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207-086
By Grace Christianson at 2:24 pm, May 23, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.23 09:53:55 - 08'00' Torin Roschinger (4662) 325-325 JJL 6/3/25 DSR-6/3/25 AOGCC witnessed BOP test to 3500 psi and annular to 2500 psi. X 10-404 A.Dewhurst 16JUN25JLC 6/16/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.06.16 14:00:27 -08'00'06/16/25 RBDMS JSB 061825 Page 1 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Well Name: G-25B API Number: 50-029-21652-02 Current Status: Non-Operable Producer PTD # 207-086 Estimated Start Date: 6/20/2025 Rig: Innovation Reg.Approval Req’std? 10-403, 10-404 Estimated Duration: 7 days Regulatory Contact: Abbie Barker Joseph Lastufka 907-564-4915 (O) 907-777-8400 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Finn Oestgaard 907-350-8420 (M) Current Bottom Hole Pressure: 3,200 psi @ 8,800’ TVD (7.0 ppge, based on offsets) Maximum Expected BHP: 3,400 psi @ 8,800’ TVD (est.) 7.5ppg EMW Max. Anticipated Surface Pressure: 2,520 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP: 140 psi (3/31/2025) H2S Level (Most Recent / Highest): 2ppm 08/16/2020, 25ppm 12/15/2018 History G-25B is a GC1 GD well which most recently produced rich gas from the Sag formation. The well failed an MIT- IA in September 2020 making the well inoperable. A follow up caliper was completed in August 2021 that showed the tubing to be in very poor condition throughout most of the well. The well was a RWO candidate in 2023, but did not make it into the RWO campaign due to limited equipment time. There is tentative rig time available in 2025 to perform this tubing swap. Objective Pull the existing 4.5” tubing and run new 4.5” completion to return well to production. Well Condition Date Pressure Pass? Event Type 7/23/2023 3000psi Y CMIT-IA 3/21/2025 5000psi Y PPPOT-T 3/21/2025 3500psi Y PPPOT-IC Page 2 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Procedure (Page 1 of 3) Pre Rig Steps (Page 1 of 1) Slickline 1. Pull PX plug from sliding sleeve at 9,246’ MD. Eline 2. Set EVO plug at ±9,295’ MD. DHD 3. CMIT-IA to 2600psi. a. CMIT-IA passed to 3000psi on 7/23/2023. Slickline 4. Set junk catcher on top of plug at ±9,295’ MD. 5. Open sliding sleeve at 9,246’ MD. Eline 6. If sliding sleeve does not open, punch 10’ of tubing from ±9,235 – 9,245’ MD. 7. Perform tubing cut of the 4.5” tubing at ±9,269’ MD. Fullbore 8. Confirm circulation between tubing and IA. a. If circulation is not established, contact OE and prepare to perform additional tbg punch. 9. Circulate ±765bbls or ±1.2 IA volumes of 1% KCL down the tubing and up the IA to fluid pack well with 8.5ppg KWF. a. Tubing volume to 9,269’ MD 141 bbls, IA volume 496 bbls. b. Add in soap to KCL to assist in tubing retrieval. 10. Freeze protect to 2100’ MD with diesel. 145 bbls for tubing volume plus IA volume. DHD 11. Bleed WHP to 0psi. Confirm well is dead. Valve Shop 12. Rig up hydraulic lubricator to set and test two way check (TWC). a. Hydraulic lubricator necessary for larger plug size. Page 3 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Procedure (Page 2 of 3) Proposed Rig Work Over Procedure (Page 1 of 2) 13. MIRU Innovation Rig. 14. Nipple down tree and tubing head adaptor. a. A new THA and tubing hanger will be used so that the tree can be reused. 15. Nipple up BOPE. a. configuration top down: i. Annular BOP ii. 3.5” x 6” VBRs iii. Blind rams iv. Integral flow cross 16. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 3.5” x 6” VBRs with 4” work string test joint. e. Test the annular with 4” work string test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 17. Rig up hydraulic lubricator and pull TWC. a. Reservoir should be isolated so pressure is not anticipated. Confirm gauge pressures in field. b. Hydraulic lubricator necessary for larger plug size. 18. Rock out diesel freeze protect with 8.5ppg KCL or seawater. 19. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.5ppg = ±102k #. 20. RU control line spooler for dual SSSV control lines. a. 26 “control line protectors” ran, one every other tubing joint to SSSV at 2,071’ MD. 21. Pull and laydown 4.5” tubing. a. Tubing will not be salvaged. b. Check end of tubing cut to verify left in hole stub does not need to be dressed off. Page 4 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Procedure (Page 3 of 3) Proposed RWO Procedure (Page 2 of 2) 22. Run 4-1/2” gas lifted tubing string with packer completion. a. Torque turn connections. 23. Land hanger and reverse in corrosion inhibited 8.5 ppg KCl or seawater. 24. Drop ball and rod and set packer. Target packer set depth ±9,219’ MD. 25. Perform MIT-T to 3,000 psi and MIT-IA to 2,600 psi for 30 charted minutes. 26. Shear the shear out valve in the top GLM. a. Freeze protect well to 2,100’ with diesel. 145 bbls for tubing volume plus IA volume. 27. Set TWC. 28. ND BOPE. 29. NU tree and tubing head adapter. 30. Test both tree and tubing hanger void to 500psi low/5,000psi high. 31. Rig down Innovation Rig. Post rig valve shop work 32. Pull TWC. Post rig Slickline Work 33. Pull shear valve and run generic gas lift design. 34. Pull Ball and rod and RHC profile. 35. Pull junk catcher from top of EVO plug. 36. Pull EVO plug from ±9,295’ MD. Attachments x Current Wellbore Schematic x Proposed Wellbore Schematic x Proposed BOP Stack x Original Tubing Tally x Tie in log for plug and tubing cut x Sundry Change Form Page 5 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Page 6 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Page 7 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Innovation Rig BOP Schematic Innovation Rig Choke Manifold Original 4.5” Tubing Tally Page 8 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Page 9 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Tie In Log For Plug and Cut (Page 1 of 2) Page 10 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Tie In Log For Plug and Cut (Page 2 of 2) Plug Set 9,295’ MD Proposed Cut 9,269’ MD Page 11 of 11 Tubing Swap RWO Well: G-25B PTD: 207-086 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU G-25B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-086 50-029-21652-02-00 N/A ADL 0028280, 0028304 12653 Surface Intermediate Liner Liner Liner 8979 2745 9687 707 838 2635 9283 13-3/8" 9-5/8" 5-1/2" 3-3/16" 2-3/8" 7960 39 - 2784 37 - 9724 9461 - 10168 9382 - 10220 10018 - 12653 2420 39 - 2685 37 - 8337 8112 - 8722 8044 - 8765 8590 - 8979 Unknown, 12400 2670 4760 6820 11780 9283 4930 6870 7740 11200 9753 - 12610 4-1/2" 12.6# L-80 35 - 94628362 - 8979 Conductor 80 20" 40 - 120 40 - 120 4-1/2" TIW Packer No SSSV Installed 9305, 7978 No SSSV Installed Date: Torin Roschinger Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY 6/10/2023 Current Pools: PRUDHOE OIL Proposed Pools: Prudhoe Oil 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:01 pm, May 23, 2023 323-300 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.23 11:38:05 -08'00' Torin Roschinger (4662) 10-404 2420 BOPE test to 3000 psi. Annular to 2500 psi. SFD 5/30/2023MGR02JUN23 DSR-5/23/23GCW 06/05/2023JLC 6/5/2023 06/05/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.05 14:15:51 -08'00' RBDMS JSB 060623 RWO Tubing Swap G-25B PTD: 207-086 Well Name:G-25B API Number:50-029-21652-02 Current Status:Shut-In – Non-Operable Rig:Thunderbird Estimated Start Date:6/10/2023 Estimated Duration:6days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:207-086 First Call Engineer:Kirsty Glasheen Contact:907-350-4310 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.22 PPGE | offset well recent SBHP Max. Anticipated Surface Pressure:2,420 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:500 psi (FB RU on 8/10/21) Min ID:1.995” @ 10024’ XO to 2-3/8” liner Max Angle:96 Deg @ 12,102’ MD Brief Well Summary: G-25B is a GC1 GD well which most recently produced rich gas from the Sag formation. The well failed an MIT- IA in September 2020 making the well inoperable. It was thought the well had two tubing leaks and one PC leak leak based on an LDL completed in November 2020. A plan was made to repair well integrity via an IA cement job. However, when EL rigged up to the well to complete pre-cement work, it was found that the well had PC integrity, so the IA cement job was cancelled. A follow up caliper was completed in August 2021 that showed the tubing to be in very poor condition throughout most of the well. The well has value remaining in both the Sag and the Ivishak, so a RWO is being pursued to repair the well to operable status. In July 2021, a CIBP set in the liner was milled to re-access Ivishak perforations, but we have not attempted to flow these perforations yet due to the integrity issues of the well. Objective: Pull the existing 4-1/2” tubing. Run new 13-Cr 4-1/2” completion with 4-1/2”x9-5/8” packer to repair tubing leaks. Achieve a passing MIT-IA & MIT-T. Mill CBP. Pre RWO work: Wellhead: 1. PPPOT-T to 5,000 psi. Function all LDS. PPPOT-IC to 3,500 psi. Function all LDS. Fullbore: 1. CMIT-TxIA to 3,000 psi. E-line/Fullbore: 1. Cut tubing ~9,268’ MD. 2. Circulate well with 8.3 ppg KWF + freeze protect. DHD: 1. Bleed WHP to 0 psi Valve Shop: 2. Set and test TWC. 3. Nipple down tree and tubing head adaptor. Inspect threads. 4. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross. RWO Tubing Swap G-25B PTD: 207-086 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). A. Record accumulator pre-charge pressures and chart tests. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8”x 5” VBRs with 4-1/2” test joints. E. Test the annular with 4-1/2” test joint. F. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. RU and pull TWC. 4. RU control line spooler. 5. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.3ppg = 101,829 lbs. 6. Pull 4-1/2” tubing to floor. a. Once control liner is recovered, circulate bottoms up looking for any missing control line bands. RD control line spooler. 7. Run 4-1/2” 13Cr tubing as detailed on proposed schematic. a. Drift overshot with cut joint. b. Torque turn connections. 8. Land Hanger and reverse in corrosion inhibited 8.3 ppg KWF. 9. Drop ball and rod and set packer. 10. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 11. Shear valve in upper GLM. 12. Set TWC. 13. Rig down Thunderbird #1. Post RWO Work: Valve shop: 1. ND BOPE. 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC. 5. Freeze protect to 2000’ with diesel. Slickline: 1. Set LGLVs. 2. Pull Ball and rod and RHC profile. Coil: 1. Mill CIBP from 9,283’ MD. Assess risk of pressure under TWC. Lubricate if necessary. - mgr RWO Tubing Swap G-25B PTD: 207-086 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO Tubing Swap G-25B PTD: 207-086 Figure 1: WBS RWO Tubing Swap G-25B PTD: 207-086 Figure 2: Proposed WBS RWO Tubing Swap G-25B PTD: 207-086 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 23, 2023Subject: Changes to Approved Sundry Procedure for Well G-25BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) “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 By Anne Prysunka at 3:55 pm, Sep 08, 2022 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:207-086 6.API Number:50-029-21652-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028304 Property Designation (Lease Number):10. 8. PBU G-25B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown IA Cement Repair Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12653 Effective Depth MD: L-80 11. 1/1/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8979 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 9321, 7992 No SSSV Installed Date: Liner 2635 2-3/8" 10018 - 12653 8590 - 8979 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 9724 37 - 8337 14. Estimated Date for Commencing Operations: BOP Sketch 39 - 2784 Conductor 7740 Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HB-BP Packer 9753 - 12610 8362 - 8979 4-1/2" 12.6#35 - 9454 Liner 10199 8748 10199 12601 39 - 2685 2670 9-5/8" 5-1/2" Contact Phone:(907)440-7692 Date: 6820 2745 493013-3/8"Surface 4760 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 80 20"40 - 120 Intermediate 9687 6870 Liner 707 9461 - 10168 8112 - 8722 838 3-3/16" 9382 - 10220 8044 - 8765 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:05 am, Dec 02, 2020 320-508 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.12.02 08:52:41 - 09'00' Stan Golis ; ADL0028280 DLB X DSR-12/2/2020DLB12/02/2020 Biennial MIT-T and CMIT TxIA post initial POP. MGR11JAN2021 10-404 MIT-T and CMIT - TxIA tested to 1500 psi. AOGCC to witness. Yeson Required? Comm 1/12/21 dts 1/12/2021 1/12/2021 RBDMS HEW 1/26/2021 G-25 IA Cement Repair REV1 Ops Engineer: Noel Nocas (907) 564-5278 Integrity Engineer: Aras Worthington (907) 564-4763 Ops Manager: Stan Golis (907) 777-8356 Expected Start Date: January 31, 2021 History G-25 is a producer with several tubing leaks and a PC leak discovered during an LDL on 11/18/2020. Tubing leaks are @ 7059’, 7697’, & 9344’ MD. The PC leak is @ 7377’ MD. Status Currently classified as Not Operable by Hilcorp due to the tubing leaks and PC leak. Objective Repair the well with an IA cement job that is estimated to provide an incremental 265 MBO of production over the next several years. Without an IA cement repair the well has no utility in the foreseeable future. The proposed TOC the IA is ~5500’ MD which is ~2200’ TVD below the SC shoe and ~550’ deeper than the estimated top of the UG4 marker @ ~4950’ MD. Post-job Evaluation o MIT-T and CMIT-TxIA o SCMT to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily 2 Procedural steps Slickline 1. Pull DDIC packoff plug. E-Line & Fullbore 1. Set 4-1/2” CBP just above the production packer. 2. PT of tubing/CBP to 1500 psi to verify CBP set. Five minute test, no more than 10% pressure loss. 3. Punch tubing in the middle of the first collar above the CBP. 4. Pump diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel. 5. Set 4-1/2” cement retainer in the joint of tubing above the tubing punch. Coiled Tubing 1. MU retainer stinger 2. RIH and sting into cement retainer. Pumping down CT, establish returns up the IA and pump the following schedule: ¾ 205 bbls 15.8 ppg Class G cement 3. POOH and MU motor and mill 4. Mill out cement retainer, cement, and CBP. Slickline & Fullbore 1. Set plug in tubing @ ~9100’ MD. 2. Log Memory SCMT from ~9100’ MD to surface to identify TOC. 3. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 1500 psi. Ensure 24-hour notice provided for AOGCC. 4. Pull plug from tubing. Well Diagnostics & WIE 1. Update AKIMS and add biennial MIT-T & CMIT-TxIA Cement Calculations ¾ 9-5/8” x 4-1/2” volume from 5500’ – 9320’ MD: 204 BBLS SCMT to AOGCC for review. 3 Production Casing Leak @ ~7380’ MD Tubing Leaks @ ~7697’ & 7059’, & 9344’ MD 4 G-25 Proposed TOC in IA ~5500’MD 5 G-25 Proposed P&A Reservoir Cement Plug Surface Cement Plug + • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 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 ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: 5Cf CL9P n----- 2. 9''2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-086 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21652-02-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU G-25B 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: RECEIVED Total Depth: measured 12653 feet Plugs measured 10199 feet true vertical 8979 feet Junk12601 feet measured JUL 2 4 2017 Effective Depth: measured 10199 feet Packer measured 9305 feet true vertical 8748 feet Packer true vertical 7978 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 40-120 40-120 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9726 9-5/8"47#L-80 37-9763 37-8371 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9753-9813 feet feet 10560-10740 feet 10770-10940 feet 10990-11030 feet 11190-11350 feet 11590-11710 feet 12130-12190 feet 12240-12270 feet 12380-12450 feet 12500-12610 feet True vertical depth: 8362-8413 feet feet 8937-8946 feet 8946-8955 feet 8958-8960 feet 8964-8962 feet 8970-8978 feet 8982-8980 feet 8980-8979 feet 8976-8975 feet 8976-8979 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 35-9462 35-8112 Packers and SSSV(type,measured and 4-1/2"TIW Packer 9305 7978 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): yh.'' �/ Treatment descriptions including volumes used and final pressure: SCANNED DEED N 0 V 0 7 2012 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 504 32081 1 80 958 Subsequent to operation: 445 20967 0 80 1005 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Oshiro,Joleen Contact Name: Oshiro,Joleen Authorized Title: G Pad Engineer/New Wells Delivery PE(GC1/FS3 Contact Email: JOLEEN.OSHIRO@bp.com Authorized Signature: )��-" / Date: ' . !!!! 1 1 Contact Phone: +1 907 564 4606 Form 10-404 Revised 04/2017 rn- /C/G/1 f1_W7 RB DMS (-Kill l 2 7 2017 Submit Original Only • • RECEIVED } .s JUL 2 4 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary July 13, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug for Well G-25B, PTD # 207-086. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • m NO O O o. ON- N N O- CO a0 co O C N N N N d' O3 CON1- N- U `; Oo000D OoLoO M O O) M I� M O) M co O) a0 N rf m COC .4- co co I- co.) O) N LI) N O) O N O LO `Cr CO I's Lf) 00 N N. co O) CO CO co co O I- N. O) O) %- �— N N N CO CO CO CO CO CO CO I� N- C) N co O Lf) d7 Lf) LO I� lj) r O) CO LO M O) O) CO MOO r- LC) r— N 00 CO 00 00 CO O CO N N '- M LO CO LM N x N- N- N- CO M OON N CO N N N O) O) (3) V CoI i i I I i co Q LO O O) CO O I"- O O) CCOO cp N LO _ 1 �t co O) co N M M M - O M ,^ (N co co (3) Lf) in O) O) O O a0 O O O 00 O O O co co � co co t1100 -1 1112J3471112.111 -11 dNfnCnNM �# (C) � 'N N C I— N O in 0ix) a0 " � " ' � (0 � V = Cr? 00 00 M 00 N -a0 N co M Cr) CO CO Ci co c j `_ M M N t O) O) CO CO Lf) LO I� C a0 O I- N O) Ln O CO rn 0) ti O) CO I- No.) J W co 0 � Q C I— W W W W w NVUUUU C.) 0 u_ u_ u_ u_ CtCCCCCC Z Z w w w Q_ W W W W W W m Q D D D 0 H Z Z Z Z Z D (i) (n (/) Cn Z J J J J J F— • 0 w 0 d 0 I— C a) O II 2 H d aw m c 0 U D CI- H w 0_ F- cei co co J N H ZS N- 0 O va 0 >- p 0 2 u v m E .- 0pOv Qw rn w E a) � z Nh I- 0- � � 2w ? 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H CV W U �Ctl ZZIL ' 02 (t) I- CI CI O0E2 _ LL' w 0 ow = 13 00o � 0 a i- `- 2 w E < 0 2 O 2 2 a) O Z w d u) w m p a0 0 J CO 70 J .- H N5 O Z 1 O W O _izU- z2 LI w 0 E 0 w J W 0 0 3 0 : S c O c U d m J a « Z W I- < Q I,- 0O cn H N ra 5 m H c0 0 Q TIS= 6-3/8"CMV • III I WELLHEAIk MoEVOY G SAFETY NOTES: WRL ANGLE >70"@ 10495' " ACTUATOR= BAKER C ��5 B 'ORIGINAL WELLBORE&CTD SIDETRACK"A"NOT OKB ELEV= 72.4' SHOWN BROW 5-1/2"MILLOUT WINDOW'"' BF ELEV= 36.5' 1 KOP= 1775' Max Angle= 96°@ 12102 2071' H4-1/2"SSSV OTIS SSSV NP,D=3.813" Datum MD= 10404' Datum TVD= 8800'SS A 5-1/2'MLLOUT WINDOW(G-25A) 10168'-10173' 20"CONDUCTOR 91.4#,H-40,D=19.124" — 110' 9246' —{4-1/2"OTIS XA SLD SLV,D=3.813" 13-3/8"CSG,72#,L.-80,D=12.347" —I 2785' 9305' HTM/SBR TBG SEAL ASSY,D=4.750" ►�� ►_ 9321' -19-5/8"x 4-1/2"TfW HB-BP A(R,ID=4.750" Minimum ID = 1.996" @ 10024" 9326' HT MLLOUT EXTENSION/ D=6.000" 2.38" XO PUP JOINT 9331' H 7"X 4-1/2"X0,ID=3.958" 9372' H4-1/2"OTIS X NP,D=3.813' 9382' H 3-314"BKR DEPLOY SLV,ID=3.00" 9391' H3-1/2"X 3-3/16"XO PW,D=2,786" 9413' __I4-1/2"OTIS XN NP,MLLED TO 3.80"D 4-1/2"TBG, 12.6#,L-80 AB-MOD, — 9454' 9415' _14-1/2"TAILPPE,D=3.958" BEH ND .0152 bpf,ID=3.958" CT LINER 9414' H E-MD TT LOGGED 03/26/87 TOP OF 5-1/2"LNR H 9461' . 9462' —{5-1/2"TM/SEAL ASSY WO SEALS,D=4.892" 9-5/8"CSG,47#,L-80,D=8.681" H 9724' 10018' H 2.70"BKR DEROY SLV,ID=2.250" 5-1/2"LNR,17#,L-80,.0152 bpf,D=4.892" H 10168' 3-3/16"LNR 6.2#,L-80 TCI,.0076 bpf,D=2.80" H 10220' 33!16"WHIPSTOCK(07/25/09) H 10220' 3-3/16"MLLOIJT WINDOW(G-258) 10220 - 10225' PERFORATION SUMMARY REF LOG: SW5 CNL/GR ON 08/08/07 10199 ]-1,2-3/8"WFD CUP(06/14/17)1 ANGLE AT TOP FERE: 310 @ 9753' Note:Refer to Production DB for historical perf data SIZE SPF NTERVAL OFi'VSHO SO2 T SQZ �f 6 9753-9813 O 11/01/16 6 2" 6 10560-10740 S 08/11/07 11/13/13 2" 6 10770-10940 C 08/11/07 I ` PBTD — 12614' 2" 6 10990-11030 C 08/11/07 2" 6 11190- 11350 C 08/11/07 2" 6 11590- 11710 C 08/11/07 2" 6 12130-12190 C 08/11/07 I FISIt MILLED CBP& ? 2" 6 12240-12270 C 08/11/07 ! �� ����� PUSHED TO '���� 2" 6 12380-12450 C 08/11/07 BOTTOM(11/25/13) 2" 6 12500-12610 C 08/11/07 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,D=1.995" H 12653' DATE REV BY COMMENTS DATE REV BY COMEffS PRUDHOE BAY INT 12/04/86 AUDI 2 ORIGINAL COMPLETION 12/04/13 LWJMD MILLED CMF/CBP DH(11/25/13) WRL. G-25B 05/29/01 NORDIC 1 CTD SIDETRACK(G-25A) 11/07/16 MRLYJMD ADPERFS(11/01/16) PERMIT No-"`2070860 08/12/07 NORIJC 1 CTD SIDETRACK(G-256) 06/22/17 BTN/JMD SET CBP(06/14/17) 1 API No: 50-029-21652-02 05/24/09 CAll PJC DRLG GRAFT CORRECTIONS_ SEC 12,T11 N,R14E,2617'FNL&1973'FEL 10/30/12 DOK/JMD TREE C/O(10/21/12) 1 11/18/13 SFRDIJMD SET CEP/SQUEEZED(11/13/13) BP Exploration(Alaska) STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIAION 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 Ed Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-086 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21652-02-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU G-25B 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: RErEIVED Total Depth: measured 12653 feet Plugs measured feet 3 NOV 0 f1 true vertical 8979 feet Junk measured 12601 feet N 2016 Effective Depth: measured 12614 feet Packer measured 9305 feet true vertical 8979 feet Packer true vertical 7978 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 40-120 40-120 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9726 9-5/8"47#L-80 37-9763 37-8371 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9753-9813 feet feet 10560-10740 feet 10770-10940 feet 10990-11030 feet 11190-11350 feet 11590-11710 feet 12130-12190 feet 12240-12270 feet 12380-12450 feet 12500-12610 feet True vertical depth: 8362-8413 feet feet 8937-8946 feet 8946-8955 feet 8958-8960 feet 8964-8962 feet 8970-8978 feet 8982-8980 feet 8980-8979 feet 8976-8975 feet 8976-8979 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 35-9462 35-8112 Packers and SSSV(type,measured and 4-1/2"TIW Packer 9305 7978 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): r�� Treatment descriptions including volumes used and final pressure: SCANNED Iv AR r .LJ t 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 250 19443 1 60 656 Subsequent to operation: 816 37085 8 100 1261 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I1 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature iPhone +1 907 564 4424 Date 11/30/16 Form 10-404 Revised 5/2015 V tt 74 t L l 7 RBDMS DMS 1s Submit Original Only �,/;� R 'V' SEC - 6 2076 • • w No p o m NO N NO (O co 000 O O) CO cO N- Lo coCb LC 0 N N N (D ti U 0 0 0 I- 0 0 0 (O O p "" coO 3 O) M O) co I-- N m CO (O I- 7 000 p I"- O cY CV LO N O) O N LC) V CO N- LC) CO N I� CO N- 01 0 0 CO O h I"- CA O N N CO CO CO CO 00 CO 00 H N- O) N M O I.0 CA in . ti LC) O) CO Ln CO 07 CO M O O r- LC) I- CO r- N CO CO CO CO CO a) p M N co L[) co MO ( i 0 r CO CO 6) N CO Ln N CO r- M O O N N N N (3) O) C\ " O V i1 1 1 1 1 1 1 1 1 1 41.4 M Q N MN C\I (Ni C° O O) 0 co O) 0 to coCA I-- co co co ct 0 N co 0 N O) 0) 6) O 3a Ln p p 000600O co co C> U J O J J J J J J �I J .N N N -0 CN N N (NO CO CO Eo Eo -- - - - - (c) U 0\0 N CO N FDDO M o\o M M 0\O N N co co co (� co co MN t p CO CV CV CO LC) LC) N- CO N- C CO CD N O LC ) O co CA J O) co ~ N W IMCHLULLILLI 0— ZoUUU � C7 Ulaitail¢iZ Z ctr W W W W W W m O » DF- zzzzzD C) co (n Z J J J J J I- • . 