) wellhead with double valves Reference RP • "Casing Cut and Pull with Baker Back-off Tool" RP Job 4: Window Mill Hazards and Contingencies - Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. - IA Pressure Barriers: 1) kill weight milling fluid 2) BOPE - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RP • "Whipstock Sidetracks" RP Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies - Two fault crossing are probable in this well with anticipated depth of 14,825' MD (Shublik) and 16, 400' MD for the fault in the horizontal section. Fault #1 is a regional fault with throw is estimated to be about 200' down to the West and is not expected to cause lost circulation problems. The second fault is a 10-20' throw fault striking NE-SW and is downthrown to the NW. Fault #2 will be crossed at near perpendicular so should not cause losses. W-10A had losses of 86 bbls at 14,313' MD which are believed to be associated with crossing the original wellbore frac. It is possible that the same could happen on the W-09. Follow the lost circulation decision tree should LC become problematic. W-09A Permit to Drill 9 • • - A pump out sub will be run in the BHA to aid in placing LCM material. - The wellbore is planned to crosscut through the 46P and toe down at the end to test the OWC and maximize MI benefit. Good quality GR/Res logs will be needed to identify sand/shale distribution for perforating. - One close approach well has been identified (see the "Directional" section for details). At the W-09A kick off point the W-10 is as close as 567', however the W-09A will be kicked off to the West drilling in the exact opposite direction of the W-10. W-10A has no history of annular integrity issues and is cemented across the same interval being drilled in the W-09A. Measurement error possibilities could place the wells significantly closer under extreme worst-case scenarios. Watch for indications of magnetic interference. Cease drilling and contact the drilling manager if wellbore interference is detected. - KICK TOLERANCE: In the worst-case scenario of 7.6 ppg pore pressure in the Ivishak, a fracture ~ lent f 9.7 ppg at the 5 1/2" casing window, and 8.5 ppg mud in the hole, the kick tolerance is -' Infinit ~~~-< "~ ressure Barriers: 1) kill weight drilling fluid 2) BOPE - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Job 9: Install 3 ~/z" Solid Production Liner Hazards and Contingencies - The completion design includes a 3'/x", 9.2#, L-80 IBT-M solid liner throughout the production interval. - Differential sticking is a concern. The 8.5 ppg mud wily be ~500psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 3'/i" liner will to be run to extend 150' back up into the 9 5/8" intermediate liner. - Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. A Gas-lock type slurry is requested to ensure the best chance for zonal isolation. - IA Pressure Barriers: 1) kill weight drilling fluid 2) BOPE - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RPs • "Modified Production Liner/Casing and Cementing Guidelines" • Schlumberger Cement Program Job 10: DPC Perforate Production Liner W-09A Permit to Drill 10 • • Hazards and Contingencies - Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. - IA Pressure Barriers: 1) kill weight fluid 2) BOPE - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RPs • Follow Schlumberger's perforating practices and recommendations. • "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is 0.1 psia at 100° F. - IA Pressure Barriers: 1) kill weight completion fluid 2) ROPE - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Job 13: ND/NU/Release Rip Hazards and Contingencies - The closest neighboring wells are spaced as follows: W-08 at 35.01' and W-10 at 35.06'. These two wells will require well house removal and shut-in for the rig move from W-11 i and while moving off. Care should be taken while moving onto the well. Spotters will be used at all times. - IA Pressure Barriers: 1) kill weight completion fluid on top of ball/rod and packer 2a) wellhead with BOPE or 2b) wellhead with TWC or 2c) wellhead with tree and BPV - OA Pressure Barriers: 1) CITOA 2) wellhead with double valves Reference RP • "Freeze Protecting an Inner Annulus" RP W-09A Permit to Drill 11 r: W-09A Well • Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Production Hole Section: • There are two fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. • Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. • There are no close approach issues in the production hole section after direction is confirmed at kick off. • Kick tolerance is Infinite with a 9.7 ppg FIT. • Differential sticking has been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S • This Pad is no designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. W-09A Permit to Drill 12 TREE = 4" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 