2 N- 0 J O ( N o inN- 0 O (n d- a OO N Z (` N- ' �\ d7 (n ,- Z O O © 'I) Q II Q II Q O U' 202 w ✓ � UF- 10_ ,,, 0_ < W � 2002aa W w W L.L a. UU d Q o W Q W O W O o O 0 C cd ( mw _10 * Z J J J — Q * (n c O w W 2 U 2 V U Q LU _10 Q 0 * Cl_ Li_ rx v - O Y ° Z Z _ W N W N U 0 ~ - C Om W - h- W 0404Wa Z 2 W Q F- O II O II w Q co IP O W N. 0O2 a co CO coQ 0 i < Off- 0mJ 0 ; F ; F D > Q E w 7 Q Q F- F- F- < W u_ 000022 W W ~ 2 +�Z Z U) > w Z J Z J U w w m 0 Mu) E W W w < > d F U F U U) W 2 72 _ U U d N c) _ b oaalLb LL1 -) -) 0 < cc W W ono O ZwJ Z •Wr_iwri CO < ',V"-. 11). N N J W J 00 I� O m oesot � j (n � poem - O Q W • CO * F- F d _' Q _W J Z u_.,, LLZm � w °° F 0 O " 0otfa - J M _ M W > oo �= W � 0 `� X ° xr- Oz O U w C7 z * W rn rn F- w cn Ce W 2D � � 00 JacoJccoJQCt (AJ >+ Z U � O 5 122 �O W Q � UU ( _Iwp. U O O2C Ww oWUWWo W W Lo & FC2Hw ow Z2000- 1- a 10Z0ZCL >H_ Lo I— NW 11 Q Q Z Q Q O II j Q > Q 0 > N d 2 N N Q a 0 Ill2 >_ H U 2 J X X CO 2 0 J E W E ir O d O m Wco � ° � c) m wQ � ON000 Jm Z z O z z O 1 z 11_ " U_ __10 -1 °3 Z rx J z < 0 m * < < C" < < *" * 2 w 2 W J z * w * CLCL �WCL * * zCLWw' da �W * f w Q Q CS CS cfl >- (N o o N _ N co -- m F- O U a EVOY ACTLaUTORii BAKER C V _2 5 B ...ORIGINAL WELLBORE&CTD SIDETRACK A"NOT OKk3.ELEV= 72 4' SHOWN BELOW 5-1/2"MILLOUT WINDOW"' BF.ELEV= 36.5' 1 1 KOP= ...._. _ 1775' Max Angle= 96°@ 12102' 0 2071'7-14-1/2"SSSV OTIS SSSV NP,D=3.813" Datum MD= 10404' _ •atumTVD= _ 8800 SS 5-1/2"ML LOUT WINDOW(G-25A) 10168'-10173' 20"CONDUCTOR 91.4#,1-1-40,D=19.124'J— 110'v_, ! ! 9246' 1—4-1/2"OTIS XA SLD SLV,D=3.813" I 13-3/8"CSG,72#,L-80,D=12.347" H 2785' r 9305' --(TNV SBR TBG SEAL ASSY,D=4.750" QI 9321' H9-5/8"x 4-1/2"TM/HB-BP NKR,ID=4.750' Minimum ID = 1.995" @ 10024" 9326' H 7"MILLOUT EXTENSION,D=6.000' 2.38" XO PUP JOINT 9331' --{TX4-1/2"xO,D=3.958" 9372' —4-1/2"OT1S X NP,ID=3.813" I 9382' H3-3/4"BKR DEPLOY SLV,1D=3.00" 9391' —13-1/2"X 3-3/16"XO FIN,D=2.786" 9413' _14-1/2"OTE XN NP,MLLED TO 3.80"D 1 4-1/2"TBG, 12.6#,L-80 AB-MOD, -L 9454' I L 9415' I_14-1/2'TAILPPE,D=3.958" BEI-IND .0152 bpf,D=3.958" J CT LINER i i 9414' I EMD TT LOGGED 03/26/87 TOP OF 5-112"LNR 9461' ® 9467 —5-1/2"TIW SEAL ASSY WO SEALS,D=4.892" I 9-5/8"CSG,47#,L-80,ID=8.681" —I 9724' MI 10018' - 2.70'BKR DEPLOY SLV,D=2250' 5-1/2"LNR,17#,L-80,.0152 bpf,D=4.892" --I 10168' H 3-3/16"LW,6.2#,L-80 TC>I,.0076 bpf,ID=2.80" --i- 10220' 33/16"WHPSTOCK(07/25/09) —+ 10220' 3-3/16"MILLOUT WINDOW(G-25B) 10220'-10225' PERFORATION SUMMARY I REF LOG: SWS CNJ GR ON 08/08/07 ANGLE AT TOP PERE: 31°@ 9753' Nate:Refer to Production DB for historical pert data SIZE SPF INTERVAL OPNISOZ SHOT SQZ 2" 6 9753-9813 0 11/01/16 2" 6 10560-10740 S 08/11/07 11/13/13 r 6 10770-10940 0 08/11/07 ' ` — 2" 6 10990-11030 0 08/11/07 FETID — 12614' 2" 6 11190-11350 0 08/11/07 ` 2" 6 11590-11710 0 08/11/07 2" 6 12130-12190 0 08/11/07 ' FISIt MLLE)CEP 8 ? `,�► 2" 6 12240-12270 0 08/11/07 PUSHTO '"1,��•. 2" 6 12380-12450 0 08/11/07 '�,..4, ED BOTTOM(11125113) 2" 6 12500-12610 0 08/11/07 2-3/8"LW,4.7#,L-80 STL,.0039 bpf,D=1.995" H 12653' f DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT_____________ 12/04/86 AUDI 2 ORIGINAL COMPLETION _ 12/04/13 LLI/JMD MILLED CMT/CEP DH(11/25/13) WELL: G-25B 05/29/01 NORDIC 1 CTD SIDETRACK(G-25A) 11/07/16 MRLYJMD ADPERFS(11/01/16) PERMT ND:"070860 08/12/07 NORDIC 1 CTD SIDETRACK(G-25B) API No: 50-029-21652-02 05/24/09 CAZ/PJC DRLG DRAFT CORRECTIONS SEC 12,T11 N,R14E,261T FT L&1973'FEL 10/30/12 DOK/JMD !Nth C1O(10/21/12) 11/18/13 SRD/JMD SET CSPISODEEZZE)(11/13/13) BP Exploration(Alaska) ~ ~ ~~~~ ~ ~~ ~~~~ ~~~ ~~~~~~ ~~~~~ ~~~~~ k ~ ~ ~~~~~~ °~9~is page ~dentifiies t~ose 9ter~as t~a~t ~ere ~o~ ~ca~r~ed ~~~i~ag ~t~e i~itia~ pr~d~c~ior~ ~~~ra~i~g ~~a~~. They are avaalable ~r~ the ~rigir~al ~ile, ~ag/ be scan~ed during a special r~scan ~ctivAty ~~ a~e viewable ~y direct i~spection of ~he file, ~ ~ ~- ~ ~~ ell ~I~s~oa~y ~ile ~deratofier ~C~BIiIZl97~ (done) ^°fwo-sided ~II II'I II II ~I I II ~~~ ^ Rescan Needed II I II'I I~ II I I~II II~ RES (V DLGITAL DAT~- C lor Items: i~'Diskettes, No. ~ v Greyscale Items: ~ ^ Other, No/Type: ^ Poor Quality Originals: ~ Other: OVERSiZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~,~ Q ^ Other:: ~s~ Pro "ect Proofin ! 9 II I I I~I () I I III I I~II BY: Maria Date: ~~ Q /s! ti i P x 30 ~ =~~ ~ ''' + O~~ = TOTAL PAGES on repara ng Scann _ . _ ~~~/// ~~~ ~ (Count does not include cover sheet} BY: Maria ~ Date: ~~ ~' ~ , ~ ~ ~S~ _ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES NO BY: Maria Date: /~,~ /~q ~Sl V V~, ~ ~ ~f ! / Stage 1 !f NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scanning is complete at this point unless rescanning is required. I) I II'I II I II I) I I III l~eScanned ~II (III~II~III ~I~II BY: Maria Date: Isl Comments about this file: Quality Checked II I II II~I ~II II'I ~II 10l6/2005 Well History File Cover Page.doc STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMIV _iON DEC 19 26 • REPORT OF SUNDRY WELL OPERATIONS (-w� 1.Operations Abandon ❑ Repair Well Li Plug Perforations Lj ,q.• Perforate ❑ Other Li c O�°`CO Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 . Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Q Exploratory ❑ 207-086-0 _ 3.Address: P.O.Box 196612 StratigraphiC Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21652-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028304 • PBU G-25B . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 12653 feet Plugs measured None feet true vertical 8979.1 feet Junk measured 12601 feet Effective Depth measured 12614 feet Packer measured 9308 feet true vertical 8979.13 feet true vertical 7981.01 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 36-116 36-116 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 9688 9-5/8"47#L-80 34-9722 34-8335.5 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10560-10740 feet 10770-10940 feet 10990-11030 feet 11190-11350 feet 11590-11710 feet 12130-12190 feet 12240-12270 feet 12380-12450 feet 12500-12610 feet True Vertical depth 8936.8-8945.82 feet 8946.16-8954.53 feet 8957.79-8960.24 feet 8963.89-8962 feet 8970.25-8977.72 feet 8981.58-8980.04 feet 8980.08-8979.18 feet 8976.4-8974.58 feet 8975.8-8979.14 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 37-9465 37-8115.39 Packers and SSSV(type,measured and true vertical depth) 4-1/2"TIW Packer 9308 7981.01 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Acid Stim: 10,560'-12,590' Cement Squeeze: 10,560'-10,740' SEAMED ,IAi'v .1 ? L y Treatment descriptions including volumes used and final pressure: Acid Stim:24 Bbls 12%HCL, 1,756 psi;Cement Squeeze: 133 Bbls OrganoSeal,45 Bbls Squeeze Crete,3000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 323 20497 2 0 1081 Subsequent to operation: 0 0 0 0 0 14.Attachments: •15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Ell - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0• Gas ❑ WDSPIJj GSTOR 0 WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Gar, _Catron( BP.Com Printed Name Garry Catron Title PDC PE Signature f Phone 564-4424 Date 12/18/2013 V RT M DEC 2 0 2 " 175//4 Form 10-404 Revised 10/2012 91//”' Submit Original Only w 0. M 000000 ar t O CO N I� • CO o O� CO Tr N N N- (.3 000000 3 NOOMCDTr m OD I' CC) CC) Tr 00 NI- co ▪ N � N M • CO• Cq UP op OD CD CD CD 0) M CD CD 00 OD CO a0 a0 (N 00 t() Tr M OD 0) I N N N- CO NI" LO C'`) a _N 00) co co 10 Co CD CO 0• ° OD CD 000 0 N (c) tM N U) a) Lc) � co N � CO r- 00) co Tr a) � � � 0) '— (NI 0) 0 M ao CO mwa) � ov � ml- a) N � � � OMMO) C O 7 Q O \ t- 0 co 0 0 0 0 ° 0 C) U oJD J OJO (� co J OJ0 CU -a M N N N_ C N "cr 0 0) CO I` I`7. U NVCVCOCVpO -a\0 ° ° N N - M c? to c7 M Lo N O) 2 .c C0030) NCD (0 ((OCDMTr aDCO J N O 0 ' ti CC Z • O O Co C) U U O V (° inCLW CCCLOlailai ? 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I NOTES: MIL ANGLE >70°c 10495' " ACTUATOR= BAKER C 'ORIGINAL WELLBORE&CTD SIDETRACK"A"NOT OKt3.HIV 72 4' SHOWN BELOW 5-1/2"MILLOUT WINDOW"" BF.ELEV= 36.5' I 1 KOP= 1775' Max Angle= 96° 12107 2071' H4-1/2"SSSV OTIS SSSV NP,D=3.813" I Datum ND ° 10404' Datum TVD= 8800'SS 5-1/2'MLLOUT WNDOW(G-25A) 10168'-10173' 20"C ONDUCTOR,91.4#,H-40,0=19.124" 110' ' i 9246' H4-112"OTIS XA SLD SLV,D=3.813" 13-3/8"CSG,72#,L-80,D=12.347' H 2785' 9305' —1TIW SBR TBG SEAL ASSY,D=4.750" •'.4 E�� 9321' H9-5/8"x 4-1/2"TNV I43-BP PKR,ID=4.750.1 Minimum ID = 1.996" @ 10024" L 9326" —17"FALLOUT EXTENSION,D=6.000" I 2.38" XD PUP JOINT 9331' H7"x 4-1/2"x0,0=3.958" 9372' —4-1/2"OTIS X MP,D=3.813' J I 9382' H3-314"BKR DEPLOY SLV,D=3.00" I 9391' —I3-1/2"X 3-3/16"XO RN,ID=2.786" I 9413' 1_14-1/2'OTIS XN NP,MILLED TO 3.80"D 4-1/2"TBG,12.6#,L-80 AB-MOD, — 9454' \ 9415` 1_14-1/2'TAILPIPE,E,D=3.958" BND A152 bpf,D=3.958" \ 1 9414' I--EL.WD TT LOGGED 03/26/87 CT LINER TOP OF 5-112"LNR - 9461• I 9462' H5-1/2"TNV SEAL ASSY WO SEALS,D=4.892' 9-5/8"CSG,47#,L-80,0=8.681' --I 9724 • 10018' -12.70"BKR DB'LOY SLV,D=2.250' 5-1/2"LNR,17#,L-80,.0152 bpf,D=4.892" I— 10168' E— 3-3/16"LNR,6.2#,L-80 TC1,.0076 bpf,D=2.80" ,—I 10220' 3-3t16"VVh6'STOCAC(07/25/09) —I 10220' 3-3/16"FALLOUT VOIDOW(G-2513) 10220'-10225' PERFORATION SUMMARY REF LOG: SWS CPU GR ON 08/08407 ANGLE AT TOP PERF: 89°@ 10770' Note:Refer to Roduction DB for historical pert data SIZE SPF INTERVAL OPWSQZ SHOT SOZ 2" 6 10560-10740 S 08/11/07 11/13/13 2" 6 10770-10940 0 08/11/07 2' 6 10990-11030 0 08/11/07 I ` 2" 6 11190-11350 0 08/11/07 PBTD — 12614" 2" 6 11590-11710 0 08/11/07 ` 2" 6 12130-12190 0 08/11/07 44%ip 2" 6 12240-12270 0 08/11/07 I FISH WILLED CEP& ? 2" 6 12380-12450 0 08/11/07 Kt PUSf-�TO '41*' 2" 6 12500-12610 0 08/11/07 '�� BOTTOM(11!25!13) 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,D=1.995" H 12653' DATE REV BY COMuBJTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/04/86 AUDI 2 ORIGINAL COMPLETION 12/04/13 LLVJMD PALLED CM/CEP OH(11/25/13) WELL: G-25B 05/29/01 NORDIC 1 CTD SIDETRACK(G-25A) PB2MT No: 2070860 08/12/07 NORDIC 1 CTD SIDETRACK(G-25B) API No: 50-029-21652-02 05/24/09 CAZ/PJC DRLG DRAFT CORRECTIONS SEC 12,T11 N,R14E,2617'FNL&1973'FE.. 10/30/12 DOK/JMD TREE C/O(10/21/12) 11/18/13 SRD/JMD SET CBR'SQUEEZZ®(11/13/13) BP Exploration(Alaska) DATE: 23- Aug -12 Stephanie Pacillo TRANS#: 6044 Data Delivery Services Technician 17IVlakanaK Bender Scbiumberger Oilfield Services -4. ° ' Natural Resources Technician U. WIRELINE Alaska Oil & Gas Conservation Commission 2525 Gambell St, Ste, 400 3 3 W . 7" Ave , Suite 1 00 I- n choracre, i:-.K ti -; .= 7.0 Anchorage, AK 99503 . N: Office: (907) 273 -1770 `. <� ELL` SERVICE ; , " RESERV CNL MECH LOG DESCRIPTION DATE 8(W COLOR CD's NAME ORDER # DIST DIST DIST DIST LQGGfD PRINTS PRINTS G -25B BAUJ•00145 X MEMORY IPROF 25- Jul -12 1 1 CD IF E -09C 6C00.00024 _ X _ PPROF/IPROF MCNL 12- Jul -12 1 1 CD G -0413 C6O0.00025 X MEMORY PPROF / IPROF MCNL 10- Jul -12 1 1 CD _ K -10C BAUJ -00138 X MEMORY PPROF W/ GHOST 29-Jun-12 1 1 CD V - 202 C000.00031 X MEMORY LDL 22- Jul -12 1 1 CD Z -06A CSXI.00016 X MEMORY PPROF 13- Jul -12 1 1 CD W - 02A C3XI.00018 X MEMORY LEAK DETECTION 15- Jul -12 1 1 CD 14 -33A CSXI- 00006 X MEMORY PPROF 13- Jun -12 1 1 CD 05 -23B BAUJ -00140 X MEMORY PPROF W/ GHOST OST 3- Jul -12 1 1 CD H -09 C2JC -00027 X IPROF 23- Jun -12 1 1 CD MPS-0113 EZ81.00021 X PDC CORRELATION 9- Jul -12 1 1 CD _ MPS -01B BZ8I.00021 _ X USIT 11- Jul -12 1 1 CD 05 -22B BCRC -00196 X MEMORY PPROF 9- JuI -12 1 1 CD P1.06 SYS-4.00048 X XI=LOW WI IBP SET RECORD 20- Jun -12 1 1 CD L1.09 BVYC -00041 X PPROF 16- Jul -12 1 1 CD _ L1 -21 _ APBSURVE _. . X. PPROF 26- Jun -12 1 1 CD • N -12 APBSURVEEL X PPROF 19- Jul -12 1 1 CD 05 -22B BCRC -00196 _ X MEMORY PPROF W/ GHOST 9- Jul -12 1 1 CD 18 -25A 11996389 X SCMT 13- Mar-08 1 1 CD G -25B BAUJ -00145 __ _ X _ MEMORY PPROF W/ GHOST 24- Jul -12 1 1 CD UJ - 00142 Z -13A BA MEMORY LEAK 7- Jul -12 1 1 CD X Please return a signed copy to: Please return a signed copy'to: BP PDC LR2 -1 4 , 7 01? s: DCS 2525 Gambell St, Suite 400 900 E Benson Blvd 5i4.:_' ` ` Anchorage AK 99503 Anchorage AK 99508 K\ 1\ 04 --S h. 0 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg ` DR 0 2012 Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue 107 5- Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB G -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, o� Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G-01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G-02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G-03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-048 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G-09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 I G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 _ 4.0 0.6 _ 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 s4 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA _ 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA _ 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 ~ - ~. r z ~''= ~ ~, .,,~ „~.~ ~~g ~- a ~ _ ~ ~.r + ~y ~, ~ - ..#, ~,~~ ~ ~w .. ~ iii";. „~9`"', ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1 ~ ~y~ DATA SUBMITTAL COMPLIANCE REPORT 7/20I2009 Permit to Drill 2070860 Well Name/No. PRUDHOE BAY UNIT G-25B Operator BP EXPLORATION (ALASF(A) INC API No. 50-029-21652-02-00 MD 12653 ND 8979 Completion Date 8/12/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~/ Mud Log No Samples No Directional Survey es DATA INFORMATIDN Types Electric or Other Logs Run: MWD DIR, GR, RES, MCNL / GR / CCL (data taken from Logs Portion of Master Well Data Maint Weli 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 D Asc Directional Survey 0 12653 Open 9/25/2007 Rpt Directional Survey 0 12653 Open 9/25/2007 D Asc Directional Survey 0 11549 Open 9/25/2007 PB 1 Rp Djrectional Survey 0 11549 Open 9/25/2007 PB 1 D C Las 15772' Induction/Resistivity 9707 12653 Open 12/3/2007 ATR, RPM, GR, RAM, D C Las 15776+~Induction/Resistivity 9707; 11548 Open 12/14/2007 ROP, RPD w/PDF graphics PB1 ATR, RPM, GR, RAM, ROP, RPD w/PDF graphics " pt LIS Verification 10220 12653 Open 1/17/2008 LIS Veri, GR, ROP, RAS, RPD, RPS D C Lis 15840 ~nduction/Resistivity 10220 12653 Open 1/17/2008 LIS Veri, GR, ROP, RAS, RPD, RPS w/Meta and TIF graphics og Gamma Ray 25 Blu 10220 12653 Open 1/17/2008 MD GR 4-Aug-2007 og Induction/Resistivity 25 Blu 10220 12653 Open 1/17/2008 MD GR, MPR 4 Aug-2007 ~og Induction/Resistivity 25 Blu 10220 12653 Open 1/17/2008 NO GR, MPR 4-Aug-2007 pt LIS Verification 10220 11549 Open 1/17/2008 P61 LIS Veri, GR, ROP, D C Lis 15841~Induction/Resistivity 10220 11549 Open 1/17/2008 RAS, RPD, RPS P61 LIS Veri, GR, ROP, RAS, RPD, RPS w/EMF and Tif graphics og Gamma Ray 25 Blu 10220 11549 Open 1/17/2008 P61 MD GR 29-Ju1-2007 ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/20/2009 Permit to Drill 2070860 Well Name/No. PRUDHOE BAY UNIT G-25B Operator BP EXPLORATION (ALASK~ INC API No. 50-029-21652-02-00 MD 12653 ND 8979 Completion Date 8/12/2007 Completion Status 1-OIL Current Status 1-OIL UIC N og Induction/Resistivity 25 Blu 10220 11549 Open 1/17/2008 P61 MD GR MPR 29-Ju1- 2007 og Induction/Resistivity 25 Blu 10220 11549 Open 1/17/2008 P61 ND GR MPR 29-Ju1- 2007 Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y I~ Chips Received? 'f7'N" Analysis ~ Received? Sample Set Sent Received Number Comments Daily History Received? Y ~ Formation Tops ~ ~ Comments: Compliance Reviewed By: Date: ~ ~, 1~ J Transmittal Form ri~r BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99502 Attention: Christine Mahnken Reference: G25BPB1 ~ Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image fites) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log 1 blueline - NIl'R/Directional TVD Log 1 blueline - MPR/Directional Measured Depth Log Sent By: Deepa Jog,l~kar Date. J ~1~~5,'~2~6,~~ , ~ , '~- , ~ _ J, ~ _ ~~ :~~_ ~, ~ °~ - Received By: ~ ~` ~--~---~ Date: j(~}`~ ~ ~ '~,~5}=~ ..~ ~T,~t~1~~7J :''L~ ` - I ~ ~ ,:i1~V3$t~ ~~/`~3 ~ vt~ =,1¢,V '3. a~..i .2l..~ . I ~ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE~ ~~` ~~~'~YNG ' ~ . . I_ , ; _.. OR FAXING YOUR COPY ' ' FAX: (907) 267-6623 ~ ~ Baker Hughes INTEQ j ~ 7260 Homer Drive ° Anchorage, Alaska ' ~~~.--(~`If~o ~(~ `G~~~ 99518 ~I Direct: (907) 267-6612 ; FAX: (907) 267-6623 .. ~ , ~ Transmittal Form ~ ~~.~ -~.r_ ~~, ~~ BAKER HUGNES ~ , INTEQ To: AOGCC 333 West 7~` Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: G25B Anchorage GEOScience Center ~ =- ; Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log 1 blueline - NIPR/Directional TVD Log 1 blueline - MPR/Directional Measured Depth Log LAC Job#: 1491558 Sent By: Deepa Jo lekar 'r ~'` _ - Received By: ~~ ~/ ~ ; ~ _~~-~~ ~' ~~ ~~ Dat~ R~~2~~'8 _ n `~~~~~ ~ ' ~'LCP ` Date: `" t ~, c f '3,~~St~.., i~t iit ..'3 ~ „f1! ~ .,,.~ .. ~ >, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive ~d~ p`~ Anchorage, Alaska 99518 ~ ;~~,~~~j Direct: (907) 267-6612 FAX: (907) 267-6623 i • ,F ' ..._ i ~ ~ ~ --: __ : ___ ,_, _ ~~ : ~ y _ _~ ~.-~---- ; ' ~~.:, .. , ~_ ~ _ ~ - - ~- T- - , ~ "_ , : \ '.,.. I _.. . ,_ =i ~, _.. _, ~ ; ,_ _,, ,, ~ , _. ;~, I , BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) t you nave any questions, please contact llouglas llortcri at trie Ylll: at Jb4-4y /3 Contents G-25BP61 ~o~- -o~SC~ "'~ 15~~~ X-30A ~o'~-p3~ ~5 ~~~ X-30AP61 ~o'~-O'~-~ 1 ~~ ~ X-30APB2 ~p~.~~ t S~'~ f Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken ; ~ ~:` s ~,~ ~ ~- 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 _. ~ =~ ~' ~ ~~ ~~ ~;5 a~~ ~=~~' „ _ -' ~ ~~ __. ;~~ ,,,~; t, ~ ~ ~"~z.. . ~ , ~~ ?~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date i 1-30-2007 Transmittal Number:92922 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have Contents 05-286 ~oc,-o ~°~ ~ I~-}(~~f 05-286PB1 ~o(,-v~9 ~ 1 S~"~~ 1-39A/N-16~~--!~~ ~~~(oa 1-39A/PB1 ~uc~- ~ b~ - 5$~3 15-12B -~~ /aP i C-32C ~o ~- t 3q ~+- , S~ 6` E-11B -no ~4P1 E-11 BL1 ~o~--o~~ ~ ~~ -~.;~~ E-11BL1-01 av~-UL~~~~ ~~ E-11 BL1 PB1 ~o-~-o~, r~ ~5-~-~ v E-11BLiPB2~U~}-p~! ~~$~;,~ E-19B 2a'~-o'~~ # i ~-~~ ~ G-25B av~--b ~lo ~' ! S~~-~ NK-14A-~ aa~-o3 - ~ ~~-~-3 NK-14AP61 ~0~-03~ ~t r~~~~.~ NK-61A ~6(o-p3~ ~ t5~~ S contact llou~las llortch at the YllC: at 564-4y%:3 ~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 • i ~~ ~~ BAKER~ NUGNES INTEQ To Whom It May Concern: 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 September 20, 2007 Please find enclosed directional survey data for the following wells: E-11BLIPBI E-19B E-llBL1PB2 E-11BL1 E-11BL1-Ol G-25BPB 1 02-16CPB 1 G-25B 02-16C OS-28BPB1 OS-28B Enclosed for each well is: 2ea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey ~les Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. ~~ ,;'; ~, j~ ~ r RECEIVED BY:~~~% ,. ~' a''~`'!~'`~ , State of Alaska AOGCC DATE: a ~ ~~~a° " ~~ `~~ `-~~° Cc: State of Alaska, AOGCC a,c~~-~~ ~ ~ ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, September 17, 2007 3:24 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU G-25B / PTD # 207-086 H~ Art, Pfease reference the following weli: WeU Name: PBU G-25B Permit #: 207-086 API #: 50-029-21652-02-00 Top PerF MD: 10560' Bottom PerF MD: 12610' This well began Praduction on September 15, 2007 Method of Operations is: Flowing Date of Test: Q9/16/07 Hours Tested: 6 24-Hour Rate / Oil-Bbl: 1,348 24-Hour Rate / Gas-Mcf: 9,088 24-Hour Rate / Water-Bbl: 12 Test Rate / Oil-Bbl: 337 Test Rate / Gas-Mcf: 2,272 Test Rate / Water-Bbl: 3 Choke Size: 83 Gas-Oil Ration: 6,74Q Flow Tubing Pressure: 750 Casing Pressure: 100 Oil Gravity-APl: 26 9/17/2007 STATE OF ALASKA ~~ ALASKA~IL AND GAS CONSERVATION COM~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~,~~~ ~~~~ .~ o zao~ a~~N%~ <'~rt ~ Gas Cons 1a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoaACZS.~oe zoaacze.~,o 1b. Well Class: ~~C1101'aa ~ Development ^ Explot'a~ory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban~.~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/12/2007 ~ (L 207-086 ~ 3. Address: 6. Date Spudded 9' 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/26/2007' S0-029-21652-02-00 ~ 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: SurFace: ' ' 8/4/2007 ' PBU G-25B ' FNL, 1973 2617 FEI., SEC. 12, T11N, R13E, tJM Top of Productive Horizon: 8. KB (ft above MSL): 72.40 ~ 15. Field / Pool(s): .~ 2913' FNL, 1980' FEL, SEC. 07, T11 N, R14E, UM Ground (ft MSL): 34.7' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+~/D) Pool 4291' FNL, 538' FEL, SEC. 07, T11 N, R14E, UM 12614 8979 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+ND) 16. Property Designation: Surface: x- 658254 y- 5969032 Zone- ASP4 12653 8979 ADL 028304 " TPI: x- 663170 y- 5968841 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 664647 y- 5967495 Zone- ASP4 None 18. Directional Survey ~ Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic an rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information p 20 AAC 25. 1): ~ ~ MWD DIR, GR, RES, MCNL / GR / CCL j~/Nd~~J ~ J~~l~ 1Y~ Ps~S ZZ. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH' NQ HOLE AMOUNT ! WT. PER FT. GRADE TOP BOTTOM TOR BOTfOM SIZE CEMENTING RECQRD , PULIEQ` 20" Insulated Conduct r Surface 110' Surface 110' 26" 9 cu ds oncrete 13-3/8" 72# L-80 / S-95 39' 2785' 39' 2685' 17-1/2" 3890 cu ft Permafrost 9-5/8° 47# L-80 36' 9724' 36' 8337' 12-1 /4" 590 cu ft Class 'G' 5-1/2" 17# L-80 462' 10169' 8113' 8723' 8-1/2" 484 cu ft Class'G' 3-3/16" x 2-7/8" 62# J 6.16# L-80 9382' 1 8044' 8765' 3-3/4" 146 cu ft Class 'G' 2-3/8" 4.7# L-80 10018' 12653' 8590' 8979' 3" 95 cu ft Class'G' 23. Open to production or inject ion? ~ Yes ^ No 24: 'f'us-r~G ReeoRo If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): SizE ~EPTH .SET MD PACKER SET MD 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9465' 9322' MD ND MD ND 10560' - 10740' 8937' - 8946' FRACTURE; CEMENT SQUEEZE ,,ETC. 25. ACia 10770' - 10940' 8946' - 8955' , , 10990' - 11030' 8958~ - 896~~ ~EPTH ~NTERVAL MD AMOUNT & KIND OF MATERIAL USED 11190' - 11350' 8964' - 8962' 9300' Freeze Protected w/ Diesel 11590' - 11710' 8970' - 8978' 12130' - 12190' 8982' - 8980' 12240' - 12270' 8980' - 8979' 12380' 12450' 8976' - 75' - 89 12500' - 12610' 8976' - 8979' ZF). PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test: Hours Tested: PROOUCr~oN FoR Oll-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: Cn~c~~n,reo OIL-BBL: GAS~MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: Press. 24-HouR RaTe• 27. CORE DATA Conve~tional Core(s) Acquired? ^ Yes ~~ No Sidewal l Core s A uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. COi~PLE7ICN None S ~~~ ~~'""°~ ~ J~P ~ 6 ~dQ~ lSSIC Form 10-407 Revised 02/2~ ~~~ I N A L CONTINUED ON REVERSE SIDE (~ ~~~ 'A/~ //~ I ~ ,~ ~ ~~, 7~ ~c/7 i 28. GEOLOGIC MARKERS ~LIST AlL FORMATIONS AN KERS ENCOUNTERED~: Z9. FORMATION TESTS ~ NAME TVD Well Teste . ^ Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 22TS 10245' 8784' None Zone 2A / 21TS 10333' 8842' Zone 1 B/ 14N 10472' 8911' 14P 10558' 8936' Formation at Total Depth (Name): Zone 1 B/ 14P 10558' 8936' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. O~ ^ Title Technical Assistant Date /~~ / D Signed Terrie Hubble PBU G-25B 207-086 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A roval No. Drilling Engineer: Ganet Staudinger, 564-4242 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITem 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 In2erval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITea~ 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~ ~ BP EXPLORATlQf~l' Page 1 of 18 Clperations Sumr~t~ry Repvr~t Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 ' Date From - To Hours Task Code NPT Phase Qescription of Operations 7/23/2007 03:30 - 09:30 6.00 MOB P ~ I PRE Move from E-19B to G-25A. Accept rig at 09:30. 09:30 - 16:00 6.50 RIGU P I PRE Installed reel. NU BOP. Swap rams for 2" CT.Change out ~ gripper blocks on injector. I ~', PU brand new CT reel, length of CT 15700', e-line 15900', '~ slack is 1.27percent 16:00 - 23:00 7.00 BOPSUF~ P PRE BOP test witnessing waived by Chuck Scheeve AOGCC. ~ , ~ Tested all lines rams and valves to 250 and 3500 psi for 5min ' i each, annular to 250 -2500 psi 5min each, choke manifold I valves 250-3500 psi 5min each, note VBR failed pressure test, ~~ borrowed a set of seals Nordic 2, Performed Accumulator ~ draw down test -~~~e ~° Z~(u,re.~ r,(,+;~~ t ~ gpPt~ t'~Sa+ ~- ~ ~t~~ C~I~'~ ~ ~Z C'k.~~ -vutr~, v~:tUe ~~r~!^~ ~ RU hardline and heading up e-line connector in reel during ~'~~ BOP test 23:00 - 00:00 1.00 BOPSUF~ N I SFAL ~ PRE Open VBR door, attempt to pull VBR's, found guide plate deformed and mushroomed, similiar to what happen to lower 2 , ' 3/8" combi on E-11, grinded down the guide plate to remove ' I the rams, damage was caused by closing rams on oversize I ~~ pipe, believed to have happen during last koomey draw down i test, found 3 1/2" test joint which is believed to be what caused the damage to the VBR guide plate with fresh marks on collar i ', on test joint, unable to use VBR's do to damage to guide ~ ~ plates, would not align properly, did not have spare VBR's " 7/24/2007 00:00 - 00:30 0.50 BOPSU N SFAL PRE combi Install 2 3/8 00:30 - 01:00 0.50 BOPSU P PRE Install test joint, tested rams from 250 - 3500psi, OK, LD test joint 01:00 - 01:15 025 KILL P WEXIT PJSM with crew on pulling CT across pipeshed 01:15 - 04:00 2.75 KILL P W EXIT Pull test internal grapple, pull CT across, stab injector, cut off internal grapple, NU stuffing box to injector, run CT thru same, ' RU hydraulic CT cutter, cut 55' of 2" CT, found e-Iine cable, ' ~ i check and meg e-line, OK, boot e-line, RD hydraulic cutter, ~ stab injector 04:00 - 05:00 1.00 KILL P WEXIT Pump 7bbls down CT, test hardline to inner reel valve to 4000psi, continue circ at 1.5bpm, 1400psi, filling CT with double slick KCL 05:00 - 06:00 1.00 KILL ~ P j i W EXIT RU, rev circ, performing slack management, heard e-line move ~ while rev circ, RU hydraulic cutter, cutting 220' CT, 22' of e-line 06:00 - 06:50 0.83 KILL ! P WEXIT Pull BPV with lubri 06:50 - 12:00 5.17 BOPSU N SFAL WEXIT Released BPV gas to possum bellt Shut in weli at choke. Well not properly shut in for Pulling BPV. Notify Anch CTD manager, AOGCC Chuck Scheeve, GC1 operator X4084, I Unable to contact G pad operatordirectly.Notify Nordic mgt Alan Graff, AlanMaddsen Conduct Investigation of gas release. 12:00 - 12:45 0J5 BOPSU N ~ SFAL W EXIT Debrief on current operations with CoMan and Alan Madsen, Drlg Supt 12:45 - 13:10 0.42 BOPSU P WEXIT PJSM with BPV crew, rig personnel on pulling BPV, valve alignment, safety hazards and precautions 13:10 - 13:30 0.33 BOPSU P i WEXIT Open well, finished releasing and pulling BPV with lubricator, ~ shut in master valve, open choke released trap pressure to tiger tank, RD lubricator and BPV, secured well, offload lubricator and BPV from rig floor 13:30 - 13:45 0.25 KILL I P ~ ~ I W EXIT PJSM on handing and heading up CTC and e-coil, adjusting Printed: 8/15/2007 7:40:04 PM ~ ~ BP' EXPLQRATIOf~}' Page 2 of 18 .Operations Summary R~p~r~fi Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hc~urs Task Code NPT Phase Description of C~p~ratians - - ~ 7/24/2007 ~ 13:30 - 13:45 0.25 KILL P ~i W EXIT rollers on gooseneck for 2" CT 13:45 - 15:15 1.50 KILL P i W EXIT i Adjust rollers for 2" CT, Install Kendall dipple CTC, putl test to ~ ~36K 15:15 - 16:00 0.75 KILL ~ P WEXIT MU Nozzle BHA #1 with UQC, head up e-line, Meg e-line, ok, ', installed LQC blind sub, and nozzle 16:00 - 16:30 0.50 KILL P WEXIT PJSM with all involved personnel on pumping operations, valve alignment and good communication 16:30 - 19:00 2.50 KILL P ! W EXIT Pressure Test CT riser to 3500 psi, est circ rates at 1.09bpm, ~ 1380psi, 1.59bpm, 2080psi, 2.19bpm, 3014psi, 2.50, 3500psi, ~ ; Pressure up to 1500psi, open swab and master vaives, Shut in ~ i pressure stabilized at 1406psi, bulihead down tubing at 1.50bpm, 3350 - 2900psi, pressure increased to 3450psi after pumping 116bb1s, slowed pumps down to 1.22bpm, 3180psi. ~ Bullhead a total of 142bb1s of fluid Q 1 bpm/3500psi CTP & ; 2600 WHP. Not qettinq required +/-4bpm rate to kill well. 19:00 - 19:25 0.42 KILL P ~ WEXIT Attempt to snub in hole - injector tripping out @-14k. Line up ~ to take returns to the tiger tank. Attempt to bleed down the W HP via the Swaco auto choke - not working properly. Switch to manual choke & bleed off W HP to 1800psi with -11 k CT wt. ' 19:25 - 21:30 2.08 KILL P W EXIT RIH with nozzle BHA #1 to 10200' maintaining +/-1800psi W HP & taking gassy returns to the tiger tank. 21:30 - 22:20 0.83 KILL P ~ W EXIT S/I choke & bullhead 15bbls KCL fluid (vol from 10200' to i PBTD) into perfs @ 0.75bpm/2800psi CTP & 2250psi WHP. 22:20 - 00:00 1.67 KILL P ~ WEXIT Open up choke & attempt to kill well conventionally with j 1.92bpm/4000psi CTP & 2000psi WHP. 7/25/2007 00:00 - 00:45 0.75 KILL P I W EXIT Continue pumping to kill well conventionally with 2.15bpm/4000psi & 2000psi. Observe frosting on choke manifold lines & valves - suspect gas hydrates & possible ice-plugging of choke lines. Aiso did not getting back much returns after 280bb1s pumped. 00:45 - 03:00 2.25 KILL P WEXIT Open up choke more & continue pumping additional 110bb1s until returns cleaned up. Circ 2X BU with no gas to surface. Start taking returns to pits. Bleed down OAP from 1000psi to ' 250psi. Meanwhile call for 150kcps flo-pro pill to squeeze into t eTi ~per~ s before POOH. 03:00 - 04:00 1.00 KILL P i W EXIT Line up & pump down 40bbls of 150kcps flopro pill down to ~ nozzle. S/I well & squeeze-in 20 bbis Q 0.93bpm/3300psi CTP & 1550-1750psi WHP. Open up choke & lay-in remaining flopro pill 1:1. 04:00 - 05:45 1.75 KILL P WEXIT POOH nozzle BHA#1. 05:45 - 06:45 1.00 KILL P WEXIT Flowcheck well - stable while having change out with WSL and toolpusher discussing plan forward 06:45 - 07:15 0.50 KILL P WEXIT PJSM on injector handling for bha changes and opening 2" drain line 07:15 - 07:30 0.25 KILL P WEXIT POH with nozzle BHA #1, LD same 07:30 - 08:00 0.50 WHIP P ; WEXIT Make up BHA#2 with whipstock and Mech WS Packer. 08:00 - 10:35 2.58 WHIP P WEXIT RIH BHA#2 to 9750. 10:35 - 10:45 0.17 WHIP P WEXIT Ran tie in pass. Correlated back to PDC log. Baker correction of plus 1, SLB CT minus 13. 10:45 - 10:55 0.17 WHIP P WEXIT RIH to 10228. Set whipstock. TOWS 10220, BOWS 10228. 10:55 - 12:15 1.33 WHIP P WEXIT POH BHA#2. ~ 12:15 - 12:30 0.25 WHIP P W EXIT Pressure test whipstock packer to 2000 psi. 12:30 - 13:30 1.00 WHIP P WEXIT PJSM laying down BHA and unstabing injector. POH with Printed: 8/15/2007 1:40:04 PM ~ ~ BP'' EXPLORATION ; Page ~ af ~8 ' ; O~erations Summary Rept~rt Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hou~s Task Code NPT Phase Description af C)peratians 7/25/2007 ~i 12:30 - 13:30 1.00 WHIP P WEXIT BHA#2 and lay down whipstock running tool. j 13:30 - 14:00 0.50 STWHIP P WEXIT PU milling assembly, BHA#3. ~, 14:00 - 14:20 0.33 STWHIP P WEXIT RIH with BHA#3. I 14:20 - 14:45 0.42 STWHIP N DFAL WEXIT Stop at 1400ft. CoilTrac is not working. POH to BHA#3. 14:45 - 16:10 1.42 STWHIP N DFAL I WEXIT Troubleshoot BHA#3. Change out Power and Communication Sub. ',16:10 - 18:30 2.33 STWHIP P I WEXIT ~ RIH with BHA#3. Tag WS/Lnr pinch pt without pumps @ ~ ~ 10232'. P/U with 30k up wt. Down wt = 18.5k. Bring on pumps 'I & establish freespin @ 1.5bpm/1700psi. RBIH with pumps on & 'i retag WS/Lnr pinch pt Q 10231.6'. Correct CTD to 10220' inch t CTD & fla CT. ~ I 18:30 - 19:30 1.00 STWH~P P WEXIT Start milling window with 1.55/1.55bpm, 1700/1800psi, 1k ' s~ I ~ DWOB & lfph ave ROP. Mill to 10221 . ' •?j 19:30 - 20:45 1.25 STWHIP P WEXIT Mill to 10222 with 1.55/1.55bpm, 1700/1890psi, 1.8k DWOB & 0.8fph ave ROP. i 20:45 - 21:40 0.92 STWHIP P WEXIT Mili to 10223' with 1.55/1.55bpm, 1700/1800psi, 0.8k DWOB & ' ifph ave ROP. j21:40 - 22:40 1.00 STWHIP P WEXIT Mill to 10224' with 1.55/1.55bpm, 1700/1800psi, 0.8k DWOB & ' lfph ave ROP. MWD still acting up. 22:40 - 23:00 ( 0.33 STWHIP P WEXIT Mill to 10225' with t.55/1.55bpm, 1700/1800psi, 0.8k DWOB & ~ ~ ~ ifph ave ROP. Exit into formation @ 10225'. i23:00 - 23:45 ~ 0.75 STWHIP P WEXIT i Control mill to 10226' with 1.55/1.55bpm, 1700/1800psi, 0.8k , ~ DWOB & 1.3fph ave ROP. !23:45 - 00:00 0.25 STWHIP P WEXIT Wiper trip clean to 10200'. RBIH clean to btm. Establish '~ freespin @ 1.5bpm/1600psi. Observe MWD communicating only to the BCM in the P&C. No good communication could be established from the CTM & other components below. Currently will not be able to disconnect in the worst case I scenario of getting stuck. Decide to finish up rat hole with ' I current BHA failure. 7/26/2007 I00:00 - 01:00 1.00 STWHIP P WEXIT Control mill 10' formation to 10235' with 1.5/1.5bpm, 1550/1850psi, 9fph ave ROP & 2.4k DWOB. 01:00 - 01:45 0.75 STWHIP P WEXIT Swap wellbore to 8.6 ppg reconditioned flopro mud with 12ppb K-G & 3% L-T. Meanwhile backream/dress window/rat hole severai times. W indow looks clean. Tentative window depths ; are: TOWS = 10220', TOW = 10220', BOW = 10225', RA Pip tag = 10225'. i~01:45 - 03:45 2.00 STWHIP P WEXIT POOH window milling BHA #3, while displacing well to mud. 03:45 - 04:45 1.00 STWHIP P WEXIT PJSM. UD BHA #3 & inspect mills. Both window mill & string mill gauge 2.73" go / 2.72" no-go. Wear on window mill face indicate center crossed the liner wall, found EDC sub shorted out internally 04:45 - 05:35 0.83 DRILL P PROD1 M/U drilling BHA#4 with new Hughes 2.7" x 3" DOSTRWD bicenter bit #2, 1.1deg X-treme motor, BHI HOT, USMPR, ~ ~ DGS, DPS, EDC, P&C, SWP, LQC & UQC. Scribe tools. M/U ~ injector & Initialize/function test BHI tools. ~ 05:35 - 07:20 1.75 DRILL P PROD1 RIH drilling BHA#4 to 9773', up wt at 9300' 28k 07:20 - 07:40 0.33 DRILL P PROD1 Tie-in pass f/ 9773' to 9808', corrected CT -6', Baker coiltrak +7,dn wt at 9773', 2.4fpm, 14.9k 07:40 - 08:00 0.33 DRILL P PROD1 RIH to TOW, orient TF to 30L, slide thru window without pumps ~ i to btm ! 08:00 - 13:30 5.50 DRILL P ~ PROD1 Drill to 10400', TF at 19L-58R, 1.58/1.57bpm, 3000psi, FS ~~ i 1.58bpm, 2750psi, ECD 9.57ppg, WOB .5-1k, AP 4314psi, BP Printed: 8/15/2007 1:40:04 PM ~ ~ BP ~xP~o~a-rian~ ~~~~ ~ ~f f~ Op~ratiQns Summary Report Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Qate From - To Hours Task Code NPT Phase Description of Qperatior~s 7/26/20~7 ~ 08:00 - 13:30 ~ 5.50 DRILL P PROD1 4764psi, ROP 21- 76fph ~ 13:30 - 13:45 0.25 DRILL P PROD1 Wiper trip to window, no problems 13:45 - 16:15 I 2.50 DRILL P PROD1 Drill to 10550', TF at 54R, 1.51/1.50bpm, 3000psi, ECD ; 9.57ppg, WOB 1 k, AP 4365psi, BP 4950psi, ROP 75- 32fph, i I ~ ( PVT 324bb1s ' 16:15 - 16:45 0.50 DRILL P PRODi Wiper trip to window, no problems 16:45 - 19:30 2.75 DRILL P PROD1 Drill to 10561', TF at 99R, 1.60/1.59bpm, 3344psi, ECD 9.69ppg, WOB ik, AP 4445psi, BP 5133psi, ROP 5fph, PVT 341 bbls. Getting repeated stalls & not able to drill off - suspect bit balling in 14N shale. 19:30 - 21:30 ~ 2.00 DRILL P PROD1 Drill to 10582' with 120R TF, 1.7/1.7bpm, 3250/3450psi, ~ 9JOppg ECD, 1.9k DWOB & lOfph ave ROP. Stacking wt. ~ 21:30 - 21:35 ~ 0.08 DRILL P PROD1 Short BHA wiper. ( 21:35 - 00:00 i 2.42 DRILL P PROD1 Drill to 10622' with 110R TF, 1.7/1.7bpm, 3250/3450psi, 9.71ppg ECD, 2.4k DWOB & 20fph ave ROP. 7/27/2007 j 00:00 - 00:40 0.67 DRILL P PROD1 Drill to 10638' with 115R TF, 1.7/1 Jbpm, 3250/3450psi, ~ i 9.72ppg ECD, 2.4k DWOB & 25fph ave ROP. Observe drilling ~ break @ 10638'. 00:40 - 00:55 0.25 DRILL P PROD1 Drill to 10650' with 125R TF, 1.7/1.7bpm, 3350/3550psi, 9.73ppg ECD, 2.2k DWOB & 50fph ave ROP. 00:55 - 01:00 0.08 DRILL ~ P PROD1 Short BHA wiper. 01:00 - 02:50 1.83 DRILL P PROD1 Drill to 10700' with 125R-50L TF, 1.7/1.7bpm, 3350/3550psi, 9.73ppg ECD, 2.2k DWOB & 50fph ave ROP. 02:50 - 03:05 0.25 DRILL P PROD1 Wiper trip clean to window. 03:05 - 03:15 0.17 DRILL P PROD1 Log down GR @ 145fph & tie-into RA pip tag - Add 1'to CTD. 03:15 - 03:35 0.33 DRILL P PROD1 RBIH clean to btm. i 03:35 - 06:00 2.42 DRILL P PRODi Drill to 10850' with 45-90L TF, 1.7/1.7bpm, 3350/3750psi, 9.83ppg ECD, 2-3.5k DWOB & 65fph ave ROP. j 06:00 - 06:45 ~ 0.75 DRILL P PROD1 Wiper trip to below window i 06:45 - 10:50 ~ 4.08 DRILL P PROD1 Drill to 10994' with 68 - 100L TF, 1.6/1.57bpm, 3530/3365psi, ~ 9.81 ppg ECD, 2.5-3k DWOB, 35-72fph ave ROP, PVT 332bb1s, IA 320psi, OA 306psi 10:50 - 11:40 0.83 DRILL P PROD1 Wiper trip to below window, no problems 11:40 - 16:30 4.83 DRILL P PROD1 Drill to 11157' with 31-76L TF, 1.60/1.55bpm, 3450/3450psi, 9.46ppg ECD, 2.5-4k DWOB, 40-20fph ave ROP, IA 371psi, OA 345psi, swapping well to new Flo-Pro mud 16:30 - 19:15 2.75 DRILL P PROD1 POH to Drlg BHA #4 19:15 - 19:30 0.25 DRILL i P PROD1 Hold PJSM & THA for C/O drilling BHA. , 19:30 - 20:30 1.00 DRILL P PROD1 S/B injector. Flush BHA with water & B/D with air. UO bit - 3/2/I with 2 plugged nozzles on the pilot. C/O O-ring in LQC. I P/Test CTC to 3500psi - OK. Observe UQC & CTC connection not properly torqued up (was able to break it while breaking i P/Test plate with wrenches). Decide to rehead eline & P/test CTC & UQC. 20:30 - 22:00 1.50 DRILL N SFAL PROD1 Rehead eline & M/U UQC. Conduct eline conductivity test -- OK. Meg eline - OK. P/Test CTC & UQC to 3500psi - OK. 22:00 - 23:00 1.00 DRILL P PROD1 M/U lateral BHA #5 with new Hycalog 2.7" x 3" SRX3408M-A5 I bicenter bit #3, 1.1deg X-treme motor, BHi HOT, USMPR, DGS, DPS, EDC, P&C, SW P, LQC & UQC. Scribe tools. Gall i connection between the UQC & LQC while M/U the injector due to too much CT residual bend. 23:00 - 00:00 1.00 DRILL N SFAL PROD1 S/B injector. C/O the LQC & housing on UQC. Re-M/U injector. ~ i Initialize/function test BHI tools. Function test BHA - OK. M/U Printed: 8/75/2007 1:40:04 PM ~ ~ BP EXPLQRATIUN : Page 5 of 18: Operations Summary I~epc~r~t Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date '~ Frorn - To Hours Task Code NPT Pt~as 7/27/2007 23:00 - 00:00 1.00 DRILL N SFAL I PRODi 7/28/2007 00:00 - 01:50 1.83 DRILL P PROD1 01:50 - 02:05 0.25; DRILL I P PROD1 02:05 - 03:00 ~ 0.92' DRILL P PROD1 03:00 - 04:00 1.00 DRILL i P ~ ~ PRODi 04:00 - 05:00 1.00 DRILL i P I PROD1 05:00 - 06:45 1.75 DRILL ; P ; ~ PROD1 06:45 - 10:25 3.67 i DRILL ~ P PROD1 10:25 - 11:30 I 1.081 DRILL I P I I PROD1 11:30 - 15:10 I 3.671 DRILL I P I I PROD1 15:10 - 15:20 0.17 DRILL i P PROD1 15:20 - 15:45 0.42 DRILL I P PROD1 15:45 - 17:00 ~ 1.25 ~ DRILL i P ~ ~ PROD1 17:00 - 18:10 I 1.171 DRILL I P I I PRODi 18:10 - 18:25 I 025) DRILL ~ P ~ I PROD1 18:25 - 19:30 1.08 DRILL P ' PROD1 19:30 - 21:45 2.25 DRILL C PROD1 21:45 - 21:55 0.17 DRILL C PROD1 21:55 - 23:45 1.83 DRILL C PROD1 23:45 - 00:00 025 DRILL ~ C PROD1 7/29/2007 00:00 - 01:00 1.00 DRILL C PROD1 01:00 - 01:15 025 STWHIP C PROD1 01;15 - 02:15 1.00 STWHIP C PROD1 02:15 - 05:00 I 2.751 STWHIPI C I I PROD1 injector. RIH lateral BHA#5 to 10250'. Log down GR @ 135fph & tie-into RA pip tag - Add 8' to BHI & subtract 9' from CTD. Continue RIH lateral BHA#5. Set down in 10637', 10744', 10785', 10789' & 11125' (14N shale). Backream up to 10300'. Observe motor work across the 14N. RBIH clean & set down @ 11125'. Ream shales to btm with as-drilled TF at 66L, motor work intermittently f/ 11125 to bottom Drill to 11300' with 8L - 133R TF, 1.63/1.63bpm, 3256/3281 psi, 9.64ppg ECD, 2-4k DWOB, 35-76fph ave ROP, IA 93psi, OA 16psi, PVT 329bb1s W iper trip to below window, up wt off btm at 33k, overpull of 10k at 11118', 11108', 10858', RIH with bobbles of 5k at 10100', 10120', 10500',10600' Drill to 11429' with 70-90R TF, 1.65/1.60bpm, 3457/3581 psi, 10.13ppg ECD, 2-4k DWOB, 35-60fph ave ROP, frequently stacking wt and stalling out, IA 258psi, OA 195psi, PVT 321 bbls 100' wiper trip Drill to 11450' with 139R TF, 1.58/1.60bpm, 3395/3424psi, 9.85ppg ECD, 2k DWOB, 60fph ave ROP, frequently stacking wt and stalling out, IA 370psi, OA 303psi, PVT 321 bbls W iper trip to below window to 10235', up wt off btm at 31 k, 16fpm, 5k overpill at 11118', 10680', 10643', overpulls of 10k at 11108', 10858', ratty formation from 10575' to 10563' with overpulis of 5 -10k RIH, tight spot at 10575' with 10k dn drag, ratty formation f/ 11122' - 11157 and 11182' - 11191' w/ 5-10k dn drag, worked back thru ratty hole once, RIH, ratry formation f/ 10200' to 10240', and 11362' to 11420', working back thru ratty hole, RIH from 11360' to 11440', ream shale to btm Drill to 11460' with 45R TF, 1.58/1.53bpm, 3460/3519psi, 9.85ppg ECD, 22k DWOB, 50fph ave ROP, frequently stacking wt and stalling out, IA 367psi, OA 325psi, PVT 316bb1s. Observe drilling break @ 11460'. Drill to 11551' with 125R TF, 1.58/1.58bpm, 3450/3750psi, 9.92ppg ECD, 1.5k DWOB & 85fph ave ROP. W iper trip while Geos decide on OHST options. Observe +/-5k to 10k O/pull between 11500' & 11400', 10620'. Log down GR @ 135fph & tie-into RA pip tag - Add 1' to CTD. Paint EOP Flag Q 10000' & POOH drilling BHA#5. Hold PJSM & THA for UD drilling BHA. S/B injector. Flush BHA with water & B/D with air. UD BHA. Bit gauge- 0/0/I with a piece of stator rubber in the pilot. Hold PJSM & THA for M/U GH whipstock BHA. M/U GHWS BHA #6 with BOT 2-3/8" guide shoe, 2-5/8" steel OHWS, setting sleeve, Hyd S/tool, X/Over BHI HOT, DGS, DPS, EDC, P&C, SWP, LQC & UQC. Scribe toois. M/U injector & Initialize/function test BHI tools. RIH OHWS BHA #6. Wt check @ 10000' - up = 32k & down = 19k. Correct CTD by -4' & BHI by +10' @ EOP flag. Observe Printed: 8/15/2007 1'40:04 PM ~ ~ BP EXPLORATIQRI ' Page 6 0# 18' Operations Summary Repa~rt Legal Well Name: G-25 Common Well Name: G-25 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 '~. 1'1.~.+r. '~. ~ Cv.~:w~ T..:: I LJ....e.. ~ T..~3.1. !(~.