90.66' BF. ELEV = 53.96' KOP = 904' Max Angle = 61 @ 9500' Datum MD = 14882' Datum TVD = 8800' SS LJ OA near surface leak found 5/04 13 3/8" TOC near surface, tob job on primary cmt job OA Arctic Packed w/dry crude to shoe 13-3/8" 68# L-80 BTC, ID = 12.415" 3264' 9 5/8" TOC rrex height 6,890' 4 1/2" PX plug, set 7/08/03 14,274' Minimum ID = 3.725" @ 14357' 4-1 /2" OTIS SSSV NIPPLE TOP OFS-1/2"LNR 14359' 4-1/2" TBG, 12.6#, L-80, ID = 3.958" 14369' I 9-5/8" 47# NS-80S NSCC ID = 8.681" I PERFORATION SUMMARY REF LOG: SWS - BHCS ON 06/22/89 ANGLEATTOPPERF: 55@ 14982' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 14982 - 14996 O 07/14/91 3-3/8" 4 15000 - 15036 O 07/14/91 3-3/8" 2 15044 - 15084 O 07/02/89 3-3/8" 2 15094 - 15154 O 07/02/89 3-3/8" 4 14906 - 14948 O 07/18/91 NOTES: 5-112" TIW SEAL STEM LANDED W ~O 9 LNR HGR TIEBACK SLV 2306' ~-{4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4141 3011 59 OTIS RA 3 8724 5508 56 OTIS RA 2 11938 7216 54 OTIS RA 1 14246 8442 56 OTIS RA 14274' ~4-1/2" PARKER SWS NIP, ID = 3.813" 14280' BAKERTBGANCHOR ~ 14281' H9-5/8" X 4-1 /2" BAKER SB-3 PERM PKR, ID = 3.99" II ~ 14335' H 4-1/2" PARKER SWS NIP, ID = 3.813" 14357' 14369' 4-1/2" OTIS XN NIP, ID = 3.725" a-1/2" x 5-1/2" xo 14369' S-1/2" TNV SEAL STEM WIO SEALS 14366' ELMD TT LOGGED 09/21/91 14685' I-~ MARKER JOINT 14937' I~ EXT CSG PKR 15153' I-1 EXT CSG PKR PBTD -j 15300, 5-1/2" LNR, 17#, L-80, ID = 4.892" 15428' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/02/89 DFF ORIGINAL COMPLETION 09/04/01 RN/TP CORRECTIONS 01/26/04 RMO/TLP MINIMUM ID CORRECTION 05/28/04 TJS OA/1A STATUS L- PRUDHOE BAY UNfT• WELL: W-09 PERMff No: 1890540 API No: 50-029-21947-00 SEC 21, T11 N, R12E, 1437' SNL & 1194' WEL BP Exploration (Alaska) TREE = 4" CM/ WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 90.66' BF. ELEV = 53.96' KOP = 904' Max Angle = 61 @ 9500' Datum MD = 14882' Datum TVD = 8800' SS ~ W 09 Pre Ri SAFETY NOTES: 5-112" TIW SEAL STEM LANDED ~ ~ IN LNR HGR TIEBACK SLV OA near surface leak found 5/04 13 3/8" TOC near surface, O 2306' 4-1/2" OTIS SSSV NIP, ID = 3.813" tob job on primary cmt job OA Arctic Packed w/dry crude to shoe GAS LIFT MANDRELS ~ 13-3/8" 68# L-80 BTC, ID = 12.415" ~ Minimum ID = 3.725" ~ 14357' 4-1/2" OTIS SSSV NIPPLE Pre-rig them cut 4 1/2"tubing 14,267' \' ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 4141 3011 59 OT1S RA 3 8724 5508 56 OTIS RA 2 11938 7216 54 OTIS RA 1 14246 8442 56 OTIS RA 9 5/8" TOC rrex hegM 6,890' ~ 14274' ~4-1/2" PARKER SWS NIP, ID= 3.813" 14280' BAKER TBG ANCHOR Pre-rig punch holes abv/blw pkr 14,281' TOP OF 5-1/2" LNR ~-~ 14359' ~ 4-112" TBG, 12.6#, L-80, ID = 3.958" ~ ~ 14281' H 9-5/8" X 4-1 /2" BA KER SB-3 PERM PKR, ID = 3.99" ~ 14335' ~--~4-1/Z" PARKER SWS NIP, ID = 3.813" 143Sf' H4-1/2" OTIS XN NIP, ID = 3.725" 14369' a-v2" x 5-1/2° xo 14369' 5-112" TN1i' SEAL STEM W/O SEALS 14366' -j ELMD TT LOGGED09/21 /91 9-518" 47# NS-805 NSCC ID = 8.681" 14638' Pre-rig cement P&A plug 14,750' - 146$5' ~~ MA RKER JOINT 14937' H EXT CSG PKR PEf2FORATION SUMMARY REF LOG: SWS - BtiCS ON 06/22/69 ANGLE AT TOP PERF: 55 @ 1498 '.- Note: Refer to Production DB for historical rerf da~_~ SIZE SPF INTERVAL O n/S z DATE 3-3/8" 4 14982 - 14996 O 07/1 d ', 3-3/8" 4 15000 - 15036 O 07/14,4 ' 3-318" 2 15044 - 15084 O 07/02.' 3-3/8" 2 15094 - 15154 O n7~02' 3-3/8" 4 14906 - 14948 O PBTD 5-1/2" LNR, 17#, L-80, ID = 4.892" 15153' I-i EXT CSG PKR DATE REV BY COMMENTS DATE REV BY COMMENTS 07/02/89 DFF ORIGINAL COMPLETION 09/04/01 RN/TP CORRECTIONS 01/26/04 RMO/TLP MINIMUM ID CORRECTION 05/28/04 TJS OA/IA STATUS/PRE-RIG WORK PRUDHOE BAY UNff WELL: W-09 PERMIT No: 1890540 API No: 50-029-21947-00 SEC 21, T11N, R12E, 1437' SNL & 1194' WEL BP Exploration (Alaska) TREE = 4 1 /16" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 90.66` BF. ELEV.- 53.96' KOP = 904' Max Angle = 61 @ 9500' Datum MD = 14882' Datum TV D = 8800' SS L-80, ID = 12.415" 3,264' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH 6 2150 2000 40° 3 1 /2" X 1 112" MMG DV RK 5 4340 3200 59° 3 1 /2" X 1 1 /2" MMG DCR RK 4 6720 4500 55° 3 1/2" X 1 1/2" MMG DV RK 3 8995 5750 57° 3 1 /2" X 1 1 /2" MMG DV RK 2 11410 7000 56° 3 1/2" X 1 1/2" MMG DV RK 1 13690 8250 59° 3 1/2" X 1 1/2" MMG DV RK 14,125' 3 1 /2" 'X' landing nipple, ID = 2.813" 14,145' 9 5/8" X 4 1/2" Baker S-3 Packer 14,170' 3 1/2" 'X' landing nipple, ID = 2.813" 14,190' 3112"'X'landingnipple, ID=2.813" XO 3 1/2" to 7" WLEG 14,190' 14,190' 3 1/2", 9.2#, 13Cr-80, VAM TOPtubing 14,200' 7 X 9 5/8" Baker ZXP liner top packer, w / TBS, ,/" " liner. HMC liner hanger crossed over to 3 1/2 Top 5-1/2" Liner 14359' 9-5/8", 47#, Ns- 14638' 80S, ID = 8.681" Marker joint 14,685' External casing pkr 14,937' External casing pkr 15,153' PBTD 15300' 5-1/2" Liner, 17#, 15428' L-80, ID = 4.892" 2,100' 3 1/2" 'X' landing nipple, ID = 2.813" 14,655' Window exit in 5 1/2" liner from Whipstock set on EZSV f ~~ ~ . ~, ~' ~y: 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/02/89 DFF ORIGINAL COMPLETION 09/04/01 RN/TP CORRECTIONS 01/26/04 RMO/TLP MINIMUM ID CORRECTION 04/26/04 dew Proposed Completion 17,450' 3 1/2", 9.2#, L-80, IBT-M solid liner PRUDHOE BAY UNIT WELL: W-09A PERMIT No: API No: 50-029-21947-01 SEC 21, T11 N, R12E, 1437' SNL & 1194' WEL BP Exploration (Alaska) W-~9A Proposed •ompletion t'UMPANY U4TAll 1 KI~~7JtI:N('1~.INIt)RMAI ION riURVEY PRt)(i1tAM I'INI: W-O)A xpf}J I)cep WO (W-09/Plml W-09A I>c yl K-f )I nP Nmu.'o .,nhnuw lNl.l Nrlirclxr, Wcll ('tour: WJ14, Tnw•N~~N1 1 .