~ . __~ 7/29/2007 02:15 - 05:00 2.75 STW H I P I C 05:00 - 05:40 0.67 STWHIP~ C 05:40 - 06:30 ( 0.83 I STW H I P I C 06:30 - 08:45 I 2.251 STWHIPI C 08:45 - 09:15 I 0.501 STWHIPI C 09:15 - 10:15 I 1.00 I STW H I P I C 10:15 - 12:05 1.83 STWHIP C 12:05 - 12:20 0.25 STWHIP C 12:20 - 12:30 0.17 STWHIP C 12:30 - 15:20 I 2.83 ~ STW H I P I C 15:20 - 19:00 I 3.671 STWHIPI C 19:00 - 19:30 I 0.50 I STW H I P I C 19:30 - 00:00 4.50 STW H I P C 7/30/2007 00:00 - 01:00 1.00 STWHIP C 01:00 - 02:00 1.00 STWHIP C 02:00 - 04:15 2.25 STWHIP C 04:15 - 04:30 0.25 STWHIP C 04:30 - 05:15 0.75 STWHIP C 05:15 - 06:15 I 1.001 DRILL I C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 06:15 - 08:00 1.75 DRIL~ C PROD1 08:00 - 08:30 ~ 0.50 DRILL C PROD1 08:30 - 09:15 0.75 DRILL C ~ PROD1 09:15 - 11:15 2.00 DRILL X I i DFAL I PROD1 Spud Date: 10/1/1986 End: 8/12/2007 8k drag @ the window. Work BHA below window with 6k DWOB & 30fph tie into RA pip tag with -3' correction. Continue working BHA in hole with 7k DWOB. P/U with up to 20k O/pull. Work down to 10265' & could not make any further progress. PUH & set string to neutral wt. Open up the EDC. POOH to OHWS BHA#6 filling hole @ 0.5bpm, Brk out Injector and UQC POH with OHWS BHA #6, Left WS in hole after setting prematurely at approximate 10265', TOWS at 10256', 20R of HS MU kick-off BHA #7 with 2.74" parabolic mill, 1.5 deg X-treme motor, 8HI HOT, DGS, DPS, EDC, P&C, SW P, LQC & UQC. Scribe tools, M/U injector, Initialize/function test BHI tools, Function test BHA - OK RIH with kick-off BHA#7 Tie-in pass with RA tag, correct CTD -.6' , Baker depth +14' RIH to 10255', set dn on WS, Up wt at 32k, Dn wt 16.7k, FS at 1.5bpm, 3050psi, pinch point at 10257' Kick off with TF at HS. BHA having trouble siiding to start the OHST, Three attempts made to Kick Off with no success at 0.1 ft per 6 min, 0.1 ft per 12 min, and 0.05 ft per 12 min. Begin fourth attempt to S/T well at 0.5fph for 1' to 10258', 1.66/1.68bpm, 3464psi, increased ROP to lfph to 10259', increased ROP to 3fph to 10262', increased ROP 4fph to 10264' with 2k WOB, backream to 10250', ream down thru sidetrack to 10264', motor work started at 10262' - 10264' Controt mill to 10267' with 35R TF, 1.6/1.6bpm, 3350/3450psi, 9.66ppg ECD, 4k DWOB & 7fph ave ROP. Stall @ 10267'. PUH to 10247'. RBIH to btm. Decide to drill further with current BHA to get much lateral separation from original wellbore with the 1.5deg bend motor. Continue milling to 10277' with 35R TF, 1.6/1.6bpm, 3350/3850psi, 9.66ppg ECD, 2.5k DWOB & 2.5fph ave ROP. Continue milling to 10278' with 35R TF, 1.6/1.6bpm, 3350/3850psi, 9.66ppg ECD, 2.5k DWOB & ffph ave ROP. Stop drilling due to very slow ROP. Backream clean from 10278' to window. POOH kick-off BHA#7. Hold PJSM & THA for L/D kick-off BHA. S/B injector. Flush BHA with water & B/D with air. UD kick-off BHA#7. Parabolic mill gauge 2.73" go & 2.72" no-go. M/U drilling BHA#8 with re-run Hycalog 2.7" x 3" SRX3408M bicenter bit #5, 1.1 deg X-treme motor, BHI HOT, USMPR, DGS, DPS, EDC, P&C, SW P, LQC & UQC. Scribe tools. M/U injector & Initialize/function test BHI tools. RIH with drlg BHA #8 Tie-in pass with RA tag, correction for Baker 0', CTD -14.4' Drill to 10295', TF at 40-60L, 1.59/1.56bpm, 3171/3200psi, ECD 9.68ppg, WOB 1-2k, ROP 50fph, AP 4373psi, BP 4845psi, IA 76psi, OA 132psi, PVT 288bb1s, HOT (orienter) failed, giving false readings sporadically POH to driiling BHA#8 to change out orienter (HOT Sub), Brk Start: 7/18/2007 Rig Release: 8/12/2007 Rig Number: N1 ode NPT Phase ~ p~ ; PROD1 I ~ PROD1 ~ ,~ ;PROD1 Printed: 8/15/2007 1:40:04 PM ~ ~ ' BP' EXPLORATION'i! Page 7 a# ~ 8 ';(}p.era~ians Summary Repart ~egal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 ~~,_ I Rig Number: N1 : Date From - To Hours Task C 7/30/2007 09:15 - 11:15 2.00 DRILL X 11:15 - 11:45 I 0.501 DRILL I X 11:45 - 12:15 0.50 BOPSU~X 12:15 - 12:25 0.17 DRILL X 12:25 - 12:50 0.42 DRILL X 12:50 - 15:00 2.17 DRILL X 15:00 - 16:45 1.75 DRILL C 16:45 - 18:35 1.83 DRILL X 18:35 - 18:45 0.17 DRILL X 18:45 - 19:15 0.50 DRILL X 19:15 - 20:15 I 1.001 DRILL I X 20:15 - 22:15 2.00 DRILL X 22:15 - 22:30 0.25 DRILL X 22:30 - 22:40 0.17 DRILL X 22:40 - 00:00 1.33 DRILL C 17/31/2007 i00:00-01:25 I 1.421DRILL IC 01:25 - 03:15 I 1.831 DRILL I C 03:15 - 03:35 0.33 ORILL C 03:35 - 06:00 2.42 DRILL C 06:00 - 07:25 1.42 DRILL C 07:25 - 08:00 0.58 DRILL C 08:00 - 09:35 1.58 DRILL C 09:35 - 10:45 1.17 DRILL C 10:45 - 12:00 I 1.25 ~ DRILL ~ C N,PT ~Phase ~ ~ De~cription of C~peratior~s DFAL PROD1 out inj and UQC, stb back injector, PVT at surface 252bb1s, IA i 109psi, OA 212psi DFAL j PROD1 POH with Drlg BHA#8, flush out tools with water and blow i down, LD coiltrak tools, replace HOT sub DFAL I PRODi PU 2" and 2 3/8" test jts, Function test BOP's, OK '~ DFAL PROD1 I PJSM on handling drilling BHA #9 and stabbing injector. DFAL PROD1 i Make up drilling BHA #9 with rebuilt Hycalog 2.7" x 3" SRX3408M bicenter bit #6, 1.1deg X-treme motor, BHI HOT, USMPR, DGS, DPS, EDC, P&C, SWP, LQC & UQC. Make up ~ injector. DFAL PROD1 RIH with BHA #9 to bottom PROD1 Drili to 10352', TF at 65L, 1.61/1.60bpm, 3391/3431psi, ECD 9.65ppg, WOB 1-2k, ROP 60-42fph, AP 4373psi, BP 5030psi, , IA 18psi, OA 46psi, PVT 284bbfs, orienter failed, not responding properiy on bottom, seems to be working fine off ~ bottom DFAL PROD1 POH to drlg BHA#9 DFAL PROD1 Hold PJSM & THA for UD drilling BHA. DFAL PROD1 S/B injector. Flush BHA with water & B/D with air. UD drilling BHA#9. UO all coiltrack tools. DFAL PROD1 ~ M/U drilling BHA#10 with rebuilt Hughes 2.7" x 3" DOSTRW D bicenter bit #7, 1.1deg X-treme motor, new BHI HOT, USMPR, DGS, DPS, EDC, P&C, SWP, LQC & UQC. Scribe tools. M/U injector & Initialize/function test BHI tools. DFAL PROD1 RIH drilling BHA#10. DFAL PROD1 Log down GR @ 135fph & tie-into RA pip tag - Add 10' to BHI & subtract 5' from CTD. DFAL PROD1 RIH drilling BHA#10 clean past OHST pt to btm. PROD1 Drill to 10462' with 35L-60R TF, 1.6/1.6bpm, 3350/3550psi, 9.7ppg ECD, 1k DWOB & 80fph ave ROP. RES tool quit working & come back to life again @ 10462'. PROD1 , Drill to 10490' with 45R TF, 1.6/1.6bpm, 3350/3550psi, 9.7ppg ~ ECD, 2k DWOB & 20fph ave ROP. PROD1 Dril! to 10540' with 45R TF, 1.6/1.6bpm, 3350/3550psi, 9.7ppg ECD, 2k DWOB & 30fph ave ROP. PROD1 Wiper clean to 10300' (below OHST pt). RBIH clean to btm. PROD1 Drill to 10580' with 45R TF, 1.6/1.6bpm, 3250/3450psi, 9.7ppg ECD, 2k DWOB & 20fph ave ROP. PROD1 Drill to 10710' with 123R TF, 1.73/1.71bpm, 3706/3728psi, 9.83ppg ECD, 1-2k DWOB & 90-125fph ave ROP, ap 4530psi, bp 5184psi, IA 367psi, OA 392psi, PVT 269bb1s, broke out in sand at 10585' PROD1 I W iper trip clean to 10300' (below OHST pt), RBIH clean to btm. PROD1 Drill to 10863' with 136-93R TF, 1.69/1.67bpm, 3706l3728psi, 9.83ppg ECD, 1-2.6k DWOB & 145-178fph ave ROP, ap I 4530psi, bp 5590psi, IA 380psi, OA 408psi, PVT 267bb1s PROD1 Wiper to 9300', hole clean, RBIH, Tie-in to RA Tag, no correction for SLB and Baker, swapping well to new Flo-Pro mud system with 12 ppb Kla-guard and 3 percent Lube Tex as i bit reaches btm PROD1 ~ Drill to 10950' with 122-71 L TF, 1.69/1.67bpm, 3948/3960psi, 9.88ppg ECD, 2.3k DWOB & 128-108fph ROP, ap 4551psi, bp i 5476psi, IA 363psi, OA 411 psi, swapped well to new Flo-Pro Printed: 8/15/2007 1:40:04 PM ~ ~ Bl~ EXPLC?~=tATIC~N ' Pa~~ ~ of t8 ' 4per~tions Summar~ Repar# Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Qate i From - To Hours Task Cotie NPT Phase Description of Operations 7/31/2007 i 10:45 - 12:00 i 125 DRIL~ C PROD1 Mud, sent returns to MI for recycie I 12:00 - 12:55 ~ 0.92 DRILL C PROD1 Drill to 11037' with 90L TF, 1.65/1.65bpm, 3050/3350psi, 9.5ppg ECD, 2k DWOB & 100fph ave ROP. 12:55 - 13:35 0.67 DRILL C PROD1 Wiper trip clean to 10300' (below OHST pt). RBIH clean to btm. 13:35 - 16:10 2.58 DRILL C PROD1 Drill to 11201' with 70-90L TF, 1.65/i.65bpm, 3050/3350psi, 9.5ppg ECD, 2k DWOB & 70fph ave ROP. Drilling thru Zone 1 B interbedded sandstones & shales. i 16:10 - 17:05 0.92 DRILL C PROD1 Wiper clean to 10300' (below OHST pt). RBIH clean to btm. ~ 17:05 - 18:45 ~ 1.67 DR~LL C PROD1 Drill to 11349' with 120R TF, 1.65/1.65bpm, 3050/3350psi, ; 9.5ppg ECD, 2k DWOB & 105fph ave ROP. 18:45 - 19:40 0.92 DRILL C PROD1 Wiper clean to window. 19:40 - 19:55 0.25 DRILL C PROD1 Log down GR @ 135fph & tie-into formation marker -- Add 2' to BHI & 1.5' to SLE3. 19:55 - 20:25 0.50 DRILL C PROD1 RBIH clean to btrn. 20:25 - 21:50 1.42 DRILL C PROD1 Drill to 11384' with 80-150R TF, 1.65/1.65bpm, 3050/3350psi, 9.6ppg ECD, 2k DWOB & 30fph ave ROP. Wt stacking. ~ 21:50 - 00:00 2.17 DRILL C PROD1 Drill lateral, 1.7 bpm, 3050/3400 psi, 180R TF, 9J ecd, slow ROP. Stacking wt, not sliding. ', ~ Made a 200' wiper trip with same problem on bottom, drilling ~ shales. 30% chert in last GEO sample, before drilling into shales. Drilled to 11,402'. 8/1/2007 00:00 - 02:30 2.50 DRILL C PROD1 Drill laterat in shale, 1.7 bpm, 3050-3400 psi, 175L TF, 9.7 ecd, very slow rop, stacking wt, coil not sliding. Drilled to ~ 11,412'. i 02:30 - 05:20 2.83 DRILL C PROD1 Drill lateral in shale, 1.7 bpm, 3050-3400 psi, 175L TF, 9.7 ~ ecd, 2-3K wob, very slow rop, stacking wt, Drilled out of shale at 11,420'. ROP increased. Drilled to 11,473'. 05:20 - 06:25 I 1.08 DRILL C PROD1 Wiper trip to 10,300'. 30K up wt. Clean hole. RIH. Sat down at 10,560', fell thru, RlH ciean to bottom. 06:25 - 07:20 0.92 DRILL C PROD1 Drill to 11500' with 115R TF, 1.6/1.6bpm, 3050/3350psi, 9.75ppg ECD, 0-1 k DWOB & 30fph ave ROP. Wt stacking. 07:20 - 07:45 0.42 DRILL C PROD1 100' short wiper. 07:45 - 08:00 0.25 DRILL C PROD1 Drill to 11511' with 115R TF, 1.6/1.6bpm, 3050/3350psi, 9.8ppg ECD, 0-1k DWOB & 45fph ave ROP. Wt stacking. Will mix & pump multiple pills of lo-torq pilis to bring the whole mud system up to 4%. 08:00 - 09:15 i 1.25 DRILL P PROD1 Drill to 11591' with 60L TF, 1.6/1.6bpm, 3250/3550psi, 9.85ppg ECD, 0-2k DWOB & 65fph ave ROP. 09:15 - 10:40 1.42 DRILL P PROD1 Wiper trip clean to 10300'. RBIH clean to btm. 10:40 - 12:15 1.58 DRILL P PROD1 Drill to 11715' with 50L TF, 1,65/1.65bpm, 3250/3950psi, i 9.85ppg ECD, 0-2k DWOB 10-15k SWOB & 80fph ave ROP. Stacking wt on btm & difficult getting wt to btm. Decide to POOH to P/U agitator. 12:15 - 15:00 2.75 DRILL P PROD1 POOH clean to 10200'. Open up the EDC. Continue POOH to surtace. 15:00 - 15:15 ~ 0.25 DRILL P PROD1 Hold PJSM & THA for C/O drilling BHA. 15:15 - 16:15 1.00 DRILL P PROD1 S/B injector. Flush BHA with water & B/D with air. UO bit - 2/1/I with 2 plugged nozzles on the pilot. 16:15 - 16:45 0.50 DRILL P ~ PROD1 M/U nozzle, RIH & calibrate pipe straightener for 2" CT. CT I was straight Q 600psi. " " 16:45 - 17:45 1.00 DRILL P PROD1 M/U drilling BHA #11 with rerun Hycalog 2.7 x 3 SRX3408M I bicenter bit #8, 1.1deg X-treme motor, agitator, BHI FVS, HOT, Printed: 8/15/2007 1:40:04 PM ~ ~ BP' EXPLC~~~4'T'1C3N', Page 9 c~f 18' Operations Summary Report Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 C7ate : From - To Hours Task Cade NPT Phase ' Description of OperatiQns 8/1/2007 16:45 - 17:45 1.00' DRILL P PROD1 USMPR, DGS, DPS, EDC, P&C, SWP, LQC & UQC. Scribe tools. M/U injector & Initialize/function test BHI tools. 17:45 - 20:10 i 2.42 DRILL P PROD1 RIH drilling BHA #1 t straightening bottom 4000' of CT. RIH to ~ 10250'. 20:10 - 20:30 0.33 DRILL P PROD1 Log GR tie-in. Add 11' to CTD. 20:30 - 21:30 1.00 DRILL P PROD1 RIH clean to bottom. Tag at t1,710'. 21:30 - 22:30 1.00 DRILL P PROD1 Drill Zone 1 B lateral, 1.4 bpm, 3500-4000 psi, 90L, 55 fph, j 1 K WOB, 9.9 ecd, ~ swap to new FloPro. Drilled to 11,744'. BHI HOT tool failed. 22:30 - 00:00 ~ 1.50 DRILL N DFAL PROD1 POH for BHI orienter failure. Continue with mud swap while POH. 8/2/2007 00:00 - 02:00 2.00 DRILL N DFAL PROD1 POH for failed BHI orienter. Swapped to new FloPro while POH. 02:00 - 02:15 0.25 DRILL N DFAL PROD1 SAFETY MEETING. Reviewed procedure, hazards and ~ mitigation for C/O BHI BHA. 02:15 - 04:30 2.25 DRILL N DFAL PROD1 C/O orienter, check bit, Bit graded at ( 1,1,1 ), re-run bit, motor ( OK, Rest of BHI tools OK. I , Check scribe line orientation. ~ Orienter was only tool that was changed out. 04:30 - 07:10 2.67 DRILL N DFAL ~ PROD1 RIH with Lateral / RES BHA #12 with BC Bit #9, 1.1 deg motor and Agitator. Circ at min rate. OAL = 75.64'. , i Straighten bottom 4000' of coil with 600 psi hyd pressure on pipe straightener. I Continue to RIH to 10270'. 07:10 - 07:25 025 DRILL N DFAL PROD1 Log down GR Q 135fph & tie-into formation marker - Add 10' to BHI & subtract 4' from SLB. 07:25 - 08:00 0.58 DRILL N DFAL PROD1 RIH & tag @ 10509' (14N shale). P/U & observe hi-circ pressure of 1.5bpm/4000psi & ECD of 11.3 -- indicating annular pack-off. Work shales with as-drilled TF 2x from 10450 to 10600' & cleanout area. 08:00 - 08:30 0.50 DRILL N DFAL PROD1 Continue RIH clean. Tag @ 11420' (14N shale). P/U & run thru. ( Cont RIH clean to btm tagged @ 11743'. Establish freepsin @ 1.5bpm/3450psi. PVT = 338bb1s. IAP =0psi. OAP = Opsi. 08:30 - 10:05 1.58 DRILL P PROD1 Drill to 11833' with 90L TF, 1.5/1.5bpm, 3450/3850psi, 9.58ppg ECD, 9.5k CT wt, 7.5k SWOB, 2k DWOB & 65fph ave ROP. 10:05 - 10:15 0.17 DRILL P PROD1 Short BHA wiper. 10:15 - 11:15 1.00 DRILL P PROD1 Drill to 11899' with 85L TF, 1.5/1.5bpm, 3450/3950psi, 9.6ppg ECD, 6k CT wt, i ik SWOB, 2.5k DWOB & 75fph ave ROP. 11:15 - 13:00 I 1.75; DRILL P PROD1 Wiper trip clean to 10300'. RBIH with minor wt bobbles acros the 14N. 13:00 - 15:00 2.00 DRILL P PROD1 Drill to 11950' with 85L TF, 1.5/1.5bpm, 3450/3950psi, 9.6ppg ECD, 10k CT wt, 7k SWOB, 2.5k DWOB & 35fph ave ROP. Meanwhile held an SPCC (Spill Prevention, Conirol & Countermeasure) table-top spill drill & review with crew. 15:00 - 18:30 3.50 f DRILL P PRODi Drill to 11951' with 55L TF, 1.5/1.5bpm, 3450/3950psi, 9.6ppg ECD, -5k CT wt, 23.5k SWOB, 2.5k DWOB & 3fph ave ROP. Stacking wt & not making much progress. Suspect bit is balled up and/orjets are plugged. Pump down 10bbls of lo-vis (3% ~ ~ KCL) followed by 20bbls of hi-vis pill to cieanout the bit & hole. ~ i Circ to bit. Printed: 8/15/2007 1:40:04 PM ~ ~ BP' EXPLORATlU~' Pa~e t0 of 18 ; Operations Summ~ry -Repart Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 ' aate From - Ta H~urs Task ~ Code NPT Phase Description of C~perations ~ 8/2/2007 18:30 - 18:45 0.25 DRILL i P - ---- ; PROD1 - Pump at max rate of 1.55 bpm at 4100 psi, work bit up and i ; down off bottom to try and clear ports. I I ; No luck. Circ press is up and zero ROP with 4.8K BHI WOB. i j i, Ports are plugged with motor rubber. We found motor rubber I ~ I on shaker. 18:45 - 21:30 2J5 DRILL ; N I DFAL I PROD1 POH for motor failure. 3620 psi at 1.5 bpm free spin. Free i ': spin pressure dropped while POH. 21:30 - 21:45 0.25 DRILL i N ' DFAL PROD1 SAFETY MEETING. Review procedure, hazards and ~ ~ mitigation for changing out BHA. 21:45 - 00:00 2.25 DRILL N ~ DFAL PROD1 C/O motor, check bit, lay out RES tool. Trouble shoot BHI i I, tools. EDC was not working. C/O. I ~ Bit had 1 plugged side port with motor rubber. 8/3/2007 00:00 - 01:10 1.17 DRILL N DFAL PROD1 M/U lateral BHA #13 with 1.1 deg motor, HYC BC bit #10 with ( Agitator. OAL = 66.04'. Test BHI tools at surface, OK. Test Agitator, OK. Swapped back to original blue rig cuttings tank after Veco repairs and leak testing. 01:10 - 03:45 2.58 DRILL N DFAL PROD1 RIH with Lat BHA #13 with 1.1 deg motor, BC bit and Agitator. circ at 0.1 bpm, 600 psi. Straighten 4000' of coil at 50 fpm, 600 psi. RIH. 03:45 - 04:00 0.25 DRILL N DFAL PROD1 Log GR tie-in. +13' BHI, -1' CTD. 04:00 - 04:45 0.75 DRILL N DFAL PROD1 RIH. Stacked wt in shales at 10550', feil thru, RIH clean to bottom. 04:45 - 06:30 1.75 DRILL P PROD1 Drill Zone 1 B lateral, 1.5 bpm, 3410 - 3900 psi, 40-60 L TF, 60 fph, 2-3K WOB, Build incl up to 92 deg for GEO. Steady drilling at 60 fph. Drilled to 12,040'. 06:30 - 07:30 1.00 DRILL P PROD1 Drill Zone 1 B lateral to 12100' with 1.5 bpm, 3410 - 3900 psi, 40-60 L TF, 60 fph, 2-3K WOB. 07:30 - 10:00 2.50 DRILL P PROD1 Wiper trip to 10300' with minor O/pulls across shales. RBIH & , stack out @ 11080' ~ fall thru. RIH clean to btm. ~, 10:00 - 11:45 1.75 DRILL P PROD1 Drill to 12209' with 80L-70R TF, 1.55/1.55bpm, 3650/3850psi, I 9.85ppg ECD, 10k CT wt, 7k SWOB, 22k DWOB & 75fph ave 'i ROP. I 11:45 - 11:50 0.08 DRILL P PROD1 Short BHA wiper. ~' 11:50 - 12:15 0.42 DRILL P I PROD1 Drill to 12250' with 90R TF, 1.55/1.55bpm, 3650/3850psi, ' j 9.89ppg ECD, 10k CT wt, 7k SWOB, 2.2k DWOB & 100fph ' ~ ave ROP. ' 12:15 - 14:55 2.67 DRILL P i PROD1 Wiper trip to 10300' with minor bobbles across shales. RBIH clean to btm. 14:55 - 16:10 1.25 DRILL i P ~ ~ PROD1 Drill to 12324' with 90R TF, 1.55/1.55bpm, 3550/4050psi, I I 9.89pp9 ECD, 11 k CT wt, 6k SWOB, 2k DWOB & 70fph ave I ROP. Start stacking wt from 12324'. 16:10 - 17:20 1.17 DRILL P PROD1 Drill to 12324' with 90R TF, 1.55/1.55bpm, 3550/4050psi, 9.95ppg ECD, -3k CT wt, 20k SWOB, 1.5k DWOB & 70fph ave ROP. Stacking wt. 17:20 - 18:45 1.42 DRILL P PROD1 Wiper trip to window. Some motor work in shales at 10,550'. 18:45 - 19:10 0.42 DRILL P PROD1 Log GR tie-in at RA tag. Add 2.5'. 19:10 - 20:45 1.58 DRILL P PROD1 RIH. Stack wt in 14N shales at 10520, 10530 and 10560'. Back ream shales with 45R TF. Ream down clean. RIH clean to bottom. 20:45 - 22:30 1.75 DRILL P PROD1 Drill Zone 1 B lateral, 1.5 bpm, 3700-4200 psi, 100R, 92 deg I ( ~ ~ incl, 1-2K WOB, 10.0 ECD, 50 fph, ' Printed: 8/15/2007 1:40:04 PM ~ ~ BP' EXPLORATIC7N' Page ~1 of ~8 O~perations Summary Re~c~rt Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To'' Hours Ta~k C~de NPT Phase ' Description of (~{~erafions 8/3/2007 20:45 - 22:30 1.75 DRILL P i PROD1 Drilled to 12,500'. 22:30 - 23:10 0.67 DRILL P i PRODt Driil Zone 1 B lateral, 1.5 bpm, 3800-4200 psi, 100R, 90 deg I incl, 1-2K WOB, 10.0 ECD, 50 fph, I Drilled to 12533'. 23:10 - 00:00 0.83 DRILL P PROD1 ~ W iper trip to 10,300'. Overpull at 12030'. 8/4/2007 00:00 - 01:45 1.75 DRILL P PROD1 j RIH afier wiper up to 10,300'. Sai down once at 11,050'. RIH clean to bottom. 01:45 - 03:20 1.58 DRILL P PROD1 Drill Z1 B lateral, 1.5 bpm, 3750-4200 psi, 90R TF, 90 deg I incl, 1-2K WOB, 10.1 ECD, 90 fph, i Drilling clean sand. Drilled to end of polvqon at 12650'. 03:20 - 04:30 1.17 DRILL P ~ i PROD1 W iper trip to window. Overpull at 12,020'. 04:30 - 04:55 0.42 DRILL P PROD1 Log GR tie-in at RA tag. Added 4.5' CTD. 04:55 - 06:45 1.83 DRILL P PROD1 RIH. Ream 14N shales at 10,550' at 10 FPM, shales were ; clean. RIH, tag & confirm TD @ 12653'.~- 06:45 - 09:45 3.00 DRILL P PROD1 I POOH drilling BHA #13 faying in new ffopro liner piil in OH. Paint EOP flags for liner @ 9900' & 7400'. 09:45 - 10:00 0.25 DRILL P PROD1 OOH. Hold PJSM & THA for UD drilling BHA. 10:00 - 10:30 0.50 DRILL P ~, PROD1 UD drilling BHA#13. Bit grade - 2/2/I. 10:30 - 11:15 OJ5 CASE P i RUNPRD Bring in Baker tools & R/U for running completion liner. 11:15 - 11:30 0.25 CASE P ! RUNPRD Hold PJSM & THA for M/U & RIH with liner. 11:30 - 17:00 5.50 CASE P ~ RUNPRD M/U 2-3/8" STL rotating guide shoe, 1 float collar, 1 shoe jt, 1 float collar, spacer pup & landing collar. M/U & drift first 5jts of 2-3/8" STL 4.7# L-80 liner with Baker 1.89" x 12" drift. All jts ~ drifted OK. Continue M/U 81jts of 2-3/8" STL 4.7# L-80 liner. M/U pup, Baker Deployment sleeve & GS Spear. M/U FVS, BS, DPS, EDC, P&C, SWP, LQC, & UQC. M/U injector. OA BHA length - 2667.44'. ~ OAL of liner = 2,635.14'. 17:00 - 18:30 1.50 CASE P ~ RUNPRD RIH with liner on CT. Correct -4 ft at flag. Up wt above window ~ was 31.5K. RIH clean thru window. f 8:30 - 19:20 0.83 CASE P RUf4PRD Run in open hole. Sat down 10K in 14N shale at 10520'. RIH clean to 12270', sat down at 12, 270', 12322, 12480', 12510'. Now just not sliding, not formation problem. Work Liner to bottom. Land liner at TD at 12654' CTD. Sat down at same depth / wt, 2 times. Stack 8K WOB and pump at 1.1 bpm at 4000 psi. i Pick up clean off top of liner with 26K up wt. Top of liner deployment sleeve = 10,018'. PBTD = 12,613'. 19:20 - 21:00 1.67 CASE P RUNPRD POH with GS Spear and Coiltrak tools. 21:00 - 21:15 0.25 CASE P RUNPRD SAFETY MEETiNG. Review procedure, hazards and mitigation for L/O BHA. 21:15 - 22:00 0.75 CASE P RUNPRD UO GS Spear and Coiltrak tools. Recover 100%. 22:00 - 23:00 1.00 CEMT P i RUNPRD Load 1" CSH workstring into pipeshed. Workstring was inspected / cleaned at Tuboscope. 23:00 - 00:00 1.00 CEMT N WAIT RUNPRD Wait on Vac truck to deliver Bleach for coil pickle. Truck broke down. Strap 1" CSH workstring in pipeshed. 8/5/2007 00:00 - 00:45 0.75 CEMT N WAIT RUNPRD Wait on Veco bleach truck to arrive. Truck had mechanical problems. 00:45 - 01:00 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping fluids and blowing down with N2. Oi:00 - 02:00 1.00 CEMT P RUNPRD I Pump 20 bbl fresh water, 15 bbl bleach, 20 bbl fresh water, 15 Printed: S/15/2007 1:40:04 PM ~ ~ BP'' E~CPL4RATIQN ' `' Page 12 c~f ~8' Operatic~ns Summary Repc~rt Legal Well Name: G-25 Common W ell Name: G-25 Spud Date: 10/1/1986 Event Nam e: REENTE R+COM PLET E Start : 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALIST A Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 ~ate From - To Hours Task Code NPT Phase Description of ~peration~ 8/5/2007 ~ 01:00 - 02:00 1.00 CEMT P RUNPRD bbi inhibitor, 5 bbl MEOH. 02:00 - 03:15 , 1.25 CEMT P RUNPRD Blow down reel with N2. Bleed fluids and pressure to tiger tank. 03:15 - 03:45 0.50 CEMT P RUNPRD , Cut off CTC. M/U internal grapple. 03:45 - 04:00 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and i mitigation for pulling coil to reel. ~ 04:00 - 05:45 ~ 1 J5 CEMT P RUNPRD Puil test grapple. Pull coil stub to reel with tugger as backup. Secure coil on reel with cross bar and chains. Cut off stub. Position reel for bridge crane. Set reel brake and secure reel. Rig up bridge crane to pick reel. i 05:45 - 06:00 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for swapping reels with bridge crane. 06:00 - 08:00 2.00 CEMT P RUNPRD Open door and lower E-coil reel to trailer. Pick new E-Free coil off second trailer with bridge crane. Close bombay door. Set reel in support and drive pins of reelstand. This used reel has t5,000', HS-90, 0.156 wall CT with 273,401' running footage. 08:00 - 10:30 2.50 CEMT P RUNPRD M/U hardline to reel. Slip grapple connector into CT & pull test. 10:30 - 10:45 025 CEMT P RUNPRD PJSM & THA for stabbing CT into the injector. 10:45 - 11:15 ~ 0.50 CEMT P RUNPRD Pull CT across pipeshed & stab CT thru injector. 11:15 - 11:45 0.56 CEMT P RUNPRD M/U SLB CTC. Pull test to 35k - OK. ~~ 11:45 - 13:30 1.75 CEMT P RUNPRD Install dart catcher. Pump 3bbis of water. Load & launch wiper I dart. Chase dart with mud & pig CT. Did not observe dart bump after pumping 46bbls. S/D pump & reloadlpump dart. Dart bump on catcher @ 42.3bbls. P/test CTC, hardline to reel & , inner reel valve to 4000psi - OK. I 13:30 - 13:45 025 CEMT P RUNPRD PJSM for M/U & RIH with Baker LWP & LBRT. 13:45 - 14:30 0.75 CEMT P RUNPRD M/U Baker LWP, LBRT with XOs & 1 jt of 2-1/16" CSH tbg, OAL - 41.76'. M/U injector. 14:30 - 16:45 2.25 CEMT P RUNPRD RIH with LBRT BHA circ @ min rate. Wt check Q 9800': Up = i 27k. Run-in wt = 14k. Continue RIH smoothly & tag TOL @ ' 10037'. Set down 10k down @ 10041' & latch LBRT into I deployment sleeve. P/U Q 40k & confirm engagement. 16:45 - 17:30 0.75 CEMT P RUNPRD Establish circ. PUH to ball drop position @ 10027'. Load 5/8" steel ball & circ with mud @ 1.60/1.33bpm & 3750psi. Slow , i down pumps to 0.33/0.33bpm & 1510psi @ 30bbls away. Ball on seat @ 33bbls. Pressure up to 4200psi & release LBRT. P/U Q 27k & confirm release. Set back 10k down on LBRT. 17:30 - 20:30 3.00 CEMT P RUNPRD Circ weU to 2% KCL water with double friction reducer @ 1.51/1.33bpm & 2110psi. Send used FloPro to MI for ' I reconditioning. Meanwhile R/U SLB cementers. Mix 30bbis of ! 2ppb biozan KCL fluid. ~ 20:30 - 23:00 2.50 CEMT N RREP RUNPRD Change out breaker in SCR room. Test new breaker. 23:00 - 23:15 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and , mitigation for pumping liner cement job. ' 23:15 - 00:00 i 0.75 CEMT P RUNPRD Function test pump 1, 1.66 bpm, 1.33 bpm returns. 20% loss with KCL. Function test pump 2, 1.68 bpm, 1.37 bpm returns. Batch mix cement. Cement at wt at 2344 hrs. Press test cement line with 4000 psi. 8/6/2007 00:00 - 01:45 1.75 CEMT P RUNPRD Stage 17 bbls, 15.8 PPG, G, Cement. 1.1 bpm, 2600 psi, 0.9 bpm returns. stop pump, clean cement line. Insert dart. Zero in/out ~ totalizers. Press up to 500 psi. Printed: 8/15/2007 1:40:04 PM • ~ B~F~' E3CPLOFtATtC7N ' Page 1~ of 18 '' Opera~tic~ns ~umrnary Report Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To Hours ~ Task Code NPT Phase Description of Operations 8/6/2007 00:00 - 01:45 1.75 CEMT P RUNPRD Launch dart. Displace cement / Dart with 2# Biozan. i 10 bbl displ, 1.5 bpm, 3100 psi, 1.1 bpm returns ' ~ 20 bbl displ, 1.5 bpm, 2320 psi, 1.2 bpm returns, 26 bbls ! Biozan, swap to KCL ; II 30 bbl displ, 1.45 bpm, 2500 psi, 1.2 bpm returns I 35.3 bbl cement at shoe. Zero out totalizer. I 38 bbl displ, 1.2 bpm, 3400 psi, 0.95 bpm returns I 40 bbl displ, 1.0 bpm, 3300 psi, 0.82 bpm returns Dart landed on LW P at 42.8 bbl. Sheared at 4200 psi. ~ i 45 bbl displ, 0.8 bpm, 4100 psi, 0.65 bpm returns, ~ 47 bbl displ, 0.6 bpm, 4300 psi, 0.45 bpm returns, 9.4 bbl I { returns I 48 bbl displ, 0.55 bpm, 4300 psi, 0.35 bpm returns, 50 bbl displ, 0.4 bpm, 4400 psi, 0.26 bpm returns, ~ 51 bbl displ, 0.35 bpm, 4400 psi, 0.22 bpm returns, 12.2 bbl ! returns. ~ 52 bbl displ, 0.3 bpm, 4250 psi, 0.15 bpm returns, ' ; 52.8 bbl displ, Bumped LWP at calculated displ. 