• I)cplb l4n Urplll T o 1un'ry ~l'Iw I•~•~I ('rculcl l f3y'l}uy I:ilcnM1%ky 1)a1c 4/%20114 . . 3~' toYf~W91Y>t~ <'ulruWbon Mr111oJ. M nc'un~lun' .. -.."...- ' ' 1 V IIt I'~ I Nn11N.n,oW:1 IJn~<no I]JJ4.i a I'Funna L W-119A wrAla lky KO\' A7 x'U ('lli~-k cd' I);nc WlA I .mrtri}.ICw Itil l M ll l I (' li l N ~nl Mr ruI U.I IL Ft.linn..: xl!)n ril 4G I t' l l oi M ll l M11i i l' l • ' - run r xu : rur r n rr ~ l I~.mrt %orlecc I;Iliplicul ~ ('uNing u ro : ull r uu : o lnwn unv un K~~iiexrd: I>alc: Wvmin•Mrltuxl: KuIc. IWsal FORMATION TOP DETAILS CASING DETAILS `\'I'I I uhlnus N:ulx~ N -ri I~ -W N.~1tl1u1v Iu.onx I NooNL 1 ..o%nwlr ril•~I No. TVDPath MDPath Formation No. TVD MD Name Size W{I4 1'4J,fi% '_I~1/.3 <4<XN_'4lN <,I?INV IKK 7o"17'J].I%]N IJ`nl~)3.~nvN' N.4 96 14667 97 TSHU I 8765 I 9031 b7 17448 00 3 I'2" 3 10 . . 2 0.00 0.00 TEIL . . 0 I^a`il'I uel.^u_e 3 0.00 0.00 TSAR Nunn IVI) N-~ I:-W' N~xtlonX Iamlp dupe War/A Ii II' %%(AI!N• -III]•T/XII -<I_i-III <~µ7`µn1N1 nU7u%744 1'~~nn I W{ryA I. MII)Jnl' %%n<_yr; -IIW7•rnt -IW.J2J ~`N7%7o.U11 fiU747.44 1'a•ilo W{I4A IJJ<N %%NJ.`X -I n~l!Jxl «iG 111 <43%:21.~X N'{NA I I I I• %%%4_M5 -IIKKZi-111 -124N2% ~'µ74i~,IN1 11116670.91 I'unn /AINI2.44 P~lim W'awA 1'••h- %%n•i •N~ -Ilui'_i.lll -I.4N.n <•µ743<iNl ~ fio7412) Ih+lv%.~u I I) ulil `M -Ilxlli.lu ~WXr•i11,IN1 W'-ovA I~ IaN.IG]_44 P~nm SECTION DETAILS •, Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 14655.00 55.70 227.36 8758.75 -10254.24 -3860.79 0.00 0.00 3860.79 2 14675.00 >7.38 225.31 8769.78 -10265,76 -3872.85 12.00 -46.00 3872.85 3 14954.51 84.38 203.96 8861.42 -10481.85 -4017.16 12.00 -40.98 4017.16 , 4 15065.77 84.38 203.96 887232 -10583.04 -4062.13 0.00 0.00 4062.13 5 15410.41 90.00 245.00 8889.96 -10823.10 -429828 12.00 83.58 429828 W-09A T1 LI' G 18198.73 92.93 267.42 8885.08 -10867.71 -447292 12.00 82.3> 4479.92 7 15912.0(, 92.93 267.42 8869.06 -1088L81 -4792.52 Q00 0.00 4792.52 8 15983.94 9200 276.00 8865.96 -10879.67 -4864.24 12.00 96.00 4864.24 W-09A T2 MID 46P 7800 9 16004.80 91.31 278.40 8865.36 -10877.06 -4884.92 12.00 106.06 4884.92 10 16056.75 91.31 278.40 8864.17 -10869.47 -4936.3U 0.00 0.00 4936.30 II 16257.62 90.50 302.50 8860.96 -10799.80 -5123.10 12.00 91.70 8123.10 W-09AT31P 12 16263.06 89.98 302.11 8860.94 -10796.89 -5127.69 12.00 -143.02 5127.69 13 1651261 89.98 302.11 8861.03 -10664."'5 -5339.07 0.00 0.00 5339.08 I4 16761.57 79.00 312.30 8884.96 -1051SU0 -5536.01 6.00 137.64 5536.01 N'-O)AT445N 15 16784.35 77.64 312.39 8889.57 -10499.98 -5552.50 6.00 176.49 1552.50 IG 17449.34 77.64 31239 9031.96 -IUO(?.IU -6012.'8 0.00 0.00 6032.28 N•-09AT5 TD 81 c Q' 0 0 L c F 3600 3 ri) 1 42 U 4500 4800 5100 Vertical Section at 270.00° [300ft/in] 54C0 ~~ ~ ~ _' • <'IIMI'ANV nl~lnll .5 Ii IrIK1:Nt'IINI~I)IUfAlit)N IL L ~ 151 1 .,..1 I NI. I<I µ' 11t W I •Nunh +~u~.llw xiu. ,.ww.~~i I I AI ~II 1 M nl unallue I,: '+ _ I}( W1A ~` I Il'n K I NI.Y( %I.YM1 k IA k 1 k I IlUNI IM)I:1 M 4 M•II I Ire~( yhakr Nunh ca 71hpK4 %1.) %I Il <a41In.n Al 1+l: Al t I.mrt.~urluc<: I~JIi(xxvl ~(asmg ms mun inanv. Wxming Mekxxl: Kula n un.•~I SECTION DETAILS Sec MD Inc Azi TVD +N%-S +E--N' DLeg TFace b'Sec Target I 2 146$$,00 14675.00 55.70 57.38 227.36 225 31 8758.71 -10254.24 8769 78 -10265 76 -3860.79 3 0.00 0.00 3860.79 3 14954.51 84.38 . 203.96 . . 8861.42 -104R1.85 - 872.85 -4017.16 12.00 12.00 -46.00 -40 98 3872.85 4017 16 4 15065.77 84.38 203.96 8872.32 -10583.04 -4062.13 0.00 . 0 00 . 4062 13 5 G 15410.41 15598 73 90.00 92 93 245.00 267 42 8889.96 -10823.10 -4298 ?8 12.00 . 83.58 . 4298 ?8 W-09A TI LP 7 . 15912.06 . 92.93 . 267.42 8885.08 -10867.71 8869.06 -10881 81 -447292 -4792 52 12.00 0 00 82.35 0 00 4479.92 8 9 15983.94 16004 80 92.00 91 31 276.00 278 40 . 8865AG -10879.67 . -486414 . 12.00 . 96.00 4792.52 4864?4 W-09AT2MID4GP 10 . 16056.75 . 91.31 . 278.40 8865.36 -10877.06 8864 17 -10869 47 -4884.92 -4936 30 12.00 106.06 4884.92 II 12 16257.62 16 90.50 302.50 . . 8860.96 -10799.80 . -5123.10 0.00 12.00 0.00 91.70 4936.30 5123.10 W-09AT31P 263.06 89.98 302.11 8860.94 -10796.89 -5127.69 12.00 -143.02 5127 69 13 IG51' GI 89.98 302.11 8861.03 -10664.25 _533)U7 0.00 0 00 . 533208 14 15 16761.57 16784 35 79.00 77 312.30 8884.96 -10515.00 -55;6.01 6.00 . 