'I Held 4360 psi. No returns. 13.2 bbl on return totalizer. Bleed off press. Check fioats. Good test. ~ All cement volumes came in correct. Job went well except for ' high pressure. 01:45 - 03:20 !~ 1.58 CEMT P RUNPRD Pull out of deployment sleeve at 27K up wt. Contaminate cement at top of liner with 4 bbls biozan. ' ~ POH while replacing coii voidage. 0.6 bpm, 120 fpm. 03:20 - 03:30 ' 0.17 j CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for Lay out BHA and RIH with cleanout BHA. 03:30 - 04:00 0.50 CEMT P RUNPRD Lay out LBRT BHA. Recover 100%. 04:00 - 08:30 i 4.50 CEMT P RUNPRD M/U Liner Cleanout BHA #16, 1.85" Diamond Parbolic HCC ' mill, motor, cire sub, hyd disconnect and 90 jts of 1" CSH workstring. OAL of BHA = 2,758.28'. 08:30 - 12:30 ~, 4.00 CEMT P RUNPRD RIH slowly with cleanout BHA #t6 tili cement get to 500psi I I compressive strength. Tag cement stringer @ 10000'. Meanwhile conduct AAR with crew on BHA M/U by relatively new crew. 12:30 - 14:00 i 1.50 CEMT P RUNPRD Cleanout wellbore to 10100' with 1.07/107bpm, 2550psi & ! ~ ~ 150fph. Start getting cement contaminated returns (up to ~ 9,9ppg) from 81 bbls btms up (i.e. from +l-7100'). 14:00 - 16:30 2.50 CEMT P RUNPRD Cleanout wellbore from 10100' to 10400' with 1.07/107bpm, 2450psi & 650fph. RIH Q 35fpm from 10400'. Had 4k drag from 12100'. Mix & pump 30bbls of safe-lube pill. I Continue RIH to PBTD tagged 3x @ 12,594' uncorrected CTD. ~ PBTD = 12,613'. 16:30 - 18:30 2.00 CEMT P RUNPRD POOH cleanout BHA#16. 18:30 - 18:45 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and I mitigation for standing back CSH workstring in derrick. 18:45 - 22:00 I 3.25 CEMT P RUNPRD Drop 1/2" ball to open cire sub. Open cire sub. Standback 45 ' stds of 1" CSH workstring. ~ Crew change with Nordic at 2000 hrs. Held PJSM and continue standback CSH. , Lay out mill and motor. Printetl: 8/15/2007 1:40:04 PM . ~ BP EXPLfJRAT1C7N' Page 14 of 18 Operations Sumnnary Repor~ Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ; From - To Hours Task Cade NPT Phase ' Description of Operations „ ' ' - 8/6/2007 22:00 - 22:45 0.75 j CEMT I P ( _ RUNPRD - --- - Jet stack with swizzle stick. 22:45 - 23:00 025 ~ BOPSUF~ P RUNPRD SAFETY MEETING. Review procedure, hazards and i , J~ , mitigation tor BOPE Pressure testing. ~, 23:00 - 00:00 1.001 , BOPSUF~ P i RUNPRD Pressure / function test BOPE. Test witness waived by ~ AOGCC inspecter, John Crisp. 8/7/2007 00:00 - 06:30 6.50 BOPSUF~ P i RUNPRD Pressure and function test BOPE. Send test results to ' ~ AOGCC. 06:30 - 06:45 0.25 EVAL i N DPRB LOWERI PJSM on P/U & RIH MCNUCCUGR logging tools. 06:45 - 07:15 ! 0.50 EVAL ; N DPRB LOWERI Initialize & test logging tools. P/U tool into rig floor. Load CNL I source into SLB logging tool & lower MCNUCCUGR logging I tool into the well. 07:15 - 07:30 0.25 EVAL N DPRB LOWERI PJSM on P/U & RIH 1" CHS tbg. 07:30 - 10:00 2.50 EVAL N DPRB i LOW ER1 M/U logging BHA #17 with SLB MCNUCCUGR logging tool, lower MHA, XO, 44 stds of 1" CSH tbg, XO & upper MHA. M/U injector. 10:00 - 11:30 1.50 EVAL N DPRB LOW ERi RIH with logging BHA to 9300'. 11:30 - 12:15 0.75 EVAL N DPRB LOWERI Log down Q 30fpm from 9300'. Tag @ 9630'. PUH. RBIH clean thru 9630'. Tag @ 9995', (suspect top of 2-3/8" Liner has cement pieces settled onto it). Set down 5 times with no progress. No circ ports on bottom of logging tool, so no way to clean up bottom area. 12:15 - 14:00 1.75 EVAL N DPRB LOWERI POH. 14:00 - 14:10 0.17 EVAL N DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. 14:10 - 15:30 1.33 EVAL N DPRB LOW ER1 Stand back 44 stds of CSH. 15:30 - 15:40 0.17 EVAL N DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS MCNL tools. 15:40 - 16:40 ( 1.00 ~ EVAL N DPRB LOW ER1 Lay out SWS MCNL tools. ~ M/U 2.75" mill, 2-3/8" motor, cire sub, hyd discon, checks and CTC. OAL = 13.40'. 16:40 - 18:15 1.58 EVAL N DPRB LOW ER1 RIH with cleanout BHA #18. circ at min rate. I Mix very high vis Biozan pill to cleanout hole. 18:15 - 19:15 1.00 i EVAL N DPRB LOW ER1 Sat down wt at top of 3-3/16" liner at 9400' CTD. Mill down thru top of liner top 2-3/8 liner at 10017'. 19:15 - 20:00 0.75 EVAL N DPRB LOWERi Polish top of liner pump 15 bbl pill. 20:00 - 21:30 1.50 EVAL N DPRB LOWERI POH. 21:30 - 23:30 2.00 EVAL N DPRB LOWERI LD BHA 18 Bit 2.74 Go 173 No Go. and PU BHA 19. 23:30 - 00:00 0.50 EVAL N DPRB LOWERI RIH. 8/8/2007 00:00 - 03:00 3.00 EVAL N DPRB LOWERI RIH to 10850'. Sweep well with 25 bbl bio. Clean trip. 03:00 - 05:30 2.50 EVA~ N DPRB LOW ER1 POH. 05:30 - 06:30 1.00 EVAL N DPRB LOW ER1 LD BHA 19 and standback 15 stands of CSH. 06:30 - 06:45 0.25 EVAL ~ N DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS memory CNL/GR tools. 06:45 - 09:15 2.50 EVAL N DPRB LOWERI M/U SWS memory CNVGR logging tool, ported XO, hyd disc, xo and RIH with 44 stds of 1" CSH M/U hyd disc, checks and CTC. BHA OAL = 2708.9'. 09:15 - 10:45 1.50 EVAL N DPRB LOWERI RIH with BHA #20, Memory CNVGR/CCL logging BHA. 10:45 - 11:30 0.75 EVAL N DPRB LOW ER1 Sat down at top of 2-3/8" Liner at 9986'. Work up / down I several times. i RIH faster and RIH to 9990', 4' deeper. Unable to work past 9990'. Try RIH with pump and no pump. ~ No Luck. Printed: 8/15/2007 1:40:04 PM . ~ BP EXPLORATION: Page 15 of 18 Operations Summary Repc~rt Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase C3escription af Operations 8/8/2007 11:30 - 13:00 1.50 EVAL N ~ DPRB LOW ER1 POH with logging BHA. Circ. 0.8 bpm at 1200 psi. 13:00 - 13:10 0.17 EVAL N I DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH Workstring. 13:10 - 14:45 1.58 EVAL N DPRB ~ LOW ER1 Stand back 44 stds of Workstring. 14:45 - 14:55 0.17 EVAL N DPRB ! LOW ER1 SAFETY MEETING. Review procedure, hazards and ~ mitigation for laying out SWS memory CNL/GR tools. 14:55 - 15:15 0.33 EVAL N DPRB ~ LOW ER1 Lay out logging tools. No marks on bottom of tools or bulinose. Tools OK. 15:15 - 16:00 0.75 EVAL N DPRB i LOWERI M/U 1.85" parabolic diamond mill, 1.69 motor, cire sub, hyd , ~ disc, xo, 7 stds CSH, hyd disc, lockable swivel, checks and I I CTC. BHA OAL = 444.08 16:00 - 17:55 1.92) EVA~ N DPRB LOW ER1 RIH with cement cleanout BHA #21. Circ. at min rate. RIH clean to 9900'. Stop and check max circ rate. Circ 2.0 I bpm at 3600 psi. full returns. ~ Stop pump. RIH. 13.5K down wt. Sat down at 10,027' CTD. ~ Top of liner is at 10,017'. minus 10' CTD has been the normal depth correction for this well. 17:55 - 18:30 0.58 EVAL N DPRB LOWERI ~ Pick up to 9950'. Circ. at 1.0 bpm, RIH. Very slight wt loss ~ and motor work at 10,027'. i All indications are cement / fines settling out at top of 2-3/8" ~ Liner. Continue RIH with no wt loss or motor work to 10,400'. 1.0 bpm, 1100 psi. Backream back up to 9900'. l.0 bpm, 30 fpm. ( RIH with 1.0 bpm pump again. No wt loss or motor work at top of tiner. 18:30 - 21:15 2.75 EVAL N DPRB LOW ER1 Circulate 1 bpm 1100 psi while making three passes between 10400 and 9900'. RIH dry 9900 to 10100'. @ 30fpm. No problem. Launch 1/2" AI ball with 1300 psi. Bump at 41.9 bbl at 4600 psi. 21:15 - 22:30 1.25 EVAL N DPRB LOW ER1 Circulate 22 bbl pill at 2.4 bpm @ 3730 psi. POH 70 Wmin. to 9900. RIH to 10400. Reciprocate while circulating bottoms up. Cement in returns. Spot 10 bbl Perf pili across liner top. 22:30 - 23:40 1.17 EVAL N DPRB LOW ER1 POH. 23:40 - 00:00 0.33 EVAL N DPRB ~ LOWERI LD BHA 21 cleanout assy and PU BHA 22 memory log. 8/9/2007 00:00 - 02:50 2.83 EVAL N DPRB i LOWERI MU memory logging BHA.without knuckle joint + 44 stands of i 1" CSH. 02:50 - 04:00 1.17 EVA~ N DPRB I LOW ER1 RIH to 9300'. 04:00 - 05:00 1.00 EVAL N DPRB LOWERI I Log down 30 fpm. Set down 10495'.Set down 7K . No Go. 05:00 - 07:00 2.00 EVAL N DPRB LOWERI I POH 07:00 - 08:30 1.50 EVAL N DPRB LOWERI I Standback CSH. 08:30 - 08:45 0.25 EVAL N DPRB LOW ER1 SAFETY MEETING. Review procedure, hazards and ~ mitigation for UO SWS memory CNL tools. 08:45 - 09:15 0.50 EVAL N DPRB LOW ER1 ~ Lay out logging BHA. ', 09:15 - 09:30 0.25 EVAL N DPRB LOW ER1 M/U Cleanout BHA #23 with 1.85" mill and 1.69" motor, circ ; sub, hyd disc and XO. 09:30 - 12:00 2.50 EVAL N DPRB LOWERI RIH with 44 stds of 1" CSH, M/U XO, Hyd Disc, Lockable Swivel , checks and CTC. BHA OAL = 2697.38'. 12:00 - 14:50 2.83 ~ EVAL N DPRB ~ LOW ER1 RIH with Cleanout BHA #23. RIH clean thru top of liner. Siight ~ wt loss and motor work at bridge at 10495'. Back ream and ream down thru that area. RIH at 40 fpm with 1.1 bpm to PBTD. Circ. high vis 4# Biozan pill at PBTD. Tag PBTD at Printed: 8/15/2007 1:40:04 PM • ` BP'' EXPLORATION P Op~rat~c~n~ Summary Report age t6 c~f 18 ' Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18l2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 i ` Date From - To', Hours Task Cade NPT Phase Descri~tic~n of Qperations -- - -- - _ ~ _ 8/9/2007 12:00 - i4:50 2.83 EVAL N DPRB LOWERI I 12,586' CTD. i 14:50 - 17:40 2.83 EVAL N DPRB LOWERI ~ ' Insert 1/2" AL ball and circ with second 16 bbl high vis Biozan i ~ ( sweep. Ball on seat at 45 bbls. Circ 1 J-1.4 bpm at 4200 psi. ~ ~ Pull up to 11,100'. Circ high vis pill to surface. 1.5 bpm , 4400 I~ psi, Pull to top of 2-3/8" liner. Reciprocate at top of liner from 9900-10030'. 17:40 - 19:45 2.08 EVAL N DPRB LOW ER1 Circ 20 bbl 15,000 CP FloPro. Circ in FloPro at max rate of 1.8 I bpm, 4300 psi from 10,600' to 9300'. Follow FloPro with 60 bbl I rig water. POH at max circ rate. to surface. RIH 500 pumping ( at max rate. Shut down pump. POH. Approx 1 Gallon of ~ cement & polymer nuggets recovered. Nuggets 1/2" soft like i marshmellows. 19:45 - 21:20 1.58 EVAL N DPRB LOWERI ! Standback 44 stands of 1" CSH. 21:20 - 2i:30 0.17 EVAL P LOWERI i PJSM for PU memory log without CNL. 21:30 - 23:30 2.00 EVAL P LOW ER1 I MU memory tools and RIH in 44 stands of CSH. 23:30 - 23:45 025 EVAL P LOW ER1 ~ PU and stab injector. 23:45 - 00:00 0.25 EVAL P LOW ER1 RIH. 8/10/2007 ~ 00:00 - 02:15 2.25 EVAL P LOW ER1 RIH to 9900 . PU wt 28.5K. RIH at .25 bpm. Tag at 12,627' ' uncorrected. 02:15 - 02:45 0.50 EVAL P LOW ER1 Circulate perf pill to logging tool. Displace with clean 2% KCL double slick. 02:45 - 04:00 1.25 EVAL P LOWERI j Log up at 45 ft/min per SLB.to 9300'. While spotting 15bb1 perf ~ pill at .24 bpm @ 45 fpm. 04:00 - 05:15 1.25 EVAL P LOW ER1 I POH 05:15 - 06:30 1.25 EVAL P LOW ER1 I~ Stand back CSH and LD logging tools. Crew change. 06:30 - 06:45 0.25 EVAL P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for standling back CSH. 06:45 - 08:00 1.25 EVAL P LOWERI Standback 1" CSH. Lay out logging tools. Faxed GR/CCL log to town. Geo confirmed that perforating intervals will stay the same and that a PBTD of 12,618' from the log will be used. 08:00 - 08:15 025 CEMT P RUNPRD ~ SAFETY MEETING. Review procedure, hazards and ~ ; mitigation for Pressure testing Liner lap. 08:15 - 10:15 2.00 CEMT P RUNPRD Pressure test liner lap with 2000 psi. Pressure up inner annulus with Little Red to 1000 psi for TIW 9-5/8" PKR. Pressure inner annulus to 2010 psi, End pressure after 30 min. was 9 0 psi. lost 60 psi in 30 min. Good Liner lan tact. 10:i5 - 10:30 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and ~ mitigation for Running SWS Perforating guns. 10:30 - 13:00 2.50 PERFO P LOWERI ~ RIH with SWS 1.56" HSD PJ perforating guns with firing head. 13:00 - 13:15 0.25 PERFO P LOW ER1 SAFETY MEETING. Review procedure, hazards and mitigation for running 1" CSH. 13:15 - 17:10 3.92 PERFO P LOWERI RIH with Hyd disc, XO and 37stds of 1" CSH, XO, hyd disc, lockable swivei, checks and CTC. ~ ~ BHA OAL = 2,785.21 ft. I I Tagged PBTD at 12, 625' , corrected dept to 12,618' at pick up. Position reel for bali drop. Circ. 8 bbi new high vis FloPro. 17:10 - 18:15 1.08 PERFO P LOWERI Insert 1/2" AL ball. Displace with FloPro. 8 bbis ahead, 7 bbl I ~ behind, 15 bbl total FloPro. Printed: 8/15/2007 7:40:04 PM • ~ :~P' E~PLC?RATION' Page t7 of 18' Operati€~ns Summ,ary Repart Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ' From - To ~ Hours Task Code NPT Phase Description of Qperations ---i----- - ' ` 8/10/2007 17:10 - 18:15 ! 1.08 PERFO P LOWERI --- Displace with KCL water, 1.1 bpm, 2000 psi. Position bottom shot at 12,613'. Circ ball on seat. Fire on the fly with bottom shot on depth at 12,610'. Good shot indication. 18:15 - 19:00 0.75 PERFO P LOWERI POH to 9950 . 19:00 - 19:35 ; 0.58 ~ ( PERFO P LOWERI Flow check at top of liner. No FLOW. 19:35 - 20:50 i 1.25 PERFO P LOW ER1 ~ POH Flag pipe EOP 6500'. POH ot BHA. 20:50 - 21:20 ~ 0.50I PERFO P LOWERI ~ Flow check. No FLOW. 21:20 - 23:00 i ~ 1.67' PERFO P LOWERI Stand back 37 stands of 1" CSH. 23:00 - 23:15 ~ 0.25I PERFO P LOWERI PJSM for LD perporating guns. 23:15 - 00:00 'i 0.75 i PERFO P LOWERI LD perfoaring assy #1. 8/11/2007 00:00 - 00:30 ~'I 0.50 ~ I PERFO P LOWERI LD balance of perfoaring assembiy #1. All shots fired. ~~ 00:30 - 02:30 2.00 PERFO P LOWERI Clear ffoor. Load pipe shed with run #2. ' 02:30 - 02:45 ~ I 0.25I PERFO P LOW ER1 PJSM for PU guns. 02:45 - 05:00 2.25 j PERFO P LOW ER1 PU 55 guns and bianks. SWS, PJ, 1.56", 6SPF. 05:00 - 06:45 I , 1 J5 ~ PERFO P LOW ER1 RIH with the same 37 stands of 1" CSH used on the last trip for I, ; correct BHA lenght. i ~ ~ ~ Crew change. 06:45 - 07:00 I~ 0.25 ~ PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and 07:00 - 08:30 ~ I I~ 1.50i PERFO P LOWERI mitigation for running CSH. RIH with remaining 1" CSH. Puli test CTC with 26K, press test i w/ 3600 psi, OK. M/U Hyd Disc, checks, locking swivel and CTC. BHA OAL = 3,467.77'. 08:30 - 10:30 2.00 i PERFO P LOW ER1 RIH with perforating BHA #26. Circ at min. rate. 0.2 bpm and I 130 psi. RIH to flag at 9,967.8'. Added 2.5' to CTD to correct to flag. RIH thru top of liner clean. RIH to ball drop point. Pump 10 bbl ' FloPro. 10:30 - 11:30 1.00 PERFO P LOWERI Insert 1/2" AL ball. Displace with 11 bbls FloPro, Pull bottom shot to 11,714'. displ with KCL. 1.1 bpm, 2000 psi. Ball on seat at 41 bbl. i Fired guns on the fly, on depth with bottom shot at 11,710'. ~ Firing head sheared at 4100 psi. ~ Good shot detection. 11:30 - 13:00 1.50I PERFO P LOW ER1 POH, no overpull, 27.5K up wt, circ 0.8 bpm, 1300 psi. j Pull to 9300'. ~ Flow check above top of liner. No flow. ~ POH to top of CSH. 13:00 - 13:30 0.50 PERFO P LOW ER1 Flow check at top of BHA. No flow. Held prejob Safety meeting during flow check time for standing back CSH workstring. 13:30 - 15:15 1.75 PERFO P LOWERI Stand back 37 stds of 1" CSH. 15:15 - 15:30 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired perf guns. 15:30 - 19:00 3.50 PERFO P LOWERI Lay out 55 guns/blanks. ell not taking fluid. Well is dead . oa out guns. 19:00 - 19:15 025 WHSUR P POST MU nozzel checks disconnect 19:15 - 21:15 I 2.00 WHSUR P POST RIH to 10000'. 21:15 - 21:30 I 0.25 WHSUR P POST Flow check well. No FLOW. 21:30 - 00:00 2.50 WHSUR P POST Circulate in 118 diesel from 10000'. 2.6 bpm 2800 psi .Shut in well. monitor 15 min dead. Pull dry from 6000'.Stop at 4600 open choke. slight vac. Continue to POH thru open choke. Printetl: 6/15/2007 1:40:04 PM ~ • ' BP; EXPLORAT'1QN ' Page 18 of ~8 Op~ra#ians Summ~ry Repor# Legal Well Name: G-25 Common Well Name: G-25 Spud Date: 10/1/1986 Event Name: REENTER+COMPLETE Start: 7/18/2007 End: 8/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 8/12/2007 Rig Name: NORDIC 1 Rig Number: N1 ' Date '' From - To Hours Task Code NPT Phase Description of Operations ~ --- -- -- - 8/11/2007 21:30 - 00:00 2.501 WHSUR P POST 8/12/2007 00:00 - 00:30 0.50!, WHSUR P POST POH to surface. Close master took 4.7 bbl to fill coil. Total I 1200' of voidage. Potential for 400 psi under balance. 00:30 - 03:15 2J51~ WHSUR P POST Jet stack. While holding PJSM for setting BPV with lubricaror. ~ ~ Reviewed new draft procedures BP's and Nordic. DSM has no I procedure for setting with lubricator only puliing. Pop off well. I LD swizzel stick. Set back injector. PU lubricator. PT lub 250 ' psi low and 950 psi high.Set BPV. Well on Vac.RD lubricator 03:15 - 03:25 0.17 ~~ W HSUR P POST PJSM for N2 blowdown. 03:25 - 05:00 I 1.58I~ WHSUR P POST Circulate coil with ,15 bbl bleach, 50 bbl fresh H2O, inhibitor, I ' MEOH, Followed by N2 blow down. 05:00 - 07:45 ~ 2.75! WHSUR P POST Pull coil stub to reel and secure it. I Pick up coil off reel stand with OH crane. 07:45 - 08:00 0.25I WHSUR P POST SAFETY MEETING. Review procedure, hazards and i ' mitigation for lowering reel onto Veco trailer. 08:00 - 09:00 i 1.00'~, W HSUR P POST Open bombay door. Lower E-free reel onto trailer and 4 point j I secure reel on trailer. 09:00 - 09:15 ~ 0.25I W HSUR P POST SAFETY MEETING. Review procedure, hazards and j mitigation for N/D BOPE. 09:15 - 12:30 ~ 3.25 ~I WHSUR P POST N/D BOPE. ~ , Clean cuttings box with supper sucker. I I i N/U tree cap and press test. ' RIG RELEASE AT 1230 HRS, 08/12/2007. ~ ~, TOTAL OF 20 DAYS AND 3 HOURS FROM RtG ACCEPT TO I RELEASE. ~i ALL FURTHER RIG INFORMATION WILL BE IN DIMS, WELL ' ~ I I I i i i i ~I i i ~I I I I I 02-16C Printed: S/15/2007 1:40:04 PM • i ~- ~~ BP Alaska ~~~~ ~ Baker Hughes INTEQ Survey Report l~v~r~:+~ Company: ;BP Amti~~ Date: $1~312~307 Time: 09:48:4$ Page: : 1 Fiel~: 'Prudht~e';B~y Co-ardinaEe(iV~~R~ference: ' Well: G-25, TrueiNorth Site: '~~f~B G 1~2~~! Vertieal (TVIf} R~`ferenee: ~~; 3'~ : 251 "if17119$6 00:4(7 72.4 R~ell: G-2~~ ~~~; - Seet~on (~S) Refieren~~: ', Well (Q.qdlV,O.OOE,~QT.4aAzi} WelEp~~h: ',~-~5RP~31 Survey Calcu~atxon M~thu+~: ~'~~, ~+tinimum Gurvature '~ D6: Oracte 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) Coardinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB G Pad TR-11-13 UNITED STATES : North Slope Site Position: Northing: 5966&32.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-25 Slot Name: 25 ~ G-25 I Well Position: +N/-S 2158.16 ft Northing: 5969032.00 ft Latitude: 70 19 19.434 N +E/-W 1998.11 ft Easting 658254.00 ft Longitude: 148 43 0.699 W - -~ Position Uncertainty: 0.00 ft - ~ Welipath: G-25BPB1 Drilled From: G-25AP61 500292165272 Tie-on Depth: 10203.57 ft Current Datum: 31 : 25 11/17/1986 00:00 Height 72.40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/27/2007 Declination: 23.67 deg Field Strength: 57653 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 3770 0.00 0.00 101.45 _~ --~ Survey Program for Definitive Wellpath I Date: 7/27/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 10168.30 1: Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 10203.57 10203.57 MWD (10203.57-11453.30) (3) MWD MWD - Startdard 10219.50 11549.00 MWD (10219.50-11549.00) MWD MWD - Standard ~ Annotation MD ' TVD . ft ft ' 10203.57 8752.13 TIP 10219.50 8764.84 KOP 11549.00 8924.21 TD Survey: MWD Start Date: 7l27/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path • e ~ ~~~~.~ ~~ BP Alaska ~~~ Baker Hughes INTEQ Survey Report ~~ ~A~~~ ~~,~~E~ iNT~(Z C6~npany: BP Amoeo Date: 8/23/2007 ~~, Time: 09;48:48 ~ ~age: ~ 2 ~ Fieldc Prudhoe.6ay Co-prdinate(NE) Reference: Virsll: G=2~, Tr~le' Nott61 , Sif~: ',P~ G Pad Vertical (TYD) Referenee: 31 : 25'11(17l19$6 Of1:4(J 72.4 Well. G~~ 3ection (VS) Reference: Well (O.QON;~_tltlE,"I01.451~i} WetlpaEh:_;G-2~BP~1 Survey Calculation Metho~i: ' Mitl'trnUYn CUruature ' Db: OraCle I Survey MD ' Inel Azim TYD ', Sys TUD N/S E/W MapN 1V~ap~+ ! T'S ALS Tool ' ft deg deg ' ft ft' ft ' ft ft ft #t ~legf70~ft I 10203.57 35.42 124.50 8752.13 8679.73 -12470 4672.69 5969005.86 662927.94 4604.46 0.00 MWD ' 10219.50 38.75 132.94 8764.84 8692.44 -130.72 4680.15 5969000.00 662935.53 4612.97 38.14 MWD i 10240.76 41.45 132.13 8781.10 8708.70 -139.97 4690.24 5968990.96 662945.81 4624.70 12.93 MWD 10269.98 45.62 131.15 8802.28 8729.88 -153.34 4705.28 5968977.92 662961.13 4642.09 14.46 MWD 10299.78 50.41 132.14 8822.21 8749.81 -168.06 4721.83 5968963.55 662977.98 4661.23 16.26 MWD 10332.29 55.38 133.91 8841.82 8769.42 -185.75 4740.76 5968946.26 662997.29 4683.30 15.89 MWD I 10361.73 59.98 136.59 8857.56 8785.16 -203.42 4758.26 5968928.97 663015.15 4703.96 17.41 MWD 10390.75 63.82 140.61 8871.23 8798.83 -222.63 4775.17 5968910.12 663032.46 4724.34 18.01 I MWD , 10420.67 69.14 143.80 8883.16 8810.76 -244.30 4791.96 5968888.81 663049.70 4745.11 20.29 MWD ~ 10458.97 72.98 149.39 8895.60 8823.20 -274.53 4811.88 5968859.00 663070.25 4770.62 17.06 MWD 10489.35 74.25 153.37 8904.18 8831 J8 -300.12 4825.83 5968833.73 663084.74 4789.38 13.25 MWD j 10519.07 76.70 157.82 8911.63 8839.23 -326.31 4837.71 5968807.79 663097.17 4806.22 16.67 MWD i 10550.32 78.65 163.00 8918.31 8845.91 -355.06 4847.94 5965779.26 663108.00 4821.95 17.35 MWD i 10580.14 78.25 167.39 8924.28 8851.88 -383.30 4555.40 596875L19 663116.05 4834.87 14.49 MWD ~ 10611.68 79.38 171.44 8930.40 8858.00 -413.71 4861.08 5968720.91 663122.37 4846.47 13.10 MWD i 10641.16 79.10 176.34 8935.91 8863.51 -442.49 4864.16 5968692.20 663126.06 4855.21 16.36 MWD ~ 10670.56 78.38 179.80 8941.65 8869.25 -471.31 4865.13 5968663.41 663127.64 4861.88 11.80 MWD ~ 10701.01 78.23 174.48 8947.83 8875.43 -501.08 4866.62 5968633.68 663129.76 4869.25 17.12 MWD ' ~ 10730.87 80.71 169.45 8953.29 8880.89 -530.13 4870.73 5968604.72 663134.47 4879.04 18.53 MWD 10761.07 85.38 165.09 8956.94 8884.54 -559.36 4877.34 5968575.65 663141.70 4891.32 21.08 MWD 10790.75 88.22 161.25 8958.60 8886.20 -587.71 4885.91 5968547.48 663150.87 4905.35 16.07 MWD 10821.99 89.57 157.04 8959.20 8886.80 -616.89 4897.03 5968518.54 663162.60 4922.04 14.15 MWD I 10851.05 89.14 153.04 8959.53 8887.13 -643.23 4909.29 5968492.47 663175.41 4939.28 13.84 MWD I 10881.82 86.89 149.00 8960.60 8888.20 -670.13 4924.19 5968465.90 663190.87 4959.22 15.02 MWD I 10915.67 90.18 145.96 8961.46 8889.06 -698.65 4942.37 596843776 663209.65 4982J1 13.23 I MWD I 10945.87 88.99 142.32 8961.68 8889.28 -723.12 4960.06 5968413.67 663227.85 5004.90 12.68 MWD ~~ 10976.39 88.65 137.23 8962.31 8889.91 -746.41 4979.76 5968390.81 663248.03 5028.83 16.71 MWD ~ 11006.27 91.44 133.11 8962.29 8889.89 -767.60 5000.82 5968370.07 663269.53 5053.68 16.65 MWD i 11037.68 94.27 129.01 8960.72 8888.32 -788.20 5024.46 5968349.98 663293.61 5080.94 15.85 MWD ( 11067.80 96.83 125.71 8957.81 8885.41 -806.38 5048.29 5968332.30 663317.80 5107.90 13.83 MWD ~ i 1109926 97.55 121.45 8953.87 8881.47 -823.65 5074.28 5968315.59 663344.16 