137.64 5i;6.01 W-09A T4 45N IG . 1744934 .64 312.39 8889.57 -10499.98 -5552.50 6.00 176.49 5552.50 77.64 312.39 9031.96 -10062.10 -603218 0.00 0.00 6032?8 W-09A T5 TD c c 0 0 r~ s t= 0 r 0 ...............~,.., Pla, w ovn Hrlw u~wT ti u I W Ix)It'IJrI w a~n u~ 0.RW Fm I).pih fn Jun~~'Plau lu,~l r I (}eJlaxl Ny Inn'lek hm'kr Daic YK~?IN)i IJfi~~lx) I]JJY.xJ 1'IanwM-µ'JwA i+rlN U.p K()\' Al µ'l) (~1 ' k'a~ 1) I W I:I.I nl~.I n11S Nunn .N.-% •I~:.W Nnnhn~ Ivnnng I.anwl.' I.. ixl.~ Slul W-u'> IiH ($ _'lii,fii :9.)ift2u.14 r~iJ4oJlx ]0`I Ti].I%7N IJ')'IL'i,i'ilvW NA IAKt~rl I)I:I nI1.S Nmn.' Ian N-S -I-..N' N~,nlun % I~aumX Shin w+lnnlil~ µ'-nvA T2 h71n Jnl' x%rex'~(, -In~w~xu -.I~i.lu K4 ?vJ]wa.lxl I,nlu~,vv r,~~~u W.IriA IJ4N 6..w~ -InH7v,t,i -IxIN._J x%%J.YI, -IU:I=Al11 -5<i4al <.~J]x't~IH) "JJ%:?J ~x Ian N7`)I I'uinl ' W.UYn 11 I.I' %xxl lG -Inx_'1, 111 -02')%_?% . ~YJ]vis)xl au,[,7u.9I 1 ninl Nnvl2 vl 1'uhu W+)YA Poly ' ~ x%%Y 9! -In%21.1V J]v%._`% ~uJ7vi<Ixl «nvl_'.'ri> Nulvyun µ -IxIA T~ Tn µ13 r'M -IINIG_-ICI Ia)1~].% ~'Wtniu,lrl r~It,IGi.IV I'ulnl FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8765.96 14667.97 TSHU 2 0.00 0.00 TEIL 3 0.00 0.00 TSAR CASING DETAILS No. 'FVD MD Name Size I 9031.67 17448.00 31/2" ;.>un West(-)/East(+) [300ft/in] S err -Sun -Draft Co P Y Sperry-Sun Company: BP Amoco Date:. 418!2004 Timer 16:54:55 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) References Well: W-09, True North Site: PB W Pad Vertical (TVD) Reference: 81:96' 82.0 Well: W-09 Section (VS) Reference: Well (O.OON,O.OOE,270.OOAzi) Wellpath: Plan W-09A Deep K/O Survey Calculation Method: Minimum Curvature Dbc Oracle Plan: W-09A wp04 Deep WO Date Composed: 3/22/2004 Version: 37 Principal: Yes Tied-to: From: Definitive Path 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: bggm2003 Site: PB W Pad TR-11-12 UNITED STATES :North Slope Site Position: Northing: 5957194.18 ft Latitude: 70 17 31.506 N From: Map Easting: 609919.18 ft Longitude: 149 6 36.343 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 47.83 ft Grid Convergence: 0.84 deg Well: W-09 Slot Name: W-09 Well Position: +N/-S 1594.68 ft Northing: 5958820.04 ft Latitude: 70 17 47.187 N +E/-W 2153.63 ft Easting : 612049.08 ft Longitude: 149 5 33.569 W Position Uncertainty: 0.00 ft Wellpath: Plan W-09A Deep WO Drilled From: W-09 Tie-on Depth: 14655.00 ft Current Datum: 81.96' H eight 81.96 ft Above System Datum: Mean Sea Level Magnetic Data: 4/2/2004 Declination: 25.09 deg Field Strength: 57567 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.96 0.00 0.00 270.00 Casing Points MD TVD Diameter Hole Size Name ft ft in in 17448.00 9031.67 3.500 4.750 31/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 TMLV 0.00 0.00 0.00 TKNG 0.00 0.00 0.00 TJ G 0.00 0.00 0.00 TJ F 0.00 0.00 0.00 TJ E 0.00 0.00 0.00 TJ D 0.00 0.00 0.00 TJ B 0.00 0.00 0.00 TSGR 0.00 0.00 14667.97 8765.96 TSHU 0.00 0.00 0.00 0.00 TEIL 0.00 0.00 0.00 0.00 TSAD 0.00 0.00 Targets Map. Map <-~ Latitude --a <-_ Longitude ---> Name Description TVD +N/-S +E/-W Northing Eastin g Deg Min Sec Deg .Min Sec Dip. Dir. ft ft ft ft ft W-09A T3 IP 8860.96 -10799.80 -5123.10 5947946.00 607087. 99 70 16 0.954 N 149 8 2.682 W W-09A T2 MID 46P 8865.96 -10879.67 -4864.24 5947870.00 607347. 99 70 16 0.170 N 149 7 55.146 W W-09A T4 45N 8884.96 -10515.00 -5536.01 5948224.58 606670. 91 70 16 3.752 N 149 8 14.706 W Sperry-Sun -Draft Co~ Sperry-Sun Company: BP Amoco Date: 4/8/2004 Time: 16:54:55 Page: 2 Field:. Prudhoe Bay Co-ordinate(NE) Reference: Well: W-09, True North Site: PB W Pad Vertical (TVD) Reference: 81.96' 52.0 Well: W-09 Section (VS) Reference: Well (O.OON,O.OOE,270.OOAzi) Wellpath: Plan W-09A Deep WO Survey Calculation Methods Minimum Curvature Dbt Oracle Targets Map Map <~- Latitude ----> <--- Longitude ---> Name Description TV D +N/-S +E/-W Northing Fasting Deg Min Sec. Deg Min Sec Dip. . Dir. ft ft ft ft ft W-09A T1 LP 8889. 96 -10823.1 0 -4298.28 5947935.00 607912.99 70 16 0.730 N 149 7 38.674 W W-09A Poly 8889. 96 -10823.1 0 -4298.28 5947935.00 607912.99 70 16 0.730 N 149 7 38.674 W -Polygon 1 8889. 96 -10004.4 6 -5940.40 5948729.00 606258.99 70 16 8.770 N 149 8 26.489 W -Polygon 2 8889. 96 -10078.1 1 -6098.53 5948653.00 606101.99 70 16 8.045 N 149 8 31.090 W -Polygon 3 8889. 96 -10591.1 7 -5565.08 5948148.00 606642.99 70 16 3.003 N 149 8 15.551 W -Polygon 4 8889. 96 -10931.1 0 -5037.04 5947816.00 607175.99 70 15 59.663 N 149 8 0.174 W -Polygon 5 8889. 96 -10979.68 -4596.68 5947774.00 607616.99 70 15 59.188 N 149 7 47.356 W -Polygon 6 8889. 96 -10875.52 -4069.02 5947886.00 608142.99 70 16 0.216 N 149 7 32.000 W -Polygon 7 8889. 96 -10590.3 7 -3941.74 5948173.00 608265.99 70 16 3.021 N 149 7 28.300 W -Polygon 8 8889. 96 -10566.1 2 -4159.43 5948194.00 608047.99 70 16 3.258 N 149 7 34.637 W -Polygon 9 8889. 96 -10725.5 5 -4199.81 5948034.00 608009.99 70 16 1.690 N 149 7 35.810 W -Polygon 10 8889. 96 -10812.5 9 -4600.19 5947941.00 607610.99 70 16 0.832 N 149 7 47.462 W -Polygon 11 8889. 96 -10770.23 -5026.64 5947977.00 607183.99 70 16 1.246 N 149 7 59.875 W -Polygon 12 8889. 96 -10487.1 8 -5428.50 5948254.00 606777.99 70 16 4.027 N 149 8 11.577 W W-09A T5 TD 9031. 96 -10062.1 0 -6032.28 5948670.00 606167.99 70 16 8.203 N 149 8 29.162 W Plan Section Information MD Incl Azim TVD +N!-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft .deg 14655.00 55.70 227.36 8758.75 -10254.24 -3860.79 0.00 0.00 0.00 0.00 14675.00 57.38 225.31 8769.78 -10265.76 -3872.85 12.00 8.42 -10.25 -46.00 14954.51 84.38 203.96 8861.42 -10481.85 -4017.16 12.00 9.66 -7.64 -40.98 15065.77 84.38 203.96 8872.32 -10583.04 -4062.13 0.00 0.00 0.00 0.00 15410.41 90.00 245.00 8889.96 -10823.10 -4298.28 12.00 1.63 11.91 83.58 W-09A T1 LP 15598.73 92.93 267.42 8885.08 -10867.71 -4479.92 12.00 1.56 11.90 82.35 15912.06 92.93 267.42 8869.06 -10881.81 -4792.52 0.00 0.00 0.00 0.00 15983.94 92.00 276.00 8865.96 -10879.67 -4864.24 12.00 -1.30 11.94 96.00 W-09A T2 MID 46P 16004.80 91.31 278.40 8865.36 -10877.06 -4884.92 12.00 -3.33 11.53 106.06 16056.75 91.31 278.40 8864.17 -10869.47 -4936.30 0.00 0.00 0.00 0.00 16257.62 90.50 302.50 8860.96 -10799.80 -5123.10 12.00 -0.40 12.00 91.70 W-09A T3 IP 16263.06 89.98 302.11 8860.94 -10796.89 -5127.69 12.00 -9.59 -7.22 -143.02 16512.61 89.98 302.11 8861.03 -10664.25 -5339.07 0.00 0.00 0.00 0.00 16761.57 79.00 312.30 8884.96 -10515.00 -5536.01 6.00 -4.41 4.09 137.64 W-09A T4 45N 16784.35 77.64 312.39 8889.57 -10499.98 -5552.50 6.00 -5.99 0.38 176.49 17449.34 77.64 312.39 9031.96 -10062.10 -6032.28 0.00 0.00 0.00 0.00 W-09A T5 TD Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tooi Comme t ft deg deg ft ft ft ft ft deg/100ft deg 0.00 0.00 0.00 0.00 -81.96 5958820.04 612049.08 0.00 0.00 0.00 TSAD TSAD 14655.00 55.70 227.36 8758.75 8676.79 5948510.27 608341.92 3860.79 0.38 0.00 MWD 14667.97 56.79 226.02 8765.96 8684.00 5948502.76 608334.19 3868.63 12.00 314.00 TSHU TSHU 14675.00 57.38 225.31 8769.78 8687.82 5948498.57 608330.03 3872.85 12.00 314.74 MWD 14700.00 59.67 223.03 8782.83 8700.87 5948483.06 608315.41 3887.70 12.00 319.02 MWD 14725.00 61.99 220.86 8795.02 8713.06 5948466.61 608301.07 3902.29 12.00 320.21 MWD 14750.00 64.35 218.78 8806.30 8724.34 5948449.26 608287.04 3916.57 12.00 321.27 MWD 14775.00 66.73 216.78 8816.65 8734.69 5948431.07 608273.38 3930.50 12.00 322.21 MWD 14800.00 69.14 214.85 8826.04 8744.08 5948412.08 608260.11 3944.06 12.00 323.04 MWD 14825.00 71.57 212.98 8834.45 8752.49 5948392.35 608247.27 3957.19 12.00 323.76 MWD 14850.00 74.02 211.16 8841.84 8759.88 5948371.93 608234.90 3969.86 12.00 324.39 MWD 14875.00 76.48 209.39 8848.21 8766.25 5948350.87 608223.03 3982.05 12.00 324.93 MWD 14900.00 78.96 207.65 8853.53 8771.57 5948329.24 608211.69 3993.71 12.00 325.38 MWD 14925.00 81.44 205.94 8857.78 8775.82 5948307.09 608200.92 4004.81 12.00 325.75 MWD 14950.00 83.93 204.26 8860.96 8779.00 5948284.49 608190.74 4015.33 12.00 326.04 MWD 14954.51 84.38 203.96 8861.42 8779.46 5948280.37 608188.97 4017.16 12.00 326.25 MWD S err -Sun -Draft Co P Y Sperry-Sun Company: BP Amoco Date: 4/8/2004 Time: 16:54:55 Page: 3 Field: Prudhoe. Bay Co-ordinate(NE) Refere nce: WeIL W-09, True North Site: PB W Pad Vertica l (TVD) Reference: $1..96' 82:0 Well: W-09 Section (VS) Reference: Weli (O.OON ,O.OOE,270.OOAzi) Wellpath: Pla n W-09A Deep WO Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool Comme t ft deg deg ft ft ft ft ft deg/100ft deg 15000.00 84.38 203.96 8865.88 8783.92 5948238.73 608171.20 4035.55 0.00 0.00 MWD 15065.77 84.38 203.96 8872.32 8790.36 5948178.53 608145.52 4062.13 0.00 0.00 MWD 15075.00 84.51 205.06 8873.21 8791.25 5948170.12 608141.84 4065.94 12.00 83.58 MWD 15100.00 84.85 208.06 8875.53 8793.57 5948147.69 608131.04 4077.07 12.00 83.48 MWD 15125.00 85.22 211.05 8877.69 8795.73 5948125.85 608119.08 4089.35 12.00 83.20 MWD 15150.00 85.59 214.03 8879.70 8797.74 5948104.65 608106.00 4102.75 12.00 82.94 MWD 15175.00 85.98 217.01 8881.53 8799.57 5948084.15 608091.82 4117.23 12.00 82.70 MWD 15200.00 86.38 219.99 8883.20 8801.24 5948064.40 608076.58 4132.76 12.00 82.48 MWD 15225.00 86.78 222.97 8884.69 8802.73 5948045.47 608060.34 4149.29 12.00 82.28 MWD 15250.00 87.20 225.95 8886.00 8804.04 5948027.39 608043.12 4166.78 12.00 82.11 MWD 15275.00 87.62 228.92 8887.13 8805.17 5948010.23 608024.99 4185.17 12.00 81.95 MWD 15300.00 88.05 231.89 8888.08 8806.12 5947994.03 608005.98 4204.42 12.00 81.82 MWD 15325.00 88.49 234.86 8888.83 8806.87 5947978.83 607986.15 4224.47 12.00 81.70 MWD 15350.00 88.93 237.83 8889.39 8807.43 5947964.67 607965.56 4245.27 12.00 81.61 MWD 15375.00 89.37 240.80 8889.77 8807.81 5947951.59 607944.26 4266.77 12.00 81.55 MWD 15400.00 89.81 243.76 8889.94 8807.98 5947939.64 607922.31 4288.89 12.00 81.50 MWD 15410.41 90.00 245.00 