5136.80 13.63 MWD ~ 11129.60 94.67 117.14 8950.64 8878.24 -838.40 5100.59 5968301.39 663370.76 5165.51 17.02 MWD ; 11159.28 89.32 111.40 8949.61 8877.21 -850.58 5127.61 5968289.79 663398.03 5194.41 26.42 MWD ~ 11189.60 93.41 109.87 8948.88 8876.48 -861.26 5155.97 5968279.71 663426.61 5224.33 14.40 MWD ~ 11220.16 94.71 113.66 8946.72 8874.32 -872.56 5184.27 5968269.01 663455.14 5254.31 13.08 MWD 11250.17 90.00 116.57 8945.49 8873.09 -885.28 5211.41 5968256.86 663452.54 5283.44 18.44 MWD 11280.29 91.45 119.56 8945.10 8872.70 -899.45 5237.98 5968243.26 663509.41 5312.29 11.03 MWD 11311.29 90.52 123.60 8944.57 8872.17 -915.68 5264.38 5968227.59 663536.14 5341.39 13.37 MWD 11341.41 93.60 128.31 8943.49 8871.09 -933.34 5288.74 5968210.44 663560.86 5368.77 18.67 MWD 11371.33 94.36 131.51 8941.41 8869.01 -952.49 5311.63 5968191.79 663584.15 5395.00 10.97 MWD 11403.76 95.40 135.90 8938.65 8866.25 -974.81 5334.98 5968169.96 663607.97 5422.32 13.86 MWD 11435.44 95.04 142.35 8935.77 8863.37 -998.65 5355.62 5968146.56 663629.10 5447.28 20.31 MWD 11468.97 96.80 146.30 8932.31 8859.91 -1025.74 5375.06 5968119.90 663649.11 5471.71 12.84 MWD 11509.14 95.47 154.14 8928.01 8855.61 -1060.38 5394.88 5968085.69 663669.65 5498.01 19.69 MWD 11549.00 95.47 154.14 8924.21 8851.81 -1096.08 5412.19 5968050.36 663687.71 5522.06 0.00 I MWD North Slope ' UNITED STATES ' Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Weil Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB G Pad TR-11-13 UNITED STATES : North Slope 'i Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg We1L• G-25 S1otName: 25 G-25 Well Position: +N/-S 2158.16 ft Northing: 5969032.00 ft Latitude: 70 19 19.434 N +E/-W 1998.11 ft Easting : 658254.00 ft Longitude: 148 43 0.699 W Position Uncertainty: 0.00 ft Wellpath: G-25B Drilled From: G-25BPB1 Tie-on Depth: 10240.76 ft Current Datum: 31 : 25 11/17/1986 00:00 Height 72.40 ft Above System Datum: Mean Sea Level Magnetic Data: 7/30/2007 Declination: 23.66 deg Field Strength: 57653 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 3770 0.00 0.00 104.75 Survey Program for Definitive WelJpath Date: 7/30/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 10168.30 1: Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 10203.57 10203.57 MWD (10203.57-11453.30) (3) MWD MWD - Standard 10219.50 10240.76 MWD (10219.50-11549.00) (5) MWD MWD - Standard 10257.00 12653.00 MWD (10257.00-12653.00) MWD MWD - Standard Annotation MD= TVI} ft ft 10240.76 8781.07 TIP 10257.00 8793.02 KOP 12653.00 8979.07 TD Survey: MWD Start Date: 7/30/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard T;ed-to: From: Definitive Path • • ~~ ~~ ~. ~~ BP Alaska 8~~~~~~ ~~*~~ Baker Hu hes INTE Surve Re ort -- g Q Y P i~v~ri:~ Company: ;BP Amp~o Date: 8l231 2Q07 Ti~e: 09t57:10 Page : 2 FYeld: Pru dhCte ~ay Co-ordinate(1 VE) Reference: ' WeU; G-25, T rue' M1totttt Site: ' PB G P2d Vertical (TVD) Reference: 31 : 25 1~/3 7119$6 Q0:00 72.4 Well: '~G-25 Seetion (VSj lteference: ~ Well (O.k30i~i,(~-OOE,~04.75~zi) WellgaEh: '' Cr25B ` Survey Calculatian 1Vlethnd: ! Minimum Curv~ture Db: Oracie Survey MD lucl ' A~im TYD Sys TVD N/S E/W MapN '. Map~ , ~?S bLS Tool ' ft deg d@g ft ft < ft ft ft'' ' ft ft degl1qOft' 10240.76 41.45 132.13 8781.07 8708.67 -140.01 4690.38 5968990.93 662945.95 4571.49 0.00 MWD 10257.00 43.77 131.57 8793.02 8720.62 -147.35 4698.57 5968983.77 662954.29 4581.27 14.48 MWD 10278.47 49.84 129.08 8807.71 8735.31 -157.46 4710.50 5968973.91 662966.44 4595.39 29.50 MWD 10308.99 50.28 121.50 8827.32 8754.92 -170.95 4729.58 5968960.82 662985.79 4617.28 19.09 MWD 10339.80 52.89 118.95 8846.46 8774.06 -183.09 4750.44 5968949.12 663006.90 4640.54 10.67 MWD I I 10370.30 56.27 117.20 8864.14 8791.74 -194.78 4772.37 5968937.90 663029.07 4664.72 12.03 MWD 10399.42 60.16 119.84 8879.48 8807.08 -206.61 4794.11 5968926.54 663051.05 4688.75 15.42 MWD 10432.61 64.16 122.74 8894.97 8822.57 -221.86 4819.17 5968911.82 663076.43 4716.87 14.31 MWD ', 10463.21 66.89 126.03 8907.65 8835.25 -237.59 4842.14 5968896.58 663099.73 4743.09 13.24 MWD ! 10495.28 70.37 129.11 8919.34 8846.94 -255.80 4865.80 5968878.87 663123J6 4770.61 14.06 MWD 'I I 10525.88 74.18 131.53 8928.66 8856.26 -274.66 4888.01 5968860.49 663146.37 4796.89 14.55 MWD I 10556.96 77.95 133.73 8936.14 8863.74 -295.09 4910.20 5968840.53 663168.98 4823.54 13.94 MWD 10588.33 81.66 135.52 8941.69 886929 -316.77 4932.17 5968819.32 663191.39 4850.31 13.09 MWD 10631.81 87.91 138.08 8945.64 887324 -348.32 4961.79 5968788.40 663221.67 4886.98 15.52 MWD 10662.27 90.06 141.62 8946.18 8873.78 -371.60 4981.42 5968765.55 663241.79 4911.90 13.60 MWD 10693.31 90.86 145.82 8945.93 8873.53 -396.61 4999.78 5968740.93 663260.67 4936.02 13.77 MWD ~ 10727.20 89.82 150.00 8945.73 8873.33 -425.32 5017.78 5968712.61 663279.27 4960.74 12.71 MWD i 10761.41 89.33 153.45 8945.99 8873.59 -455.44 5033.98 5968682.84 663296.11 4984.07 10.19 MWD ! 10793.77 87.11 156.23 8946.99 8874.59 -484.71 5047.73 5968653.86 663310.47 5004.82 10.99 MWD 10825.28 89.60 159.17 8947.90 8875.50 -513.85 5059.68 5968624.99 663323.03 5023.79 12.22 MWD 10856.10 87.49 155.70 8948.68 887628 -542.29 5071.50 5968596.80 663335.44 5042.47 13.17 MWD I 10888.58 85.73 152.34 8950.60 887820 -571.43 5085.70 5968567.97 663350.25 5063.62 11.66 MWD I 10918.77 85.61 147.99 8952.88 8880.48 -597.54 5100.67 5968542.18 663365.77 5084.74 14.37 MWD i 10953.58 85.67 144.50 8955.53 8883.13 -626.39 5119.96 5968513.74 663385.66 5110.73 10.00 MWD I 10987.64 87.21 138.83 8957.64 8885.24 -653.05 5141.03 5968487.54 663407.29 5137.90 17.22 MWD 11017.78 86.03 136.96 8959.42 8887.02 -675.37 5161.21 5968465.65 663427.93 5163.09 7.33 MWD 11048.71 87.39 134.86 8961.20 8888.80 -697.54 5182.69 5968443.94 663449.87 5189.51 8.08 MWD 11079.25 88.12 131.21 8962.39 8889.99 -718.37 5204.99 5968423.59 663472.61 5216.38 12.18 MWD I 11110.32 87.51 126.32 8963.58 8891.18 -737.80 5229.19 5968404.67 663497.21 5244.73 15.85 MWD 11143.20 90.25 123.85 8964.22 8891.82 -756.69 5256.09 5968386.35 663524.50 5275.55 11.22 MWD 11175.33 90.49 119.23 8964.01 8891.61 -773.49 5283.46 5968370.13 663552.22 5306.30 14.40 MWD 11207.35 90.98 122.81 8963.60 8891.20 -789.99 5310.90 5968354.22 663579.99 5337.03 11.28 MWO 11239.48 92.40 127.37 8962.65 889025 -808.45 5337.17 5968336.32 663606.65 5367.14 14.86 MWD i 11272.18 90.09 131.68 8961.94 8889.54 -829.25 5362.38 5968316.06 663632.29 5396.81 14.95 MWD ; 11300.68 89.26 135.86 8962.11 8889.71 -848.96 5382.95 5968296.79 663653.27 5421.73 14.95 MWD i I 11330.28 90.31 139.45 8962.22 8889.82 -870.83 5402.89 5968275.34 663673.66 5446.57 12.64 MWD ~ 11361.04 91.56 144.11 8961.71 8889.31 -894.99 5421.91 5968251.60 663693.19 5471.12 15.68 MWD I 11391.25 89.08 146.54 8961.55 8889.15 -919.83 5439.10 5968227.13 663710.89 5494.06 11.49 MWD 11425.93 86.53 147.68 8962.87 8890.47 -948.92 5457.91 5968198.43 663730.32 5519.66 8.05 MWD 11455.72 84.78 149.93 8965.13 8892.73 -974.33 5473.30 5968173.36 663746.23 5541.01 9.55 MWD 11486.40 90.06 151.46 8966.51 8894.11 -1001.05 5488.29 5968146.97 663761.78 5562.31 17.92 MWD 11517.24 89.33 155.56 8966.68 8894.28 -1028.64 5502.04 5968119.67 663776.12 5582.64 13.50 MWD 11554.11 87.18 153.60 8967.80 8895.40 -1061.93 5517.86 5968086.73 663792.63 5606.40 7.89 MWD 11592.13 84.96 146.61 8970.41 8898.01 -1094.79 5536.75 5968054.28 663812.21 5633.04 19.25 MWD 11623.73 87.39 143.54 8972.52 8900.12 -1120.63 5554.80 5968028.82 663830.79 5657.07 12.37 MWD ! 11665.97 87.27 136.11 8974.49 8902.09 -1152.85 5582.00 5967997.18 663858.67 5691.58 17.57 MWD ~ 11695.49 84.99 133.74 8976.48 8904.08 -1173.65 5602.85 5967976.83 663879.95 5717.03 11.13 MWD 11726.22 86.03 132.00 8978.89 8906.49 -1194.49 5625.30 5967956.47 663902.83 5744.05 6.58 MWD 11759.66 86.78 132.99 8980.98 8908.58 -1217.03 5649.91 5967934.45 663927.91 5773.59 3.71 MWD 11790.95 90.00 127.30 8981.86 8909.46 -1237.19 5673.81 5967914.81 663952.22 5801.83 20.89 MWD 11821.07 88.13 124.51 8982.35 8909.95 -1254.85 5698.20 5967897.67 663976.98 5829.91 11.15 MWD 11850.11 88.34 121.26 8983.25 8910.85 -1270.60 5722.57 5967882.43 664001.68 5857.49 11.21 MWD 11883.39 88.28 118.45 8984.23 8911.83 -1287.16 5751.42 5967866.49 664030.86 5889.60 8.44 MWD i i • - ,u ~~ BP Alaska ~~`~ ' Baker Hughes INTEQ Survey Report ~-: s~.~~~ ~~ E~ i~T~+~ Company: ',6P Am~cr~ Date: 812312E?(?7 Tirne: 09:57:1iI Page: 3 Field: `Prudhoei Bay ~ Co-ardinate(NE) Refer~nee: ' Well: G-25, TruE Narth '~PB Site: G P~d Vertiea] (TV~},Reference. '~~ 31 : 25 `11!'l7/19$6 OO:p072.4 Weil: '.G-2~ Sectia~ (~~) lteference: ' Wefl (Q.QO~l,(I.OQE,104 .7~AEi) WeSipa[h: `G-25B ' Suru~g ~a2cutatio~ Methad: ' Minimum Curvature ' Db: Oracle Survey '~YID Inel' A~im TUD Sys'CVD N/S Elf'4' MagN 'MapE ' ~'S DL$ Tool ft deg deg ' ft ft ft ' ft ft': ft ft degl100ft < 11917.21 86.68 116.30 8985.72 8913.32 -1302.70 5781.42 5967851.59 664061.18 5922.57 7.92 MWD 11948.27 86.68 112.52 8987.52 8915.12 -1315.51 5809.65 5967839.37 664089.68 5953.13 12.15 MWD 11980.94 90.09 109.96 8988.44 8916.04 -1327.34 5840.08 5967828.19 664120.35 5985.57 13.05 MWD 12011.40 90.25 105.88 5988.35 8915.95 -1336.71 5869.06 5967819.44 664149.51 6015.98 13.40 MWD 12041.08 92.09 102.87 8987.74 8915.34 -1344.07 5897.80 5967812.68 664178.40 6045.65 11.88 MWD 12071.58 93.66 98.79 8986.21 8913.81 -1349.79 5927.71 5967807.59 664208.42 6076.03 14.32 MWD 12102.05 95.63 94.74 8983.74 8911.34 -1353.37 5957.86 5967804.65 664238.64 6106.10 14.74 MWD 12136.75 92.80 95.04 8981.19 8908.79 -1356.32 5992.33 5967802.42 664273.17 6140.19 8.20 MWD 12167.78 91.17 97.98 8980.12 8907.72 -1359.84 6023.14 5967799.56 664304.04 6170.88 10.83 MWD 12198.04 85.71 102.40 8980.15 8907.75 -1365.19 6052.91 5967794.84 664333.92 6201.03 16.72 MWD 12228.92 90.86 109.42 8980.26 8907.86 -1373.65 6082.59 5967787.01 664363.77 6231.89 23.77 MWD 12258.74 92.09 112.99 8979.50 8907.10 -1384.43 6110.38 5967776.81 664391.77 6261.50 12.66 MWD 12288.10 90.34 116.47 8978.87 8906.47 -1396.71 6137.03 5967765.10 664418.68 6290.40 13.26 MWD 12319.73 92.68 122.29 8978.04 8905.64 -1412.21 6164.57 5967750.18 664446.54 6320.98 19.82 MWD 12351.23 91.40 126.92 8976.92 8904.52 -1430.08 6190.48 5967732.86 664472.81 6350.58 1524 MWD 12389.14 90.58 131.07 8976.26 8903.86 -1453.93 6219.93 5967709.64 664502.76 6385.14 11.16 MWD 12421.85 92.15 134.13 8975.48 8903.08 -1476.06 6244.00 5967688.03 664527.25 6414.04 10.51 MWD 12455.52 91.53 138.86 8974.40 8902.00 -1500.46 6267.16 5967664.12 664550.95 6442.65 14.16 MWD 12484.55 86.71 142.07 8974.85 8902.45 -1522.84 6285.63 5967642.14 664569.89 6466.21 19.95 MWD 12513.52 86.22 147.68 8976.63 890423 -1546.48 6302.26 5967618.86 664587.01 6488.31 19.40 MWD 12552.41 87.02 151.90 8978.93 8906.53 -1580.02 6321.79 5967585.74 664607.24 6515.74 11.03 MWD 12588.26 91.38 160.23 8979.43 8907.03 -1612.75 6336.31 5967553.33 664622.45 6538.11 26.22 MWD 12615.72 90.03 160.44 8979.09 8906.69 -1638.61 6345.55 5967527.67 664632.23 6553.63 4.98 MWD 12653.00 90.03 160.44 8979.07 8906.67 -1673.73 6358.03 5967492.52 664645.45 6574.64 0.00 MWD = - ~;_= t~c ~// V6+ELL§~1ER T~ NI~ EV C1Y ~a"c~u~ra~z= ~~ ~~~ ~ ~ca. ~..EV ~_. - ~~ ~:. ; [3F. E1.EV = _ 36.5~ ~ i K = ~~~,~~ i 775' ~ . ~ IMax Ang~ = . ~ _..`c~~ ~ ~~,.q~~' ~ ; C3a# m C7 - l t74t34' i C3atum TV I~ ~ 88bt1" SS ~ 3-31s° ~sG, ~~, t-s~, ic~ -~?.3~~~~ 1-I 2785" 9?~.9" 1--! a-~ rz°~ c~°rrs ;tA s~~er~t~~ s~v, !t~ = 3.~t 3,. _ --- ~'11nrrTt~m ~Cl ~ 1.9~~", 2-318"" ~~~~~x ~~~~~~; ~ ~-~ ~° x s-arie~~ x~, ~q = ~_so~ ~-~ '~3J1' ~ ~r2~• ~s~, ~~~s~, i~-st~, .Q~s2 npr, :a - ~.ss~° 945~' T~P Ct~ 5-112" ItJR ~~~"-~.: a3~~ Lla.,. .ii: "`' t,~"'°, c..~'~~t'a w"9&$~?.6.r. s-~f~~~ cs~. ~~~, ~ ~~, ~r~ s_~~~ ° '~~~ 97~4' ~,`~ 1 5-112" f~41LLt`~tST iNiNC~3W 1 Ci3 t58' - 10173' 5-9 f2" LN€~. 17#, L-Sfl, .{1232 bpf, I[3 = 4.8y2" '~0~~~1' P~F2F{)RATtt~N SUMlA}tRY R~ L~: ~~AtS RY GRlCCL, (18112fQ7 at~~~~~~r rc~~ ~t~~: rs ~ ~~,ss~~ ~Y~: f~G'~~~'f4 ~f4diiG1}4ti ~7$ ftaf hkSSfl(IG~~ (~Hff ~~:E~ ST~E 5RF lid°f°~F2VAL C}t~SW~QZ E}A7E i.56" 6, t t}S6~1- 1 Q740 O t~87t'[ If57 1.5~" ~i is377{1- 9Q~40 t~ fl$d19~f3i 1.5~" ti 1 fl~9D - t i 030 O D811 ~31U7 1,5£i" fi 1~ 19C? - t 13Sf3 C5 t}8l11 f(}7 i.5~r" 6 1°i 590 - 1171 Q Q t?811't f(}7 1.~" 6 12130 - 12'i JQ t3 Q8d11 ~Q7 i.~fi,• ~i t 22~ - 12270 £3 flSti 1 f~I7 1.S~i" 6 i 2~8~ - 124Sa t7 ~8I12lS17 1.56'" 8 1254fl ~ 126i£~ O t~ST'~3IGi7 T1lRt SBR TBG SEA L A SSY , IGr = 4.75(l" 9-51&~" x 4-i i2" TMt F~KR, [D = 4.7~"' ~L ~?~' J- L ~-~rzt~ ca-ns x r~fp. ~~= s:a~~~ I ~3$~° ' 3-314" 8KR Li~if2 LtEPLC?;f SLV, 1~'! = 3.i7Li" ~'~~' ~ ~#-1l2" OT6S XN NIP, ARtI.LEI~ T£3 3~8{~" 1C~ '~~$'~e'~' ~ E1.~t9D 7T Lt3GGEC) €1312&1~7 $4~' ' S-9t2" TiW sEAL ;~ssY wtt~ SEA1_s . ,~t~ E ~yY E~3gL. '~. «` Ii ~~S~a.J~ ~ ~ ~..,'~~ ~ i. °3-x~ 1~~~7~ °°~ E?~ t~ ~s'~„ ~ l~t~-~', ;~„;: ~~N~~~~' T~t ~~~ u-:~o~t~' ~ <~.~.:r~c.s~ ~ ~~J~31F~`~~C~~.t; ~tt~~~~' 1-f ~-~r~ s~~ x ~-~r~~ xc~, ~n = ~.~~r~,. ~~~i f~Tp ~ ~ t~CSRIZ~N7A L '~-- j 2-718" LN#~, S. ~ 6~', L-8~ STL PFtUDH((~E BAY U~ICT WELL; G258 3~Rtv1(T No: 207-(385Q AF~ No: 54-029-21652-Q2 SEC i 2, Ti 7 N, R3 ~~ BP F~pIoratdon {AIa~~Ca} ~ ~ d ~ ~ o ~ SARAH PAUN, GOVERNOR aa~ca-7~a ~~al ~sD ~7 333 W. 7thAVENUE, SUITE 100 CO1~T3ERQA7'IOI1T COrII~II59I011T ANCHORAGE,ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Garret Staudinger CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-25B BP Exploration (Alaska) Inc. Permit No: 207-086 Surface Location: 2617' FNL, 1973' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 4371' FNL, 641' FEL, SEC. 07, T11N, R14E, UM Dear Mr. Staudinger: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. ~Nhen providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907~„~659-3607 (pager). DATED this ~ day of June, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. , ~~j p /~ ~~ STAT~~F ALASKA ~~ ~ ~`"~~'~~~~ ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL ~I~~ ~a~~~ ~ ~ 2007 20 AAC 25.005 ,~, 4•~: ;,;; ~ Ga~ Cons. Cammissiar~ 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ~ Multipie Zone ^ Stratigraphic Test ~ Devefopment Oil ^ Single Zone 1 c. Specify if well is prop ~~ g ^ Coalbed Methane ~ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-25B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12700 TVD 8877 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2617' FNL 1973' FEL SEC 12 T11N R13E UM 7. Property Designation: ADL 028304 Pool , , , , . , Top of Productive Horizon: 2775' FNL, 2634' FEL, SEC. 07, T11 N, R14E, UM - 8. Land Use Permit: 13. Approximate Spud Date: July 25, 2007 Total Depth: 4371' FNL, 641' FEL, SEC. 07, T11 N, R14E, UM - 9. Acres in Property: 2560 14. Distance to Nearest Property: 16300' 4b. Location of Well (State Base Plane Coordinates): Surface: x-658254 y-5969032 Zone-ASP4 10. KB Elevation (Height above GL): 72.40 feet 15. Distance to Nearest Well Within Pool: 600' 16. Deviated Wells: Kickoff Depth: 10230 feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3220 SurFace: 2340 18: C sin Pr ram: S ~cafio n To - Settin De th - Bo ttom aanf of inent :f, or sa s Hole Casin Wei ht Grade Cou lin Len th MD ND MD TVD includin sta e data 3" 2-3/8" 4.7# ~-80 TCII / STL 2670' 10030' 8601' 12700' 8877' 84 cu ft Class 'G' 19. PRESE N7 WELL CONDITION SUMMARY (To be completed for Redrilt and Re-entry Operationsj Total Depth MD (ft): 12391 Total Depth ND (ft): 8949 Plugs (measured): N/A Effective Depth MD (ft): 12326 Effective Depth TVD (ft): 8953 Junk (measured): N/A Casing Length Size Cement olume MD ND Conductor / Structural 110' 20" cu ds Concrete 110' 110' Surface 2746' 13-3/8" 3890 cu ft Permafrost 2785' 2685' Intermediate Production 9688' 9-5/8" 590 cu ft Class 'G' 9724' 8337' Liner 707' S-1/2" 484 cu ft Class'G' 9462' - 10169' 8113' - 8723' Liner 3009' 3-3/16" x 2-7/8" 146 cu ft Class'G' 9382' - 12391' 8044' - 8949' Perforation Depth MD (ft): 10750' - 12320' Perforation Depth T1/D (ft): 8916' - 8953' 20. Attachments ~ Filing Fee, $100 ~ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564-4242 Printed Name Garret Staud'+n er Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4242 Date Sondra Stewman, 564-4750 Gommission Use Ont Permit To Drill Number:~~~4 60 API Number: 50-029-21652-02-00 Permit A prov See cover letter for Date: • • other re uirements Conditions of ApprovaL• ~y If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: U Samples Req'd: ^ Yes dNo Mud Log Req'd: ^ Yes ~No 35~~ eS~ ~~~ -~~- HZS Measures: [~Yes ^ No irectional Survey Req'd: [~ Yes ^ No Other: Date 6' O'd~ APPROVED BY THE COMMISSION , COMMISSIONER Form 10-401 Revised 12/2005 ~ G~ N A~.. C~ v~/ Submit In Dupticate ~ R ~~~o~ ~ BP Prudhoe Bay G-25B CTD Sidet~ CTD Sidetrack Summarv Pre-Rig Work: (Scheduled to begin June 30, 2007) 1) O Passed MIT-IA and MIT-OA. May 2, 2007 2) O AC -LDS; AC-PPPOT-IC, T 3) S Run dummy whipstock drift to 10245' 4) E Set 3-3/16" Baker Packer WS w/ HS orientation at 10230' ~~-a~~ 5) O PT Packer Whipstock to 2000 psi 6) O PT MV, SV, WV 7) O Bleed gas lift and production flowlines down to zero and blind flange ~ 8) O Remove wellhouse, level pad Rig Work: (Scheduled to begin July 25, 2007) 1) MIRU Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mi112.74" window at 10230' and 10' of rathole. Swap the well to Flo-Pro. 3) Drill Build: 3.0" OH, 370' (12 deg/100 planned) 4) Drill Lateral: 3.0" OH, 2100' (12 deg/100 planned) 5) MAD pass with resistivity tools in memory mode 6) Run 2-3/8" solid liner leaving TOL at 10030' 7) Pump cement leaving TOC at 10030' 8) Cleanout liner and MCNL/GR/CCL log 9) Test liner lap to 2000 psi 10) Perforate liner per asset instructions (~1000') 11) Freeze protect well and RDMO Post-Rig Work: 1) Install well house, flow line and gas lift valves. 2) Test Separator (~1000' of perfs) Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and a11 other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole Size: • 3.0" Casing Program: Fully cemented liner • 2-3/8", 4.7#, L-80, TCII or STL 10030'MD - 12700'MD • A minimum of 15 bbls 15.8 ppg cement will be used for liner cementing. Wetl Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 psi and 2500 psi. Directional ~ L_.I • See attached directional plan. Max. planned hole angle is 94 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -16,300 ft. North • Distance to nearest well within pool - 600 ft. (E-24) Logging • MWD directional, gamma ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run Hazards The maximum recorded H2S level closest to G-25 is 10 ppm (E-21A on 08/19/00). Lost circulation risk is low Reservoir Pressure • Res. press. is estimated to be 3220 psi at 8800'TVDss (7.0 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. WEILHEA~ McEVOY ACTUATOI~ OTIS KB. ELEV = 72.4' BF. ~EV = 36.5' KOP = 1775 Max Ang~ = 96 ~ 12214' Gatum ND = 10404' DatumND= 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2785' G -2 5A • SAFEfY NOTF3: W~L IXC~B 70° ~ 10477' 8 GOB I HORIZONTAL ~ 10688'. 2Q7Q' 41/2" SSSV OTIS LNDNG IWP, ~= 3.813" 9249' ~-~ 41/2" OT1S XA SLIDING SLV, ID = 3.813" Minimum ID = 2.372" ~ 10246' 3-3/16" X 2-7/8" XO ,ID=4. 9322' I~ 9-5/8" x 41/7' TNV PKR, ID = 4.750" 9376' 41 /2" OTIS X NIP, ID = 3.813" 9382' 3-3l4" BKR LNR DEPLOY SLV, ID = 3.00" 3-1/2" X 3-3/16" XO, ID = 2.80" 9391' 9416' 41 /2" OTIS XN NIP, MILLED TO 3.80" ID 41 /2" TBG, 12.61~, L-80, .0152 bpf, ID = 3.958" 9457' 9414' ELMD TT LOGGED 03/26/87 ~5' 5-1/2" TNVSEAL ASSY W!O SEALS TOP OF 5-1 /2" LNR 9461' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 9724' PERFORATION SUMW\RY ~ ~oc: sws cr~ o5rz7ro~ ANGLE AT TOP FERF: 87 @ 10625' Note: Refer to Production DB for historical perf data S¢E SPF INT9~VAL OPWSQZ QATE 2' 6 10750 - 10825 O 09/04/02 1-11/16" 4 10935 -10960 O 08/21 /03 1-11/16" 11125 - 11150 O 08/21/03 7' 4 11440 -11530 0 05/28/01 2" 4 11590 -11790 O 05/28/01 7' 4 11840 -12080 O 05J28X)1 2' 4 12180 - 12320 O 05l28J01 PBTD ~ 10557' ~• 5-1 /2" LNR 17#, L-80, .0232 bpf, ID = 4.892" 10600' • ~ 10168' TOP OF WHIPSTOCK ~-I1L NILLVUI VVIIVWVV ~m~~ _ ~mr.~~ 70246' 3-3/16" X 2-7/8" XO, ID = 2.372" . PBTD H 12326' I 12391' I QATE REV BY COMMBV'fS LIATE REV BY CANMBYTS 12104/86 ORIGINAL COMPLETION 06/12/04 CMO/PAG OWTUM CORRECTION 05/15/01 RNftlh CORRECTIONS 05/25/'01 CWKAK CTD SIDETRACK 09l04/02 JAF/KK ADPERF 09/16/a2 JLG/tlh MINIMUM ID CORRECTION 04/17/04 TVVCMAK PERF CORRECTIONS I 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, I ID = 2.372" PRUDI-IOE BAY UNIT VU~L: G-25A PERRIVNINT No: 1861620 AR No: 50-029-21652-01 SEC 12, T11 N, R14E BP F~tplorffilon (Alaska) WEILHEA~ McEVOY ACTUATOR= OTIS KB. ~EV = 72.4' BF. ~EV = 36.5' KOP = 1775' Max Angle = 96 ~ 12214' Datum fuD = 10404' Datum ND = 8800' SS G-25B [ Proposed CTD Sidetrack O C 13-3/8" CSG, 72#, L-80, ID =12.347" ~-i 2785' NOTES: WELL IXCEEDS 70° aLD ~ 4-1/2" SSSV OTIS LNDNG NIP, ID = 3.813" ~ 9249~ H 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" Minimum ID = 9308' I~ TNV SBR TBG SEAL ASSY, ID = ~ 9-5/S" x 4-1/2" TM/ PKR, ID = 4.750" ~ I 3-1l2" X 3-3/16" XO, ID = 2.80" ~ 9391' /2" TBG, 12.6#, 1-80, .0152 bpf, ID = 3.958" 9457' TOP OF 5-1/2" LNR SCMT TOC 3 3!' ~_tiii 9461' 9690' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9724' 5/01 5-1/2" MILLOUT 1MNDOW 10168' - 10173' 5-1/2" LNR. 17#. L-80. .0232 bof. ID = 4.892" ~ PERFORATION SUMMARY REF LOG: SWS CNL 05/27/01 ANGLE AT TOP PB~F: 87 @ 10625' Note: Refer to Roduction DB for historical pert data SIZE SPF INTH2VAL OPWSQZ DATE 2" 6 10750 - 10825 O 09/04l02 1-11 /16" 4 10935 - 10960 O 08/21 /03 1-11/16" 11125 - 11150 O 08/21l03 2" 4 11440 - 11530 O 05/28/01 2" 4 11590 - 11790 O 05/28/01 2" 4 11840 - 12080 O 05/28/01 2" 4 12180 - 12320 O 05/28/01 i 9375' H 4-1 /2" OTIS X NIP, ID = 3.813" I 9382' 3-3/4" BKR LNR DQ'LOY SLV, ID = 3.00" 9416~ 4-1/2" OTIS XN NIP, MILLm TO 3.80" ID 9414' ElMD TT LOGGm 03/26/87 9465' 5-1/2" TNV SEAL ASSY W/O SEALS 3 3i'~5" MILLOUT WINDOW propcsed 1C23C I 10030' ~ TOP OF 2 3/8" LWER TOC ~ ~ 10230' TOP OF WHIPSTOCK \ , -~.. ° ;,, a.,W,~:~ 10260' ~ z-7ie" CiBP ~ I 12700' 2-3/8" LNR, 4J#, L-80 STL, 1~1.920 DATE REV BY COMMBJTS DATE REV BY COMMENfS 12/04/86 ORIGINAL COMPLETION O6/12/04 CAAO/PAG DATUMCORRECTION 05/15/01 RWtlh CARRECTIONS 05/25/01 CWKAK CTD SIDETRACK 09/04/02 JAF/KK ADP~tF 09/16/02 JLGJtIh MINIMUM ID CORRECTION 04J17/04 TWC,JKAK PB2F CORRECTIONS 12391' ~--~ 2-7/8" LNR, 6.16#, L-80 STL PRUDHOE BAY UNff VV~L: G25A P9~MIT No: 1861620 AR No: 50-029-21652-01 SEC 12, T11 N, R14E BP Exploration (Alaska) ~ ~ bp BP Alaska ~S ~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BPAmOCO Dete: 6MW2007 Time: 19:08;56 I'a~e: 1 Field: Prudhoe Bay Co-ordiuAte(NE) Refereace: iNeil. Cr25, True North Site: PB G Pad Vertical (TVD) Refereuce: 31 : 2511/i7/1986 OQ:00 72.4 WeIL• G-25 - $ection (VS) Reference: Weil (O;OUN,~.OOE,135.OOAzi) Wellpathr Plan 3, G-25B Survey Calculatien Met6at: Minimum CurvBture , Db: Oracfe Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zooe: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datnm: Mean Sea Level Geomagnetic Model: bggm2006 Site: PB G Pad TR-11-13 UNITED STATES : North Slope Site PosiHon: Nort6ing: 5966832. 87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301. 39 ft Longitude: 148 43 59.013 W Position Uocertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 7.19 deg Well: G-25 Slot Name: 25 G-25 Well Position: +N/-S 2158.16 ft Northiog: 5969032. 00 ft Latitude: 70 19 19.434 N +E/-W 1998.11 ft Easting : 658254. 00 ft Longitude: 148 43 0.699 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, G-256 Drilled From: G-25AP61 Tie-on Depth: 10203.57 ft Current Datam: 31 : 25 11/17/1986 00:00 Height 72.40 ft Above System Datum: Mean Sea Level Magnetic Data: 6/10/2007 Declination: 23.90 deg Field Strength: 57661 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.70 0.00 0.00 135.00 Plan: Plan #3 Date Composed: 6/10/2007 Version: 10 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitnde -> ~--- Longitude -a Name Description T'VD +N/S +E/-W Northing EASting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft G-25A Polygon 72.40 -34.14 4748.68 5969098.00 663002.00 70 19 19.084 N 148 40 42.112 W -Polygon 1 72.40 -34.14 4748.68 5969098.00 663002.00 70 19 19.084 N 148 40 42.112 W -Polygon 2 72.40 -1583.93 6424.50 5967584.00 664710.00 70 19 3.829 N 148 39 53.244 W -Polygon 3 72.40 -1919.79 6176.34 5967243.00 664469.00 70 19 0.528 N 148 40 0.493 W -Polygon 4 72.40 -1293.82 5427.32 5967853.00 663707.00 70 19 6.690 N 148 40 22.333 W -Polygon 5 72.40 -1203.83 5192.15 5967938.00 663470.00 70 19 7.577 N 148 40 29.194 W -Polygon 6 72.40 -602.35 4513.63 5968525.00 662779.00 70 19 13.497 N 148 40 48.982 W G-25A Fault 1 72.40 -1332.79 5188.43 5967809.00 663469.00 70 19 6.309 N 148 40 29.305 W -Polygon 1 72.40 -1332.79 5188.43 5967809.00 663469.00 70 19 6.309 N 148 40 29.305 W -Polygon 2 72.40 -644.99 5396.99 5968501.00 663663.00 70 19 13.072 N 148 40 23.205 W G-25A Fault 2 72.40 -1480.52 4936.24 5967656.00 663220.00 70 19 4.857 N 148 40 36.666 W -Polygon 1 72.40 -1480.52 4936.24 5967656.00 663220.00 70 19 4.857 N 148 40 36.666 W -Polygon 2 72.40 -1392.34 5261.19 5967751.00 663543.00 70 19 5.722 N 148 40 27.183 W -Polygon 3 72.40 -1823.75 5796.25 5967331.00 664087.00 70 19 1.476 N 148 40 11.580 W -Polygon 4 72.40 -1392.34 5261.19 5967751.00 663543.00 70 19 5.722 N 148 40 27.183 W G-25A Fault 3 72.40 0.00 0.00 5969032.00 655254.00 70 19 19.434 N 148 43 0.699 W G-25A Target 1 8773.40 -132.79 4683.58 5968998.00 662939.00 70 19 18.114 N 148 40 44.014 W G-25A Target 3 8942.40 -1278.09 5819.77 5967877.00 664099.00 70 19 6.842 N 148 40 10.882 W G-25A Target 2 8943.40 -1030.28 5310.84 5968114.00 663585.00 70 19 9.283 N 148 40 25.727 W G-25A Target 4 8945.40 -1312.66 5941.07 5967845.00 664221.00 70 19 6.501 N 148 40 7.343 W ~ ~ ~ bp BP Alaska ~$ Baker Hughes INTEQ Planning Report 1NTEQ Cumpnny: BP Amoco Date: 6/10/2007 Time: 15:08:56 Pagr. 2 FieW: Prudhoe Bay Co-ordinate(NE) Refereqce: WeIC G-25, True Notth Site: PB G Pad Vertieai (1'VD) Refereece: 31 : 2511 /17/1986 00:OQ 72.4 We1L• G25 Sectios (VS) Retereece: Well (O:DdN,0 .00E,135.00Azi) Wellpat6: Plan 3; G-256 Survey Cakulation Method: Minimum Curvature Db: Orade Targets Map Map <--- LaHtude `--a ~c--- Loagitnde --> 1Vame Description TVD +N/-S +E/-W Northina Eastin~ Deg Mim Sec Deg Mi~ Sec Dip. Dir. ft ft ft ft ft G-25A Target 5 8950. 40 -1748.45 6256.98 5967416.00 664546.00 70 19 2 .213 N 148 39 58.136 W Annotation 1VID T~'D ft ft 10203.57 8752.13 TIP 10230.00 8772.89 KOP 10250.00 8787.75 End of 9 Deg/100' DLS 10350.00 8853.50 4 10650.00 8943.32 5 10830.00 8944.92 6 11130.00 8949.17 7 11230.00 8947.68 8 11530.00 8942.30 9 11830.00 8939.53 10 11930.00 8939.75 T 1 12130.00 8945.44 12 12250.00 8943.50 13 12350.00 8941.20 14 12700.00 8949.70 TD Plan Section Information NID 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 10203.57 35.42 124.50 8752.13 -124.70 4672.69 0.00 0.00 0.00 0.00 10230.00 41.23 137.83 8772.89 -135.52 4684.88 38.13 21.98 50.44 60.28 10250.00 42.80 136.59 8787.75 -145.34 4693.98 9.00 7.83 -6.62 330.00 10350.00 54.80 136.51 8853.50 -199.82 4745.67 12.00 12.00 0.00 360.00 10650.00 89.86 14526 8943.32 -41925 4921.34 12.00 11.69 2.92 15.00 10830.00 89.13 123.67 8944.92 -544.58 5049.04 12.00 -0.40 -11.99 268.00 11130.00 89.30 159.67 8949.17 -776.04 5232.04 12.00 0.06 12.00 90.00 11230.00 92.40 171.27 8947.68 -872.65 5257.08 12.00 3.10 11.60 75.00 11530.00 89.59 135.37 8942.30 -1136.25 5389.61 12.00 -0.94 -11.97 266.00 11830.00 91.43 99.41 8939.53 -1272.00 5651.61 12.00 0.61 -11.99 273.00 11930.00 88.32 87.82 8939.75 -1278.29 5751.23 12.00 -3.11 -11.59 255.00 12130.00 88.46 111.83 8945.44 -1312.16 5946.78 12.00 0.07 12.00 90.00 12250.00 93.39 125.37 8943.50 -1369.43 6051.85 12.00 4.10 11.28 70.00 12350.00 89.24 136.64 8941.20 -1434.91 6127.16 12.00 -4.14 11.27 110.00 12700.00 88.10 178.63 8949.70 -1751.27 6257.37 12.00 -0.33 12.00 92.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Too[ ft deg deg ft ft ft ft ft deg/100k ft deg 10203.57 35.42 124.50 8679.73 -124.70 4672.69 5969005.86 662927.94 0.00 3392.27 0.00 MWD 10225.00 40.02 135.57 8696.69 -133.15 4682.65 5968997.62 662938.08 38.13 3405.28 60.28 MWD 10230.00 41.23 137.83 8700.49 -135.52 4684.88 5968995.30 662940.36 38.13 3408.54 51.51 MWD 10230.68 41.28 137.78 8701.00 -135.85 4685.18 5968994.97 662940.67 9.00 3408.99 330.00 G-25A 10250.00 42.80 136.51 8715.35 -145.34 4693.98 5968985.68 662949.66 9.00 3421.91 330.03 MWD 10275.00 45.80 136.51 8733.24 -158.00 4706.00 5968973.27 662961.94 12.00 3439.36 360.00 MWD 10300.00 48.80 136.51 8750.19 -17i.33 4718.64 59689&0.22 662974.86 12.00 3457.73 360.00 MWD 10325.00 51.80 136.51 8766.16 -185.28 4731.88 5968946.55 662988.39 12.00 3476.95 360.00 MWD 10350.00 54.80 136.51 8781.10 -199.82 4745.67 5968932.31 663002.49 12.00 3496.99 360.00 MWD 10375.00 57.70 137.42 8794.99 -215.01 4759.85 5968917.42 663016.99 12.00 3517.76 15.00 MWD 10400.00 60.61 138.28 8807.81 -230.92 4774.25 5968901.81 663031.72 12.00 3539.19 14.49 MWD 10425.00 63.52 139.10 8819.52 -247.51 4788.83 5968885.53 663046.64 12.00 3561.23 14.05 MWD 10450.00 66.44 139.87 8830.09 -264.73 4803.54 5968868.63 663061.71 12.00 3583.81 13.67 MWD 10475.00 69.36 140.61 8839.50 -282.54 4818.35 5968851.14 663076.89 12.00 3606.87 13.34 MWD ~ ~ bp BP Alaska ~~s ~ Baker Hughes INTEQ Planning Report 1NTE Q Compaey: BP Amoco Date: 6/10/2007 Time: 19:08:56 Page: 3 FicW: Prudhoe Bay Co-ordiAate(NEJ Refereace: Well: G=25, Tn~e North Site: PB G Pad Vertical (TVD) Refererce: 31 : 25 11/17/1986 06:00 72.4 WeIL• G-25 Sectioe (VS) Reference: Weil (O.OON,O.OOE,135.OORzi) Welipath: Plan 3, G256 Survey Calculatiou Met6od: Minimum Curvature Db: OteGe Survey MD Incl Azim SS TVD N/S E/VV MapN MapE DLS VS TFO TauT ft deg deg ft ft ft ft ft deg/100ft _ ft deg: 10500. 00 72.28 141.32 8847.71 -300.88 4833.22 5968833.12 663092.14 12.00 3630.36 13.06 MWD 10525. 00 75.21 142.01 8854.71 -319.70 4848.10 5968814.61 663107.42 12.00 3654.19 12.83 MWD 10550. 00 78.13 142.68 8860.48 -338.96 4862.96 5968795.68 663122.68 12.00 3678.31 12.63 MWD 10575. 00 81.06 143.34 8864.99 -358.60 4877.76 5968776.35 663137.88 12.00 3702.66 12.48 MWD 10600. 00 84.00 143.98 8868.24 -378.56 4892.44 5968756.71 663152.98 72.00 3727.16 12.36 MWD 10625. 00 86.93 144.62 8870.22 -398.80 4906.98 5968736.78 663167.95 12.00 3751.75 12.28 MWD 10650. 00 89.86 145.26 8870.92 -419.25 4921.34 5968716.64 663182.73 12.00 3776.37 12.23 MWD 10675. 00 89.75 142.26 8871.00 -439.41 4936.11 5968696.79 663197.93 12.00 3801.07 268.00 MWD 10700. 00 89.65 139.26 8871.13 -458.77 4951.93 5968677.77 663214.14 12.00 3825.94 268.01 MWD 10725. 00 89.55 136.26 8871.31 -477.28 4968.73 5968659.63 663231.33 12.00 3850.91 268.03 MWD 10750. 00 89.45 133.26 8871.53 -494.88 4986.48 5968642.41 663249.45 12.00 3875.91 268.05 MWD 10775. 00 89.35 130.26 8871.79 -511.53 5005.12 5968626.15 663268.44 12.00 3900.86 268.07 MWD 10800. 00 89.25 127.27 8872.10 -527.18 5024.61 5968610.92 663288.25 12.00 3925.71 268.10 MWD 10825. 00 89.15 124.27 8872.45 -541.79 5044.89 5968596.74 663308.83 12.00 3950.38 268.14 MWD 10830. 00 89.13 123.67 8872.52 -544.58 5049.04 5968594.04 663313.04 12.00 3955.29 268.18 MWD 10850. 00 89.13 126.07 8872.82 -556.01 5065.45 5968582.96 663329.68 12.00 3974.97 90.00 MWD 10875. 00 89.14 129.07 8873.20 -571.25 5085.26 5968568.14 663349.81 12.00 3999.76 89.96 MWD 10900. 00 89.14 132.07 8873.58 -587.51 5104.24 5968552.29 663369.13 12.00 4024.68 89.92 MWD 10925. 00 89.15 135.07 8873.95 -604.73 5122.35 5968535.45 663387.60 12.00 4049.66 89.87 MWD 10950. 00 89.16 138.07 8874.32 -622.88 5139.54 5968517.67 663405.16 12.00 4074.65 89.83 MWD 10975. 00 89.17 141.07 8874.68 -641.91 5155.75 5968498.99 663421.77 12.00 4099.56 89.78 MWD 11000 .00 89.19 144.07 8875.04 -661.76 5170.94 5968479.47 663437.37 12.00 4124.34 89.74 MWD 11025 .00 89.20 147.07 8875.39 -682.37 5185.07 5968459.15 663451.93 12.00 4148.91 89.70 MWD 11050 .00 89.22 150.07 8875.73 -703.70 5198.11 5968438.11 663465.41 12.00 4173.21 89.66 MWD 11075 .00 8924 153.07 8876.07 -725.68 5210.01 5968416.39 663477.77 12.00 4197.16 89.61 MWD 11100 .00 89.27 156.07 8876.39 -748.25 5220.74 5968394.05 663488.98 12.00 4220.72 89.57 MWD 11125. 00 89.29 159.07 8876.71 -771.36 5230.28 5968371.15 663499.00 12.00 4243.80 89.54 MWD 11130. 00 89.30 159.67 8876.77 -776.04 5232.04 5968366.51 663500.86 12.00 4248.35 89.50 MWD 11150. 00 89.92 161.99 8876.91 -794.93 5238.60 5968347.76 663507.82 12.00 4266.35 75.00 MWD 11175. 00 90.70 164.89 8876.77 -818.89 5245.73 5968323.96 663515.45 12.00 4288.33 74.98 MWD 11200. 00 91.47 167.78 8876.30 -843.17 5251.63 5968299.81 663521.87 12.00 4309.68 75.00 MWD 11225 .00 92.24 170.69 8875.49 -867.72 5256.30 5968275.37 663527.05 12.00 4330.33 75.05 MWD 11230 .00 92.40 171.27 8875.28 -872.65 5257.08 5968270.45 663527.94 12.00 4334.38 75.15 MWD 11250 .00 92.23 168.87 8874.48 -892.33 5260.53 5968250.85 663531.80 12.00 4350.73 266,00 MWD 11275 .00 92.01 165.88 8873.55 -916.71 5265.99 5968226.59 663537.77 12.00 4371.83 265.90 MWD 11300 .00 91.79 162.88 8872.72 -940.77 5272.72 5968202.68 663545.00 12.00 4393.60 265.79 MWD 11325 .00 91.56 159.89 8871.99 -964.45 5280.70 5968179.18 663553.48 12.00 4415.98 265.69 MWD 11350 .00 91.33 156.90 8871.36 -987.68 5289.90 5968156.15 663563.17 12.00 4438.92 265.61 MWD 11375 .00 91.09 153.91 8870.83 -1010.40 5300.30 5968133.65 663574.05 12.00 4462.34 265.53 MWD 11400. 00 90.85 150.92 8870.41 -iU32.56 5311.87 5968111.75 663586.08 12.00 4486.19 265.47 MWD 11425. 00 90.61 147.92 8870.09 -1054.08 5324.59 5968090.50 663599.25 12.00 4510.40 265.42 MWD 11450 .00 90.37 144.93 8869.87 -1074.90 5338.41 5968069.97 663613.51 12.00 4534.90 265.38 MWD 11475 .00 90.13 141.94 8869.77 -1094.98 5353.30 5968050.22 663628.82 12.00 4559.62 265.35 MWD 11500 .00 89.88 138.95 8869.76 -1114.25 5369.22 5968031.28 663645.13 12.00 4584.51 265.34 MWD 11525 .00 89.64 135.96 8869.87 -1132.67 5386.12 5968013.23 663662.42 12.00 4609.48 265.34 MWD 11530 .00 89.59 135.37 8869.90 -1136.25 5389.61 5968009.73 663665.99 72.00 4614.48 265.35 MWD 11550 .00 89.72 132.97 8870.02 -1150.18 5403.96 5967996.10 663680.62 12.00 4634.48 273.00 MWD 11575 .00 89.88 129.97 8870.11 -1166.74 5422.69 5967979.94 663699.70 12.00 4659.43 273.01 MWD 11600 .00 90.03 126.98 8870.13 -1182.29 5442.26 5967964.81 663719.59 12.00 4684.26 273.03 MWD 11625 .00 90.19 123.98 8870.08 -1196.80 5462.61 5967950.73 663740.24 12.00 4708.92 273.03 MWD 11650 .00 90.35 120.99 8869.96 -1210.22 5483.70 5967937.76 663761.61 12.00 4733.32 273.02 MWD 11675 .00 90.51 117.99 8569.77 -1222.53 5505.46 5967925.91 663783.62 12.00 4757.40 273.01 MWD ~ ~ bp BP Alaska B~~ ~ Baker Hughes INTEQ Planning Report 1NTE Q Compaoy: BP Amoco Date: 6/10/2007 Time: 19:08:56 `Pa~e: : 4 Field: Prudhoe Bay Co-ordioate(NE) Reference: WeIL• G 25, True North Ske; PB G Pad Vertieal (TVDjReference: 31 : 2511/17/1986 fl0:00 72.4 We1L• G-25 Sectioe (VS) Reterence: Well (O.OON,O.OOE,135.OOAzi) ' Wellpath: Pla o 3; G-25B Sarvey Calcelatan Method: Minimum Curyature Db: Otacie Snrvey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO ' Tool' it deg deg ft ft ft ft ft deg/100Tt ' ft deg , 11700. 00 90.66 114.99 8869.52 -1233.68 5527.83 5967915.24 663806.22 12.00 4781.11 272.98 MWD 11725. 00 90.82 112.00 8869.20 -1243.64 5550.75 5967905.76 663829.34 12.00 4804.36 272.95 MWD 11750. 00 90.97 109.00 8868.81 -1252.40 5574.16 5967897.50 663852.93 12.00 4827.11 272.92 MWD 11775. 00 91.12 106.00 8868.35 -1259.91 5598.00 5967890.49 663876.92 12.00 4849.28 272.87 MWD 11800. 00 91.26 103.01 8867.$3 -1266.17 5622.20 5967884.74 663901.24 12.00 4870.81 272.81 MWD 11825. 00 91.40 100.01 8867.25 -1271.16 5646.68 5967880.28 663925.83 12.00 4891.65 272.75 MWD 11830. 00 91.43 99.41 8867.13 -1272.00 5651.61 5967879.54 663930.77 12.00 4895.73 272.68 MWD 11850. 00 90.81 97.09 8866.74 -1274.87 5671.40 5967877.09 663950.61 12.00 4911.75 255.00 MWD 11875. 00 90.03 94.19 8866.55 -1277.33 5696.27 5967875.15 663975.53 12.00 4931.08 254.95 MWD 11900. 00 8925 91.30 8866.71 -1278.53 5721.24 5967874.48 664000.52 12.00 4949.58 254.93 MWD 11925. 00 88.47 88.40 8867.21 -1278.46 5746.23 5967875.08 664025.50 12.00 4967.21 254.95 MWD 11930. 00 88.32 87.82 8867.35 -1278.29 5751.23 5967875.35 664030.49 12.00 4970.62 255.01 MWD 11950. 00 88.32 90.22 8867.93 -1277.95 5771.22 5967876.11 664050.46 12.00 4984.51 90.00 MWD 11975. 00 88.33 93.22 8868.66 -1278.70 5796.19 5967875.89 664075.45 12.00 5002.71 89.93 MWD 12000. 00 88.34 96.22 8869.39 -1280.76 5821.09 5967874.35 664100.39 12.00 5021.77 89.84 MWD 12025. 00 88.35 99.22 8870.12 -1284.12 5845.85 5867871.52 664125.21 12.00 5041.65 89.75 MWD 12050. 00 88.37 102.23 8870.83 -1288.77 5870.40 5967867.39 664149.85 12.00 5062.30 89.67 MWD 12075. 00 88.40 105.23 8871.54 -1294.70 5894.68 5967861.97 664174.24 12.00 5083.66 89.58 MWD 12100. 00 88.42 108.23 8872.23 -1301.89 5918.61 5967855.29 664198.32 12.00 5105.66 89.50 MWD 12125. 00 88.46 111.23 8872.91 -1310.32 5942.13 5967847.35 664222.01 12.00 5128.26 89.41 MWD 12130. 00 88.46 111.83 8873.04 -1312.16 5946.78 5967845.61 664226.70 12.00 5132.84 89.33 MWD 12150. 00 89.29 114.08 8873.44 -1319.96 5965.19 596783821 664245.27 12.00 5151.38 70.00 MWD 12175. 00 90.31 116.90 8873.52 -1330.72 5987.75 5967827.93 664268.05 12.00 5174.94 69.96 MWD 12200. 00 91.34 119.72 8873.16 -1342.57 6009.76 5967816.54 664290.30 12.00 5198.88 69.95 MWD 12225. 00 92.37 122.54 8872.35 -1355.49 6031.14 5967804.08 664311.95 12.00 5223.14 69.99 MWD 12250. 00 93.39 125.37 8871.10 -1369.43 6051.85 5967790.57 664332.95 12.00 5247.64 70.08 MWD 12275. 00 92.36 128.19 8869.85 -1384.38 6071.85 5967776.05 664353.25 12.00 5272.35 110.00 MWD 12300. 00 91.32 131.01 8869.04 -1400.30 6091.10 5967760.54 664372.83 12.00 5297.22 110.14 MWD 12325. 00 90.28 133.82 8868.69 -1417.16 6109.55 5967744.07 664391.64 12.00 5322.19 110.23 MWD 12350. 00 89.24 136.64 8868.80 -1434.91 6127.16 5967726.71 664409.61 12.00 5347.19 110.27 MWD 12375. 00 89.14 139.63 8869.15 -1453.52 6143.84 5967708.45 664426.68 12.00 5372.14 92.00 MWD 12400. 00 89.04 142.63 8869.55 -1472.98 6159.52 5967689.32 664442.77 12.00 5397.00 91.96 MWD 12425. 00 88.94 145.63 8869.99 -1493.24 6174.17 5967669.39 664457.84 12.00 5421.67 91.91 MWD 12450. 00 88.84 148.63 8870.47 -1514.23 6187.73 5967648.69 664471.84 12.00 5446.11 91.86 MWD 12475. 00 88.75 151.63 8871.00 -1535.90 6200.18 5967627.28 664484.74 12.00 5470.23 91.80 MWD 12500. 00 88.66 154.63 8871.56 -1558.19 6211.47 5967605.24 664496.50 12.00 5493.98 91.74 MWD 12525. 00 88.58 157.63 8872.17 -1581.04 6221.59 5967582.60 664507.09 12.00 5517.29 91.67 MWD 12550. 00 88.49 160.63 8872.81 -1604.39 6230.49 5967559.45 664516.49 12.00 5540.10 91.60 MWD 12575. 00 88.42 163.63 8873.48 -1628.17 6238.16 5967535.84 664524.65 12.00 5562.34 91.52 MWD 12600. 00 88.34 166.63 8874.19 -1652.32 6244.57 5967511.83 664531.57 12.00 5583.95 91.44 MWD 12625. 00 88.28 169.63 8874.92 -1676.78 6249.71 5967487.49 664537.23 12.00 5604.87 91.35 MWD 12650. 00 88.21 172.63 8875.69 -1701.46 6253.56 5967462.89 664541.60 12.00 5625.05 91.27 MWD 12675. 00 88.15 175.63 8876.48 -1726.32 6256.12 5967438.10 664544.68 12.00 5644.43 91.17 MWD 12700. 00 88.10 178.63 8877.30 -1751.27 6257.37 5967413.18 664546.45 12.00 5662.96 91.08 2 3/8"0 i i 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I ~~l...l.~ 1 I ~ ~ ~.. ~ i F I.I i.'- .1.1_l~ .~. ~_ 11.L (~1.1 ~ ~.~..~_l 1~._A1 ..~A-~l ~...1.1.1-~.1J.I 11,.. ~. ,$ ~ ~ bp BP Alaska Anticollision Report ~ ~.r ~i~s 1NTEQ Company: BP Amoco Date: 6/10i2007 Time: 19;14:00 Page: 1 FieW: Prudhoe Bay Reference Site: PB G Pad Co-ord'mate(NE) Refereuce: ' WeIL G-25, True North Reference We1L• G-25 Vertienl (TVDj Reterencec 31 : 25 11 /17F1986 00:OU 72.4 Reference Wellpath: Plan 3; G-25B ' Db: Orade GLOBAL SCAN APPLIED: All we0paths wit6in 200'+ 100/1000 of reference - There are'Ri~d~aeells in this99etd~pal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100,00 ft Error Model: ISCWSA Ellipse Depth Range: 10203.57 to 12700.00 ft Scan Method: Trav Cylinder North Maaimum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Pmgram for Definitive Wellpath Date: 6/1 0/2007 Validated: No Versioo: 4 Planned From To Sorvey Toolcode Tool Name ft ft 100.00 10168.30 1: Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 10168.30 10203.57 MWD (10203.57-11453.30) (3) MWD MWD - Standard 10203.57 12700.00 Planned: Plan #3 V10 MWD MWD - Standard Casing Points MD TVD Diameter Hok Size Name it ft in in 12700.00 8949.66 2.375 4.125 2 3/8"0" Summary <- -- Offset Welipath --> Reference Qftset Ctr-Ctr No-Go Allowable Site Well Weppath MD MD Distance Area DevuUion Warnie= ft ft ft ft ft PB C Pad C-17 C-17B V17 Out of range PB C Pad C-38 C-38 V1 Out of range PB E Pad E-18 E-18A V1 11093.54 12100.00 834.871123.69 -288.82 FAIL: Major Risk PB E Pad E-23 E-23B V5 12375.00 12713.50 1125.631066.00 59.63 Pass: Major Risk PB E Pad E-24 E-24A V1 10850.00 12247.07 659.94 656.72 3.23 Pass: Major Risk PB E Pad E-24 E-24AP62 V1 10239.87 11717.07 902.24 633.82 268.43 Pass: Major Risk PB E Pad E-32 E-32 V2 12575.00 12100.00 868.86 565.87 302.99 Pass: Majar Risk PB E Pad E-32 E-32A V4 12459.46 11700.00 1064.82 659.94 404.88 Pass: Major Risk PB E Pad E-32 E-32APB1 V1 12459.46 11700.00 1064.82 659.91 404.91 Pass: Major Risk PB E Pad E-32 E-32PB1 V1 12516.00 11900.00 977.81 622.27 355.54 Pass: Major Risk PB G Pad G-05 G-05 V2 11650.00 11100.00 1065.11 1487.94 -422.83 FAIL: Major Risk PB G Pad G-25 G-25 V3 10289.31 10300.00 38.631060.84 - 1022.21 FAIL: Major Risk PB G Pad G-25 G-25A V5 10297.90 10300.00 15.04 985.97 -970.93 FAII: Major Risk PB G Pad G-25 G-25AP61 V1 10297.90 10300.00 15.04 985.97 -970.93 FAIL: Major Risk PB G Pad G-25 G-25AP62 V4 10297.90 10300.00 15.04 985.97 -970.93 FAIL: Major Risk PB G Pad G-30 G-30A V1 Out of range Site: PB E Pad Well: E-18 Rule Assigned: Major Risk Welipath: E-18A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD NID TVD ReC Offset TFO+AZI TFO-HS Casiog/HSDistance Area Deviadon Warain~ ft ft ft ft ft ft deg deg in ft ft ft 10203.57 8752.09 10300.00 8252.77 201.26 245.00 59.60 295.10 9.625 2038.401064.73 973.67 Pass 10210.00 875729 10400.00 8338.28 198.27 248.41 59.94 291.88 7.000 1982.821076.94 905.88 Pass 10220.00 8765.20 10500.00 8424.26 192.91 252.55 60.50 287.32 7.000 1930.931091.21 839.72 Pass 10387.10 8873.69 10600.00 8509.72 167.17 232.08 60.89 283.04 7.000 1879.6f 1095.13 784.48 Pass 10448.55 8901.88 10700.00 8593.62 156.06 230.76 60.45 280.62 7.000 1826.891106.50 720.38 Pass 10900.00 8945.94 10800.00 8675.81 163.29 189.72 50.81 278.74 2.875 1774.411084.48 689.93 Pass 10900.00 8945.94 10900.00 8747.12 163.29 189.72 48.76 276.69 2.875 1707.671089.54 618.14 Pass 10909.30 8946.08 11000.00 8804.55 160.62 194.05 48.17 274.99 2.875 1628.311097.76 530.55 Pass 10912.04 8946.12 11100.00 8855.80 159.83 195.31 46.88 273.36 2.875 1539.951101.43 438.52 Pass 10910.79 8946.10 11200.00 8908.47 160.19 194.74 44.85 271.48 2.875 1453.081102.30 350.79 Pass 10914.11 8946.15 11300.00 8947.79 159.23 196.26 43.69 269.93 2.875 1361.961104.41 257.55 Pass 10925.00 8946.31 11400.00 8963.62 156.10 201.19 44.28 269.21 2.875 1269.531109.83 159.69 Pass 10936.27 8946.48 11500.00 8962.99 152.68 206.19 45.62 269.20 2.875 1181.381114.62 66.77 Pass 10950.00 8946.68 11600.00 8956.48 148.51 212.13 47.57 269.50 2.875 1100.551120.13 -19.58 FAIL 10975.00 8947.05 11700.00 8949.30 140.53 222.50 50.94 269.87 2.875 1029.441127.52 -98.08 FAIL 11000.00 8947.40 11800.00 8947.05 132.20 232.27 54.09 270.02 2.875 964.771132.16 -167.99 FAIL ~ ~ bp BP Alaska Anticollision Report ~ ~.