8889.96 8808.00 5947935.00 607912.99 4298.28 12.00 81.48 W-09A T1 L W-09A 15425.00 90.23 246.73 8889.93 8807.97 5947928.84 607899.77 4311.59 12.00 82.35 MWD 15450.00 90.63 249.71 8889.74 8807.78 5947919.22 607876.70 4334.81 12.00 82.36 MWD 15475.00 91.03 252.68 8889.38 8807.42 5947910.81 607853.16 4358.47 12.00 82.38 MWD 15500.00 91.42 255.66 8888.84 8806.88 5947903.64 607829.23 4382.51 12.00 82.42 MWD 15525.00 91.81 258.63 8888.14 8806.18 5947897.72 607804.95 4406.87 12.00 82.48 MWD 15550.00 92.20 261.61 8887.26 8805.30 5947893.06 607780.41 4431.48 12.00 82.57 MWD 15575.00 92.58 264.59 8886.22 8804.26 5947889.69 607755.67 4456.28 12.00 82.67 MWD 15598.73 92.93 267.42 8885.08 8803.12 5947887.69 607732.06 4479.92 12.00 82.80 MWD 15600.00 92.93 267.42 8885.02 8803.06 5947887.61 607730.79 4481.19 0.00 0.00 MWD 15700.00 92.93 267.42 8879.90 8797.94 5947881.62 607631.11 4580.95 0.00 0.00 MWD 15800.00 92.93 267.42 8874.79 8792.83 5947875.64 607531.43 4680.72 0.00 0.00 MWD 15900.00 92.93 267.42 8869.68 8787.72 5947869.65 607431.74 4780.49 0.00 0.00 MWD 15912.06 92.93 267.42 8869.06 8787.10 5947868.93 607419.72 4792.52 0.00 0.00 MWD 15925.00 92.77 268.96 8868.41 8786.45 5947868.33 607406.81 4805.44 12.00 96.00 MWD 15950.00 92.45 271.95 8867.28 8785.32 5947868.15 607381.85 4830.41 12.00 96.08 MWD 15975.00 92.12 274.93 8866.28 8784.32 5947869.28 607356.90 4855.34 12.00 96.21 MWD 15983.94 92.00 276.00 8865.96 8784.00 5947870.00 607347.99 4864.24 12.00 96.33 W-09A T2 M W-09A 16000.00 91.47 277.85 8865.47 8783.51 5947871.70 607332.03 4880.17 12.00 106.06 MWD 16004.80 91.31 278.40 8865.36 8783.40 5947872.30 607327.27 4884.92 11.99 106.11 MWD 16056.75 91.31 278.40 8864.17 8782.21 5947879.13 607275.79 4936.30 0.00 0.00 MWD 16075.00 91.24 280.59 8863.77 8781.81 5947881.87 607257.75 4954.29 12.00 91.70 MWD .16100.00 91.15 283.59 8863.25 8781.29 5947886.74 607233.24 4978.73 12.00 91.74 MWD 16125.00 91.05 286.59 8862.77 8780.81 5947892.89 607209.02 5002.86 12.00 91.81 MWD 16150.00 90.95 289.59 8862.33 8780.37 5947900.29 607185.15 5026.62 12.00 91.86 MWD 16175.00 90.85 292.59 8861.94 8779.98 5947908.94 607161.70 5049.94 12.00 91.92 MWD 16200.00 90.75 295.59 8861.59 8779.63 5947918.80 607138.74 5072.76 12.00 91.96 MWD 16225.00 90.64 298.59 8861.28 8779.32 5947929.84 607116.32 5095.01 12.00 92.01 MWD 16250.00 90.53 301.59 8861.03 8779.07 5947942.05 607094.51 5116.64 12.00 92.04 MWD 16257.62 90.50 302.50 8860.96 8779.00 5947946.00 607087.99 5123.10 12.01 92.07 W-09A T3 I W-09A 16263.06 89.98 302.11 8860.94 8778.98 5947948.83 607083.35 5127.69 12.00 216.98 MWD 16300.00 89.98 302.11 8860.95 8778.99 5947968.00 607051.77 5158.98 0.00 0.00 MWD 16400.00 89.98 302.11 8860.99 8779.03 5948019.88 606966.29 5243.69 0.00 0.00 MWD 16500.00 89.98 302.11 8861.02 8779.06 5948071.76 606880.81 5328.39 0.00 0.00 MWD 16512.61 89.98 302.11 8861.03 8779.07 5948078.30 606870.03 5339.08 0.00 0.00 MWD 16550.00 88.32 303.62 8861.58 8779.62 5948098.11 606838.34 5370.47 6.00 137.64 MWD 16600.00 86.11 305.65 8864.01 8782.05 5948125.87 606796.84 5411.56 6.00 137.61 MWD Sperry-Sun -Draft Co~ Sperry-Sun Company: BP Amoco Date: 4!8/2004 Time: 16:54:55 Paget 4 .Field:. Prudhoe Bay Co-ordinate(NE) Refere nce: Well: W-09, True North Site: PB W Pad Vertica t(TVD) Reference: 8 1.96' 82.0 Well: W-09 Section (VS) Reference: Well (O.OON ,O.OOE,270.OOAzi) Wellpath: Pla n W-09A Deep WO Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool Comme t ft deg deg ft ft ft ft ft deg/100ft deg 16650. 00 83.90 307.68 8868.37 8786.41 5948155.01 606756.45 5451. 51 6.00 137.51 MWD 16700. 00 81.70 309.74 8874.64 8792.68 5948185.44 606717.29 5490. 22 6.00 137.34 MWD 16750. 00 79.51 311.82 8882.80 8800.84 5948217.09 606679.46 5527. 57 6.00 137.08 MWD 16761. 57 79.00 312.30 8884.96 8803.00 5948224.58 606670.91 5536. 01 6.00 136.74 W-09A T4 4 W-09A 16784. 35 77.64 312.39 8889.57 8807.61 5948239.36 606654.20 5552. 50 6.00 176.49 MWD 16786. 16 77.64 312.39 8889.96 8808.00 5948240.53 606652.88 5553. 81 0.00 0.00 W-09A Poly W-09A P 16800. 00 77.64 312.39 8892.92 8810.96 5948249.49 606642.76 5563. 79 0.00 0.00 MWD 16900. 00 77.64 312.39 8914.33 8832.37 5948314.25 606569.64 5635. 94 0.00 0.00 MWD 17000. 00 77.64 312.39 8935.75 8853.79 5948379.01 606496.53 5708. 09 0.00 0.00 MWD 17100. 00 77.64 312.39 8957.16 8875.20 5948443.77 606423.41 5780. 24 0.00 0.00 MWD 17200. 00 77.64 312.39 8978.57 8896.61 5948508.53 606350.29 5852. 39 0.00 0.00 MWD 17300. 00 77.64 312.39 8999.98 8918.02 5948573.29 606277.18 5924. 54 0.00 0.00 MWD 17400. 00 77.64 312.39 9021.40 8939.44 5948638.05 606204.06 5996. 68 0.00 0.00 MWD 17448. 00 ,77.64 312.39 9031.67 8949.71 5948669.13 606168.97 6031. 32 0.00 0.00 3 1 /2" 3 1 /2" 17449. 34 / 77.64 312.39 9031.96 8950.00 5948670.00 606167.99 6032. 28 0.00 0.00 W-09A T5 T W-09A r • • TRAANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~ GrJ ~ 0 9~_ PTD# 20 ~ -,~~-~ __~~ Development Exploration. Service Stratigraphic CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (if API number Production should continue to be reported as last two . (2) digits a function ~of the original API number staled are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (per records, data and logs acquired for the pilot ~ in both hole must be clearly differentiated name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired . for well (name on permit). SPACING The permit is .approved subject ~to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. SCompany Namel assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH All dry ditch sample sets submiried to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and l0' sample intervals through target zones. 00 N , ,,, , , o ~ ~ , NN , , , ~o , ,,,,~... << , .~,~ ,~ ~ ~ ~ ; ~ ~ °~ , .,, „ ~ ~ ~ ~ ~ ~ c o ~ ~ ~ ~ ~ , , o ~ , ,,~ ~, , w , ,,, ,~ ,, ;„ ~ ; ~o , ,„ ,~~ „ ,. ,,, ; ~ o n. , O ; .. ~ ~ ~ ~ ~ ; , O ~ , ~ ~ ~ ; ~ ~ , z , ~ ~ , Q •' a ; m ~ , w ~ v. , ~ ' ' ~ ~ ~ ; ui o 'o m C7 ~ ~ ~~ , ~ O, W ~ ~ ~ ~ ~ ~ ~ ~ N~ } N~ NI N~ y~ N' N~ N~ ~ } } } } }I } } Z NI N1 a~ a~ Nf a~ y d ~ Q ~ ~ ¢' ¢' ¢' ' ~ ~ ~ ~ N~ ~ ¢' ¢' ¢ ¢' m m ' ' N~ N~ m m ' y1 ~ N~ N• H~ N' NI a~ ¢ ai a~, ai a~, a~, ' °; Q ' o; ¢ ¢' ¢' ' ' ¢', T I r; ~; >-; >- z; z; z; z z; z z z r; ~; r; r , r; z r; r, >- }, r, z z z z z z z `\VA` U ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , o a~ c. U ~ ' W ~ m ~ ~ ~ iy GT ar w' y VD ~~ rn ~ ~ ~ a ~ ~ ~, ~ ~ N+ ~ O~ ~ ~ ~ O~ N)~ ~ ~ ~ fl: X~ C ~ O, T ~' w 7 °j O ' 'O' y f0 m , ' ~ m ° 3• ~ t, ' ~ ° ~n ~ Q. - ° ' N ' N ' Z W ~ ~ ._ ~ ° c. ~, Z ° ° c. a m, ar d, °, ~, c rn ~ ~ ~, c °, m c' °, ¢ ° , , ° ° o. rn °, ' t. c v i u i y, ~ a i _ rn o, ~ d ~ ' ' • ' ' ' ' g ~' ~~ - ° u ~ • c- o ~~ ~ ° v m' m c Y m ~ ~' o ~ m ' ' Q, ° ~, m ~ ° ~ m ~~ N T o ~, ~° ~~ ~ N ~ >, o a i c ° ~~ 4 c is r a ~~ ~ ~ , t a c ° ~~ ; _ . `~ 3 c. a ~ • Z' °. ~ °~ 4 3' a • , '= a ~ ~' ~-°' . _ 3' . . 3' •~ E a Q , . , m ~, '° o, m, m, fl, a _ :~, _ -° ~ , °, ~; a h, a °i, m~ ~ ~, c ~~ N' M % , °~ N _ ~ ° aNi °, n 3; °' ~ . ~ >r o; W o o Z . n a, ~ ~, ~ •~, ° -°, ~, 3. 3 ~ ~ a~, .., •~~ ~, ~, '~ .., o' ~ ~ ~ a o y ~ a .Q ~, ~ o, 3; ~, L; ° ~ U ° v m a~ o °; f' o ° ° ° f6' ~~ °' °~ °~ ~ ~' ~' Y, ° °' o ~'' •°' E' a~ fd' E' ~ o a~ °' ' ° .~ C a ~ otS ~ . ° ~' , Q j~ a °, a~; ~° a fl. ° a~, ta' 01 a~' ~ fl. 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To improve the readability of the. Well Nistory 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. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 16 10:38:12 2004 Reel Header Service name .............LISTPE Date .....................04/09/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................04/09/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF 1e lZ~ ~~ Y ~,~~0 ;~J~~k~ ~i~ ~ Cas Cnns.C~mt~a~a~ Andt~rage Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: W-09A API NUMBER: 500292194701 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry-Sun Drilling Services TAPE CREATION DATE: 16-SEP-04 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 7 JOB NUMBER: MW0003126704 MW0003126704 MW0003126704 LOGGING ENGINEER: J. PANTER J. MARTIN J. SACK OPERATOR WITNESS: C. GALLAWAY L. VAUGHAN L. VAUGHAN SURFACE LOCATION SECTION: 21 TOWNSHIP: 11 RANGE: 12 FNL: 1437 FSL: FEL: 1194 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 79.10 GROUND LEVEL: 53.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.750 5.500 14636.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. W-09A EXITS THE W-09A PB1 WELLBORE AT 15745'MD, WITHIN THE MWD RUN 4 INTERVAL. THE W-09A WELLBORE WAS EFFECTED BY MEANS OF AN OPENHOLE SIDETRACK DURING MWD RUN 6. MWD RUN 5 WAS A FAILED ATTEMPT TO SIDETRACK; THEREFORE, NO DATA WERE ACQUIRED. DUE TO A MALFUNCTIONING DEPTH ENCODER ON RUN 6, THERE IS A 52' GAP IN SROP DATA - ALL OF RUN 6. 4. MWD RUNS 3, 4, AND 7 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY(GM)UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 5' DOWNHOLE, PER E-MAIL FROM K. GOONEY (SIS/BP) DATED 26 AUGUST 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 6. MWD RUNS 3, 4, AND 7 REPRESENT WELL W-09A WITH API#: 50-029-21947-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17505'MD/9006'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY {SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 14596.0 17439.5 RPD 14635.5 17449.0 . RPM 14635 17449.0 RPS 14635.5 17449.0 RPX 14635.5 17449.0 ROP 14667.5 17510.0 FET 14667.5 17449.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 14596.0 14591.0 17510.0 17505.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 14591.0 14913.0 MWD 4 14913.0 15745.0 MWD 7 15745.5 17505.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14596 17510 16053 5829 14596 17510 ROP MWD FT/H 0.14 4 46.38 64.2945 5582 14667.5 17510 GR MWD API 19.58 471.3 78.3278 5688 14596 17439.5 RPX MWD OHMM 2.08 2000 14.5483 5628 14635.5 17449 RPS MWD OHMM 1.69 2000 16.756 5628 14635.5 17449 RPM MWD OHMM 0.16 2000 18.3094 5628 14635.5 17449 RPD MWD OHMM 0.1 2000 18.8218 5628 14635.5 17449 FET MWD HOUR 0.78 1 71.91 6.32265 5564 14667.5 17449 First Reading For Entire File..........14596 Last Reading For Entire File...........17510 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number..........~0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14591.0 14841.0 RPD 14630.5 14851.5 RPM 14630.5 14851.5 RPS 14630.5 14851.5 RPX 14630.5 14851.5 FET 14630.5 14851.5 ROP 14662.5 14913.0 LOG HEADER DATA DATE LOGGED: 27-JUL-04 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14913.0 TOP LOG INTERVAL (FT) 14662.0 BOTTOM LOG INTERVAL (FT) 14913.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 55.5 MAXIMUM ANGLE: 61.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.750 DRILLER'S CASING DEPTH (FT) 14636.0 .BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 47.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 6100 • FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .480 62.0 MUD AT MAX CIRCULATING TERMPERATURE: .180 179.7 MUD FILTRATE AT MT: .350 62.0 MUD CAKE AT MT: .520 62.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14591 14913 14752 645 14591 14913 ROP MWD030 FT/H 2.31 72.13 25.2892 502 14662.5 14913 GR MWD030 API 44.9 471.3 151.784 501 14591 14841 RPX MWD030 OHMM 2.08 2000 64.0486 443 14630.5 14851.5 RPS MWD030 OHMM 1.97 17 80.24 54.5426 443 14630.5 14851.5 RPM MWD030 OHMM 0.16 11 39.34 47.3012 443 14630.5 14851.5 RPD MWD030 OHMM 0.1 19 43.81 92.891.8 443 14630.5 14851.5 FET MWD030 HOUR 2.28 5.62 3.9472 443 14630.5 14851.5 First Reading For Entire File..........14591 Last Reading For Entire File...........14913 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14841.5 15745.0 FET 14852.0 15745.0 RPD 14852.0 15745.0 RPM 14852.0 15745.0 RPS 14852.0 15745.0 RPX 14852.0 15745.0 ROP 14913.5 15745.0 LOG HEADER DATA DATE LOGGED: 30-JUL-04 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER {FT) 15745.0 TOP LOG INTERVAL (FT) 14913.0 BOTTOM LOG INTERVAL (FT) 15745.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.2 MAXIMUM ANGLE: 100.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.750 DRILLER'S CASING DEPTH (FT) 14636.0 BOREHOLE CONDITIONS. MUD TYPE: Water Based MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 44.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 6000 FLUID LOSS (C3) 8.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .500 64.0 MUD AT MAX CIRCULATING TERMPERATURE: .180 186.8 MUD FILTRATE AT MT: .600 64.0 MUD CAKE AT MT: .580 64.0 NEUTRON TOOL • • MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14841.5 15745 15293.3 1808 14841.5 15745 ROP MWD040 FT/H 0.82 2 78.77 55.4121 1664 14913.5 15745 GR MWD040 API 20.24 2 61.54 92.9344 1808 14841.5 15745 RPX MWD040 OHMM 2.1 2000 13.5087 1787 14852 15745 RPS MWD040 OHMM 1.69 2000 21.3717 1787 14852 15745 RPM MWD040 OHMM 1.17 2000 28.1784 1787 14852 15745 RPD MWD040 OHMM 1.64 2000 19.2633 1787 14852 15745 FET MWD040 HOUR 1.2 32.71 4.81905 1787 14852 15745 First Reading For Entire File..........14841.5 Last Reading For Entire File...........15745 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 • Date of Generation..... /09/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 15745.5 17444.0 RPM 15745.5 17444.0 RPS 15745.5 17444.0 RPX 15745.5 17444.0 GR 15745.5 17434.5 FET 15745.5 17444.0 ROP 15797.5 17505.0 LOG HEADER DATA DATE LOGGED: 08-AUG-04 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17505.0 TOP LOG INTERVAL (FT) 15745.0 BOTTOM LOG INTERVAL (FT) 17505.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 74.1 MAXIMUM ANGLE: 96.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 14636.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Water Based 8.70 56.0 8.6 6000 8.6 .500 64.0 .160 212.0 .620 64.0 .580 64.0 REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15745.5 17505 16625.3 3520 15745.5 17505 ROP MWD070 FT/H 0.14 446.38 74.3534 3416 15797.5 17505 GR MWD070 API 19.58 447.4 59.6211 3379 15745.5 17434.5 RPX MWD070 OHMM 2.93 1540.44 8.64171 3398 15745.5 17444 RPS MWD070 OHMM 3.03 1965.8 9.40243 3398 15745.5 17444 RPM MWD070 OHMM 3.09 1529.84 9.33961 3398 15745.5 17444 RPD MWD070 OHMM 3.38 1246.51 8.93312 3398 15745.5 17444 FET MWD070 HOUR 0.78 171.91 7.37196 3398 15745.5 17444 First Reading For Entire File..........15745.5 Last Reading For Entire File...........17505 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date.. ...................04/09/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Reel Trailer Service name .............LISTPE Date ................... /09/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF r~ Writing Library. Scientific Technical Services End Of LIS File