-r ~NU~i~s INTEQ Coropany: 8P Amoco Ihte: 6/i W2007 Time: 19:14:00 Fa=e: 2 Field: Prudhoe Bay Refereuce Site: PB G Pad Co-erdinate(PiE) Rtfereece: Well: G-25, True North Reference We1L• G-25 Vertical (1'VD) Refereace: 31 : 25 1 1l1~/1986 OO:OQ i2.4 Reference Weppath: Plan 3, G-256 Db: Orade Site: PB E Pad Well: E-18 Rule Assigoed: Major Risk Weilpath: E-18A V1 Inter-Site Error: 0.00 ft Refereace Offset Semi-Major Aais Ctr-Cfr No-Go ' Allowabk MD T'VD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istaoce Area Deviation Waroiog ft ft ft ft ft ft deg deg in ft ft ft 11025.00 8947.75 11900.00 8943.58 123.53 241.43 57.34 270.27 2.875 910.771133.76 -222.99 FAIL 11059.89 8948.23 12000.00 8939.75 110.91 253.11 61.82 270.56 2.875 869.79 f 131.19 -261.39 FAIL 11093.54 8948.67 12100.00 8939.76 98.33 263.11 65.91 270.61 2.875 834.871123.69 -288.82 FAIL 12031.07 8942.65 12200.00 8935.48 210.86 44.56 10.46 270.51 2.875 804.95 799.29 5.66 Pass 12044.72 8943.04 12300.00 8934.43 210.04 52.24 12.29 270.69 2.875 711.51 819.79 -108.28 FAIL 12050.00 8943.19 12314.90 8934.95 209.72 55.25 12.89 270.66 2.875 698.03 827.85 -129.82 FAIL Site: PB E Pad Well: E-23 Rule Assigned: Major Risk Wellpath: E-23B V5 Inter-Site Error: 0.00 ft Reterence Of'~et Semi-MajorAxis Ctr-Ctr NaGo Allowable NID TVD MD 1'VD Ref Offset TFO+AZI TF0.HS Casing/H~tance Area Deviation Warning ft ft ft ft ft` ft deg deg in ft ft ft 12300.00 8941.41 11200.00 8926.82 168.32 178.37 41.35 270.35 2.875 2469.921072.84 1397.08 Pass 12300.00 8941.41 11300.00 8928.31 168.32 178.39 41.32 270.31 2.875 2374.941072.91 1302.03 Pass 12300.00 8941.41 11400.00 8929.47 168.32 178.38 41.31 270.30 2.875 2277.201072.88 1204.32 Pass 12289.78 8941.68 11500.00 8930.82 170.82 175.69 40.14 270.28 2.875 2191.071072.16 1118.91 Pass 12275.00 8942.21 11600.00 8932.36 174.43 171.72 38.42 27023 2.875 2100.021070.80 1029.23 Pass 12275.00 8942.21 11700.00 8940.35 174.43 171.71 38.22 270.03 2.875 2002.011070.78 931.23 Pass 12275.00 8942.21 11800.00 8940.04 174.43 171.70 38.24 270.05 2.875 1902.291070.77 831.52 Pass 12275.00 8942.21 11900.00 8942.97 174.43 171.71 38.12 269.94 2.875 1804.531070.81 733.72 Pass 12286.75 8941.78 12000.00 8944.69 171.56 174.88 39.42 269.90 2.875 1707.001071.93 635.07 Pass 12287.87 8941.74 12100.00 8937.34 171.28 175.18 39.80 270.16 2.875 1607.681072.02 535.66 Pass 12289.26 8941.70 12200.00 8934.92 170.94 175.55 40.05 270.26 2.875 1508.061072.13 435.93 Pass 12300.00 8941.41 12300.00 8936.26 168.32 1 ~8.38 41.23 270.22 2.875 1413.06 1073.06 340.00 Pass 12310.60 894120 12400.00 8931.87 165.57 181.12 42.60 270.40 2.875 1326.531073.25 253.27 Pass 12325.00 8941.06 12500.00 8934.04 161.84 184.73 44.14 270.32 2.875 1246.081073.18 172.89 Pass 12350.00 8941.16 12600.00 8934.10 155.03 190.67 46.98 270.34 2.875 1185.681070.93 114.75 Pass 12375.00 8941.52 12700.00 8927.09 147.41 196.53 50.36 270.73 2.875 1133.241065.91 67.33 Pass 12375.00 8941.52 12713.50 8925.78 147.41 196.54 50.44 270.81 2.875 1125.631066.00 59.63 Pass Site: PB E Pad Well: E-24 Rule Assigned: Major Risk Wellpath: E-24A V1 Inter-Site Error: 0.00 ft Refereace Offset Semi-MajorAais Ctr-Ctr NaGo - Allowable NID 1'VD MD TVD Ref Offset TFO+AZI TFO-HS Gasin~lH9~stauce Area Deviation Waroing ft ft ft ft ft ft deg deg in ft ff ft 10206.98 8754.86 11100.00 8938.44 199.68 30.10 23.34 256.93 7.000 1378.13 680.93 697.20 Pass 10210.00 8757.29 11200.00 8937.33 198.27 30.48 25.41 257.35 7.000 1296.89 674.11 622.78 Pass 10216.38 8762.36 11300.00 8934.81 194.85 30.89 28.12 256.73 7.000 1218.81 661.96 556.85 Pass 10220.00 8765.20 11400.00 8932.59 192.91 31.42 30.78 257.60 7.000 1144.20 651.99 492.21 Pass 10230.00 8772.85 11500:00 8931.38 186.70 32.04 34.37 256.54 7.000 1073.55 631.50 442.05 Pass 10276.40 8806.58 11600.00 8929.54 183.04 31.36 36.72 260.21 7.000 1005.99 624.00 382.00 Pass 70321.65 8836.45 11700.00 8925.11 177.35 30.72 39.58 263.08 7.000 941.31 612.77 328.54 Pass 10371.69 8865.58 11800.00 8927.00 169.95 30.45 42.57 265.26 7.000 883.48 600.03 283.44 Pass 10421.24 8890.19 11900.00 8931.84 160.99 30.97 45.75 266.78 7.000 830.42 584.95 245.47 Pass 10475.96 8912.20 12000.00 8933.84 151.23 31.90 48.94 268.30 7.000 778.74 570.44 208.30 Pass 10536.86 8929.96 12100.00 8934.33 141.31 33.20 51.98 269.65 7.000 729.97 557.66 172.30 Pass 10604.09 8941:01 12200.00 8936.02 132.52 34.84 54.51 270.42 7.000 685.38 546.55 138.83 Pass 10850.00 8945.19 12247.07 8936.87 176.35 28.83 36.80 270.73 7.000 659.94 656.72 3.23 Pass ~ ~ bp BP Alaska Anticollision Report ~ ~.r ~s INTEQ Company: BP Amoco Date: 6/10/2007 Time: 18:14:00 Pa~e: 3 Field: Prudhoe Bay Reference Site: PB G Pad Go-erd'wate(NE) Reference: WeIL• G-25, True Notth Refereace WeIL• G 25 VerHcal (TVD) Refereuce: 31 : 25 1 1/17/1986 00:0072.4 Refereace Wellpath: Plan 3, G-256 Db: Ot'aCle Site: PB E Pad Well: E-24 Rule Assigned: Major Risk Wellpath: E-24APB2 V1 Ioter-Site Error: 0.00 ft Reference Oftset Semi-MajorAxis Ctr-Gtr' NaGo Ailownble MD TVD MD T'VD Ref Offset TFO+AZI TFO-HS Casing/EI~istxnce Area' Devistion Warning ft ft ft ft ft ft deg deg in ft ft ft' 10203.57 8752.09 1 f 200.00 8944.95 201.26 30.16 20.10 255.60 1327.46 689.59 637.88 Pass 10207.46 8755.25 11300.00 8941.54 199.45 30.49 21.93 255.24 1238.93 682.88 556.05 Pass 10210.00 8757.29 11400.00 8941.64 198.27 30.90 23.79 255.72 1153.68 677.13 476.55 Pass 10220.00 8765.20 11500.00 8937.18 192.91 31.33 26.86 253.67 1070.70 660.49 410.21 Pass 10220.00 8765.20 11600.00 8930.37 192.91 31.92 29.26 256.08 990.70 655.23 335.48 Pass 10230.00 8772.85 11700.00 8924.26 186.70 32.52 33.11 255.28 914.69 634.13 280.56 Pass 10239.87 8780.23 11717.07 8923.44 186.51 32.34 33.44 256.28 902.24 633.82 268.43 Pass Site: PB E Pad Well: E-32 Rule Assigned: Major Ris k Wellpath: E-32 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Mejor Aais Ctr-Ctr No-Go Allowable NID TVD MD TVD Ref OtYset TFO+AZI TFO-HS Casiag/H~istance Area Deviatiou Waming ft R ft R ft ft deg deg in ft ft ft 12200.00 8945.53 9700.00 7590.99 190.11 46.67 63.06 303.34 4.000 2465.54 626.34 1839.20 Pass 12200.00 8945.53 9800.00 7663.56 190.11 47.19 62.33 302.61 4.000 2378.60 632.86 1745.74 Pass 12216.38 8945.05 9900.00 7736.43 186.98 49.59 63.40 301.83 4.000 2292.75 637.69 1655.06 Pass 12225.00 8944.72 10000.00 7809.70 185.33 51.09 63.50 300.96 4.000 2207.86 643.75 1564.11 Pass 1223629 8944.21 10100.00 7883.28 183.00 52.92 63.82 300.00 4.000 2124.20 649.75 1474.45 Pass 12250.00 8943.46 10200.00 7956.86 180.16 55.06 64.34 298.97 4.000 2042.11 655.63 1386.48 Pass 12250.00 8943.46 10300.00 8030.45 180.16 55.67 63.12 297.75 4.000 1960.91 664.49 1296.42 Pass 12263.57 8942.73 10400.00 8104.16 177.05 57.69 63.40 296.51 4.000 1881.30 669.03 1212.27 Pass 12275.00 8942.21 10500.00 8178.02 174.43 59.49 63.30 295.11 4.000 1803.66 674.68 1128.98 Pass 12275.00 8942.21 10600.00 8252.07 174.43 60.09 61.71 293.52 4.000 1727.81 684.55 1043.25 Pass 12291.28 8941.64 10700.00 8326.35 170.45 62.42 61.87 291.84 4.000 1654.47 688.12 966.34 Pass 12300.00 8941.41 10800.00 8400.57 168.32 63.98 61.00 289.99 4.000 1582.13 694.75 887.38 Pass 12312.15 8941.18 10900.00 8474.96 165.17 65.88 60.33 287.95 4.000 1512.88 699.39 813.49 Pass 12325.00 8941.06 11000.00 8549.38 161.84 67.85 59.51 285.69 4.000 1448.12 703.60 744.52 Pass 12336.96 8941.05 11100.00 8623.58 158.58 69.76 58.39 283.23 4.000 1387.65 707.18 680.47 Pass 12350.00 8941.16 11200.00 8694.84 155.03 71.84 57.32 280.68 4.000 1329.42 709.40 620.02 Pass 12367.92 8941.41 11300.00 8755.41 149.57 74.59 57.21 278.43 4.000 1268.76 706.63 562.14 Pass 12386.78 8941.70 11400.00 8805.47 143.64 77.40 57.52 276.48 4.000 1207.81 701.05 506.76 Pass 12407.77 8942.05 11500.00 8851.17 136.83 80.15 58.09 274.53 4.000 1151.61 691.87 459.74 Pass 12430.68 8942.46 11600.00 8889.53 129.14 82.97 59.08 272.77 4.000 1097.09 679.33 417.76 Pass 12450.00 8942.84 11700.00 8920.25 122.48 85.37 59.89 271.26 4.000 1040.87 667.91 372.96 Pass 12481.98 8943.52 11800.00 8934.01 111.05 88.66 63.02 270.55 4.000 989.76 644.30 345.46 Pass 12511.37 8944.20 11900.00 8939.21 100.26 91.51 66.30 270.30 4.000 944.10 621.18 322.91 Pass 12542.51 8944.97 12000.00 8939.44 88.63 94.18 70.08 270.35 4.000 903.46 594.91 308.55 Pass 12575.00 8945.84 12100.00 8936.47 76.39 96.58 74.25 270.62 4.000 868.86 565.87 302.99 Pass 12609.68 8946.83 12200.00 8930.75 63.54 98.65 78.89 271.10 4.000 842.08 534.07 308.02 Pass 12645.43 8947.91 12300.00 8927.79 51.01 100.24 83.48 271.40 4.000 823.80 501.79 322.02 Pass 12682.11 8949.08 12400.00 8926.48 40.40 101.35 88.06 271.58 4.000 821.65 473.34 348.31 Pass Site: PB E Pad Well: E-32 Rule Assigned: Major Risk Wellpath: E-32A V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Gtr No-Go Aliowable , MD TVD NID 7'VD Ref Oftset TFO+AZI TF0.HS CasinglHSDistance Area Deviation WarBing ft ft ft ft ft ft deg deg i~ ft ft ft'; 12200.00 8945.53 9700.00 7590.99 190.11 46.58 63.06 303.34 2465.54 626.05 1839.49 Pass 12200.00 8945.53 9800.00 7663.56 190.11 47.11 62.33 302.61 2378.60 632.57 1746.03 Pass 12216.38 8945,05 9900.00 7736.43 186.98 49.50 63.40 301.83 2292.75 637.39 1655.36 Pass 12225.00 8944.72 10000.00 7809.70 185.33 50.99 63.50 300.96 2207.86 643.44 1564.41 Pass ~ ~ ~ bp BP Alaska Anticollision Report ~.r B~s 1NTEQ Gompany: BP AmoCO Date: 6/10/2007 Time: 19;14:00 Page: 4 Field: Prudhoe Bay Reference Site: PB G Pad Co-ordioate(NE) Reterence: Well: G25, True Nordt Reference We1L• G-25 Verticaf (TVD) Reference: 31 : 251 1/17/1986 00:00 72A Reference Weitpath: Plan 3; G-256 Db: OraGe Site: PB E Pad Well: E-32 Rule Assigned: Major Risk Welipat6: E-32A V4 Inter-Site Error: 0.00 ft Reference Oftset Semi-Major Aais Ctr-Ctr No-Go AllowaWe NID TVD- NID TVD Ref Ot'fset TFO+AZI TFO-HS Casing/HSDistaece Area Devietion Wamiag ft ft ft ft ft ft deg deg in ft ft ft 12236.29 8944. 21 10100.00 7883.28 183.00 52.82 63.82 300.00 2124.20 649.43 1474.77 Pass 12250.00 8943. 46 10200.00 7956.86 180.16 54.96 64.34 298.97 2042.11 655.29 1386.81 Pass 12250.00 8943. 46 10300.00 8030.45 180.16 55.57 63.12 297.75 1960.91 664.15 1296.76 Pass 12263.57 8942. 73 10400.00 8104.16 177.05 57.59 63.40 296.51 1881.30 668.68 1212.62 Pass 12275.00 8942. 21 10500.00 8178.02 174.43 59.38 63.30 295.11 1803.66 674.31 1129.35 Pass 12275.00 8942. 21 10600.00 8252.07 174.43 59.98 61.71 293.52 1727.81 684.18 1043.63 Pass 12291.28 8941. 64 10700.00 8326.35 170.45 62.31 61.87 291.84 1654.47 687.73 966.74 Pass 12300.00 8941. 41 10800.00 8400.57 168.32 63.86 61.00 289.99 1582.13 694.34 887.79 Pass 12312.15 8941. 18 10900.00 8474.96 165.17 65.76 60.33 287.95 1512.88 698.96 813.92 Pass 12325.00 8941. 06 11000.00 8549.38 161.84 67.72 59.51 285.69 1448.12 703.16 744.96 Pass 12336.96 8941. 05 11100.00 8623.58 158.58 69.63 58.39 283.23 1387.65 706.72 680.93 Pass 12350.00 8941. 16 11200.00 8694.84 155.03 71.70 57.32 280.68 1329.42 708.92 620.50 Pass 12367.92 8941. 41 11300.00 8755.41 149.57 74.45 57.21 278.43 1268.76 706.13 562.63 Pass 12386.78 8941. 70 11400.00 8805.47 143.64 77.27 57.52 276.48 1207.83 700.57 507.26 Pass 72407.81 8942. 05 11500.00 8851.15 136.82 80.04 58.10 274.53 1151.78 691.43 460.36 Pass 12431.07 8942. 47 11600.00 8888.04 129.00 82.90 59.20 272.84 1098.24 678.59 419.65 Pass 12459.46 8943. 03 11700.00 8906.15 119.11 86.14 61.75 271.99 1064.82 659.94 404.88 Pass 12489.79 8943. 69 11800.00 8923.26 108.20 89.30 64.50 271.10 1069.30 637.89 431.41 Pass 12577.55 8944. 35 11900.00 8928.60 97.97 91.91 67.55 270.81 1109.74 615.88 493.86 Pass 12540.94 8944. 93 12000.00 8923.04 89.21 93.90 70.61 277.07 1170.21 596.11 5~4.09 Pass 12559.54 8945. 42 12100.00 8923.53 82.22 95.32 72.78 271.01 1245.41 579.81 665.60 Pass 12575.00 8945. 84 12200.00 8919.15 76.39 96.19 74.75 271.12 1337.60 565.08 772.51 Pass 12575.00 8945. 84 12300.00 8924.38 76.39 96.40 74.49 270.86 1434.92 565.75 869.17 Pass 12584.43 8946. 11 12400.00 8929.11 72.87 96.99 75.40 270.64 1526.97 557.14 969.83 Pass 12600.00 8946. 55 12500.00 8927.64 67.06 97.80 77.29 270.66 1609.42 542.40 1067.01 Pass 12609.95 8946. 84 12600.00 8926.96 63.45 98.44 78.50 270.67 1692.60 533.67 1158.93 Pass 12625.00 8947. 29 12700.00 8920.31 57.98 99.01 80.48 270.85 1776.65 519.21 1257.44 Pass 12635.17 8947. 60 12800.00 8918.81 54.51 99.62 81.74 270.89 1851.78 510.83 1340.95 Pass 12650.00 8948. 05 12900.00 8917.87 49.45 100.10 83.52 270.89 1928.90 497.31 1431.59 Pass 12660.69 8948. 39 13000.00 8911.99 46.25 100.57 84.95 271.04 2004.40 489.19 1515.21 Pass 12675.00 8948. 85 13100.00 8907.43 41.97 100.78 86.75 271.12 2086.40 477.02 1609.38 Pass 12675.00 8948. 85 13200.00 8908.17 41.97 101.27 86.73 271.10 2174.38 478.48 1695.90 Pass 12684.58 8949. 16 13300.00 8904.97 39.85 101.21 87.90 271.12 2270.78 471.67 1799.10 Pass 12685.78 8949. 20 13400.00 8896.86 39.59 101.24 88.19 271.27 2370.27 470.85 1899.43 Pass 12686.52 8949. 22 13500.00 8888.09 39.42 101.26 88.43 271.42 2469.81 470.31 1999.50 Pass Site: PB E Pad Well: E-32 Rule Assigned: Major Risk Welipath: E-32AP61 V1 Inter-Site Error: 0.00 ft Refereace Offset Semi-Major Axis Ctr-Ctr NaGo AllowaWe NID TVD NID 1'VD Ref Offset TFO+AZI TFO-HS Casieg/H~istance Area Deviation Warning ft ft ft R ft ft deg deg in ft ft ft 12200.00 8945 .53 9700.00 7590.99 190.11 46.58 63.06 303.34 2465.54 626.04 1839.50 Pass 12200.00 8945 .53 9800.00 7663.56 190.11 47.10 62.33 302.61 2378.60 632.55 1746.04 Pass 12216.38 8945 .05 9900.00 7736.43 186.98 49.50 63.40 301.83 2292.75 637.37 1655.38 Pass 12225.00 8944 .72 10000.00 7809.70 185.33 50.99 63.50 300.96 2207.86 643.43 1564.43 Pass 12236.29 8944 .21 10100.00 7883.28 183.00 52.82 63.82 300.00 2124.20 649.41 1474.79 Pass 12250.00 8943. 46 10200.00 7956.86 180.16 54.96 64.34 298.97 2042.11 655.28 1386.83 Pass 12250.00 8943. 46 10300.00 8030.45 180.16 55.56 63.12 297.75 1960.91 664.13 T296.78 Pass 12263.57 8942 .73 10400.00 8104.16 177.05 57.58 63.40 296.51 1881.30 668.66 1212.64 Pass 12275.00 8942 .21 10500.00 8178.02 174.43 59.37 63.30 295.11 1803.66 674.29 1129.37 Pass 12275.00 8942 .21 10600.00 8252.07 174.43 59.97 61.71 293.52 1727.81 684.15 1043.65 Pass u ~ bp BP Alaska Anticollision Report • ~.r ~ ~s LNTEQ Company: BP Amoco Datec 6/10/2007 Time: 19:t4;00 Pa=e: ` 3 F~Id: Prudhoe Bay Reference Site: PB G P8d Co-ordinate(NE) Reference: Weii: G-25, True Narth Refereace We1L• G-25 - Verdca[(TVD) Reference: 31 : 251 1/17/1988 Q0:00 72.4 Referenee Wellpath: Plan 3, G-256 Db. OraGe Site: PB E Pad WeIL• E-32 Rule Assigned: Major Risk Wellpath: E-32APB1 V1 Inter-Site Error: 0.00 ft Reference Offset Scmi-Major Axis Ctr-Ctr NaGo Allowable MD 1'VD MD TVD Ref Otfset TFO+AZI TFO-HS Casing/H~istaace Area Deviation Waroiqg ft ft ft ft ft ft deg deg in ft ft ft 12291.28 8941.64 10700.00 8326.35 170.45 62.30 61.87 291.84 1654.47 687.70 966.76 Pass 12300.00 8941.41 10800.00 8400.57 168.32 63.86 61.00 289.99 1582.13 694.31 887.81 Pass 72312.15 8941.18 10900.00 8474.96 165.17 65.75 60.33 287.95 1512.88 698.94 813.94 Pass 12325.00 8941.06 11000.00 8549.38 161.84 67.72 59.51 285.69 1448.12 703.13 744.99 Pass 12336.96 8941.05 11100.00 8623.58 158.58 69.62 58.39 283.23 1387.65 706.69 680.96 Pass 12350.00 8941.16 11200.00 8694.84 155.03 71.70 57.32 280.68 1329.42 708.89 620.53 Pass 12367.92 8941.41 11300.00 8755.41 149.57 74.45 57.21 278.43 1268.76 706.10 562.67 Pass 12386.78 8941.70 11400.00 8805.47 143.64 77.26 57.52 276.48 1207.83 700.54 507.29 Pass 12407.81 8942.05 11500.00 8851.15 136.82 80.04 58.10 274.53 1151.78 691.39 460.39 Pass 12431.07 8942.47 11600.00 8888.04 129.00 82.89 59.20 272.84 1098.24 678.56 419.69 Pass 12459.46 8943.03 11700.00 8906.15 119.11 86.13 61.75 271.99 1064.82 659.91 404.91 Pass 12489.79 8943.69 11800.00 8923.26 108.20 89.29 64.50 271.10 1069.30 637.85 431.45 Pass 12517.55 8944.35 11900.00 8928.60 97.97 91.91 67.55 270.81 1109.74 615.84 493.89 Pass 12540.94 8944.93 12000.00 8923.04 89.21 93.89 70.61 271.07 1170.21 596.08 574.13 Pass 12559.39 8945.42 12100.00 8926.88 82.27 95.32 72.61 270.85 1245.76 579.97 665.79 Pass 12575.00 8945.84 12200.00 8934.52 76.39 96.32 74.10 270.48 1332.39 565.69 766.70 Pass 12575.00 8945.84 12300.00 8949.42 76.39 96.66 73.51 269.88 1425.81 566.78 859.03 Pass 12587.24 8946.18 12400.00 8958.43 71.82 97.21 74.64 269.54 1522.08 554.75 967.33 Pass 12600.00 8946.55 12500.00 8968.85 67.06 97.85 75.82 269.19 1611.76 542.51 1069.25 Pass 12610.41 8946.85 12600.00 8975.63 63.28 98.55 76.90 269.03 1692.62 533.42 1159.20 Pass 12625.00 8947.29 12700.00 8982.48 57.98 99.16 78.48 268.85 1774.75 519.56 1255.19 Pass 12625.00 8947.29 12800.00 8979.24 57.98 99.70 78.68 269.05 1861.73 521.28 1340.45 Pass 12650.00 8948.05 12900.00 8974.57 49.45 100.09 81.82 269.19 1939.62 497.01 1442.61 Pass 12650.00 8948.05 13000.00 8965.34 49.45 100.78 82.17 269.54 2015.84 499.27 1516.57 Pass 12659.23 8948.34 13014.40 8963.45 46.68 100.68 83.31 269.57 2027.24 490.61 1536.63 Pass Site: PB E Pad Well: E-32 Rule Assigned: Major Risk Wellpath: E-32PB1 V1 Ioter-Site Error: 0.00 ft Refereace Offset Semi-Major Aais Ctr-Ctr NaGo Ailowable MD TVD MD TVD Ret Offset TFO+AZI TF0.HS Casing/H~istance Area Deviation Warniu~ ft ft R ft ft ft deg deg in ft ft ft 12200.00 8945.53 9700.00 7590.99 190.11 46.58 63.06 303.34 2465.54 626.06 1839.48 Pass 12200.00 8945.53 9800.00 7663.56 190.11 47.11 62.33 302.61 2378.60 632.57 1746.02 Pass 12216.38 8945.05 9900.00 7736.43 186.98 49.50 63.40 301.83 2292.75 637.39 1655.36 Pass 12225.00 8944.72 10000.00 7809.70 185.33 51.00 63.50 300.96 2207.86 643.45 1564.41 Pass 12236.29 8944.21 10100.00 7883.28 183.00 52.82 63.82 300.00 2124.20 649.44 1474.76 Pass 12250.00 8943.46 10200.00 7956.86 180.16 54.96 64.34 298.97 2042.11 655.3U 1386.81 Pass 12250.00 8943.46 10300.00 8030.45 180.16 55.57 63.12 297.75 1960.91 664.16 1296.75 Pass 12263.57 8942.73 10400.00 8104.16 177.05 57.59 63.40 296.51 1881.30 668.68 1212.62 Pass 12275.00 8942.21 10500.00 8178.02 174.43 59.38 63.30 295.11 1803.66 674.32 1129.34 Pass 12275.00 8942.21 10600.00 8252.07 174.43 59.98 61.71 293.52 1727.81 684.19 1043.62 Pass 12291.28 8941.64 10700.00 8326.35 170.45 62.31 61.87 291.84 1654.47 687.74 966.73 Pass 12300.00 8941.41 10800.00 8400.57 168.32 63.86 61.00 289.99 1582.13 694.35 887.78 Pass 12312.15 8941.18 10900.00 8474.96 165.17 65.76 60.33 287.95 1512.88 698.97 813.91 Pass 12325.00 8941.06 11000.00 8549.38 161:84 67.73 59.51 285.69 1448.12 703.17 744.96 Pass 12336.96 8941.05 11100.00 8623.58 158.58 69.63 58.39 283.23 1387.65 706.73 680.92 Pass 12350.00 8941.16 11200.00 8694.84 155.03 71.70 57.32 280.68 1329.42 708.93 620.49 Pass 12367.92 8941.41 11300.00 8755.41 149.57 74.45 57.21 278.43 1268.76 706.14 562.62 Pass 12386.78 8941.70 11400.00 8805.47 143.64 77.27 57.52 276.48 1207.83 700.58 507.25 Pass 12407.83 8942.05 11500.00 8850.94 136.81 80.30 58.11 274.54 1151.72 692.17 459.55 Pass 12431.52 8942.48 11600.00 8885.72 128.85 83.55 59.37 272.96 1099.04 680.04 419.00 Pass ~ . ~ bp BP Alaska Anticollision Report ~..r ~s 1NTEQ Gompany; BP Amoco Date: 6/10/2007 Time: 19;14:00 Page: 6 Field: Prudhoe Bay Reference8ite: PB G Pad Co-ordinate(NE) Refereace: WeIL• G-25, True North Reterence WeIL G-25 Vertical (TVD) Refereeces 31 : 25 1 1 h 7/1986 OO:OQ 72.4 Reference Wellpath: Plan 3, G-25B Db: Orade Site: PB E Pad Well: E-32 Rule Assigned: Major Risk Welipath: E-32P61 V1 Inter-Site Error: 0.00 ft Refereece Offset Semi-MajorAais Ctr-Ctr No-Go- AllowaWe NID TVD MD T'VD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Deviatioo V-'arning ft R ft ft ft ft deg deg in ft ft ft 12457.67 8942.99 11700.00 8913.37 119.75 86.90 61.16 271.61 1052.29 664.21 388.08 Pass 12485.86 8943.60 11800.00 8936.07 109.63 90.26 63.36 270.43 1011.55 644.98 366.57 Pass 12516.00 8944.31 11900.00 8953.48 98.54 93.52 66.01 269.46 977.81 622.27 355.54 Pass 12550.00 8945.17 12000.00 8966.64 85.81 96.68 69.32 268.70 950.94 594.15 356.79 Pass 12575.00 8945.84 12089.38 8973.96 76.39 98.98 71.91 268.28 932.85 573.21 359.64 Pass Site: PB G Pad Well: G-05 Rule Assigned: Major Risk Wellpath: G-05 V2 Inter-Site Error: 0.00 ft Retereoce Oftcet Semi-Major Aais Ctr-Ctr No-Go Allowabie MD 1'VD NID 1'VD Ref Oftset TFO+AZI TFO-HS Casin~/H~istaace Area Deviatioa Warning ft ft ft ft ft ft deg deg in ft ft ft 11350.00 8943.73 9400.00 7665.71 94.04 163.30 199.93 43.03 1749.08 536.52 1212.56 Pass 11363.05 8943.44 9500.00 7734.86 98.97 171.73 198.85 43.52 1666.97 571.22 1095.74 Pass 11375.00 8943.20 9600.00 7805.73 103.49 179.71 198.10 44.20 1586.51 606.65 979.86 Pass 11400.00 8942.77 9700.00 7878.39 112.74 192.04 196.02 45.10 1508.52 666.46 842.06 Pass 11412.15 8942.60 9800.00 7953.30 117.12 199.75 195.78 46.32 1432.49 708.23 724.26 Pass 11425.00 8942.45 9900.00 8029.81 121.75 207.54 195.74 47.82 1359.00 754.94 604.05 Pass 11450.00 8942.24 10000.00 8107.06 130.49 218.99 194.57 49.64 1289.71 825.37 464.34 Pass 11466.22 8942.16 10100.00 8185.07 135.96 227.50 194.86 51.87 1226.16 886.24 339.92 Pass 11485.62 8942.12 10200.00 8263.65 142.34 236.69 195.22 54.55 1169.78 956.98 212.80 Pass 11505.45 8942.14 10300.00 8342.59 148.67 245.66 196.05 57.75 1123.601032.92 90.68 Pass 1152525 8942.23 10400.00 8421.87 154.77 254.10 197.40 61.44 1088.361111.03 -22.67 FAIL 11545.24 8942.36 10500.00 8501.95 160.62 262.13 199.01 65.47 1060.621187.05 -126.43 FAIL 11564.88 8942.45 10600.00 8582.42 166.11 269.52 200.94 69.76 1040.451259.73 -219.28 FAIL 11584.05 8942.49 10700.00 8662.89 171.24 276.33 203.12 74.23 1028.801326.69 -297.90 FAIL 11600.00 8942.49 10800.00 8744.20 175.35 282.09 205.83 78.85 1025.391382.24 -356.85 FAIL 11619.51 8942.46 10900.00 8826.82 180.01 287.72 208.20 83.56 1030.351431.45 -401.10 FAIL 11635.61 8942.40 11000.00 8910.56 183.66 292.36 210.96 88.25 1043.751466.07 -422.32 FAIL 11650.00 8942.33 11100.00 8995.53 186.82 296.35 213.85 92.86 1065.111487.94 -422.83 FAIL 11664.55 894222 11200.00 9081.83 189.73 299.34 216.58 97.33 1093.731496.83 -403.10 FAIL 1 T675.00 8942.14 1 i247.12 9122.67 191.81 300.34 217.35 99.36 1109.731499.03 -389.30 FAIL Site: PB G Pad Well: G-25 Rule Assigned: Major Risk Wellpath: G-25 V3 Inter-Site Error: 0.00 ft Reference Oftset Semi-Major Aais Ctr-Gtr No-Go Ailowable MD TVD MD 1'VD Ref Ofiset TFO+AZI TFO-HS Casiag/H~istance Area Deviatioo Warning ft ft ft ft ft ft deg deg in ft ft ft 10289.31 8815.42 10300.00 8838.61 181.42 184.11 352.03 215.52 38.631060.84 -102221 FAIL 10366.34 8862.66 10400.00 8927.67 170.91 175.80 346.7i 209.60 89.46 923.88 -834.42 FA1L 10428.55 8893.46 10500.00 9017.46 159.66 166.52 344.24 205.03 152.35 792.49 -640.14 FAIL 10478.51 8913.09 10600.00 9107.70 150.79 158.45 343.03 202.32 224.21 681.37 -457.16 FAIL Site: PB G Pad Well: G-25 Rule Assigned: Major Risk Wellpath: G-25A V5 Inter-Site Error: 0.00 ft Refereace Offset Semi-Major Axis Ctr-Gtr NaGo AllowAbk MD TVD MD 7'VD Ref Offset TFO+AZI TFQ-HS Casing/fI~istance Area Deviatiou Waraing ft ft ft ft ft ft deg deg in ft ft ft 10297.90 8821.17 10300.00 8820.33 180.34 180.34 222.24 85.74 15.04 985.97 -970.93 FAIL 10376.58 8868.20 10400.00 8870.89 169.07 169.07 229.89 92.41 75.50 910.60 -835.11 FAIL 10408.04 8884.06 10500.00 8902.51 163.38 163.37 235.71 97.16 168.46 854.83 -686.37 FAIL 10374.69 8867.19 10600.00 8911.38 169.42 169.41 239.01 101.60 260.14 820.07 -559.93 FAIL . ~ bp BP Alaska Anticollision Report L~ ~i~r s ~c.~s INTEQ Company: BP Amoco Unte: 6/10@007 Time: 19:14:00 Page: 7 Field: Prudhoe Bay Reference Site: PB G Pad ' Co-ordiuate(NE) ltefereece: Wetl: G-25, True North Reterence We1L• G25 Vertical (1'VD)Beference: ' 31 : 25 1 1/17/1986 00:00 72.4 Reference Weppat6: Plan 3, G-25B Db: Qtade Site: PB G Pad Well: G-25 Rule Assigned: Major Ris k Wellpath: G-25A V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go ` Altowable MD TVD MD TVD Ref Offset TFO+AZI TF0-H5 Casing/fi~istaace Area Deviatioe Waming ft ft ft ft ft ft deg deg in ft ft ft; 10315.03 8832.28 10700.00 8915.48 178.19 178.20 245.87 109.36 324.81 714.79 -389.97 FAIL 10261.74 8796.23 10800.00 8917.84 184.85 184.90 254.10 117.60 376.51 561.13 -184.62 FAIL Site: PB G Pad Wel1: G-25 Rule Assigned: Major Risk Welipath: G-25AP61 V1 Inter-Site Error: 0.00 ft Reference Oftset Semi-Major Axis Ctr-Ctr No-Go Aqowable MD TVD NID TVD Ref Offset TFO+AZI TF0.HS Casiug/H~istance Area Deviation Waroing ft ft ft ft ft ft deg deg in ft ft ft 10297.90 8821.17 10300.00 8820.33 180.34 180.34 222.24 85.74 15.04 985.97 -970.93 FAIL 10376.73 8868.28 70400.00 8870.72 169.05 169.04 229.68 92.19 75.43 912.47 -837.04 FAIL 10418.11 8888.77 10500.00 8913.20 161.55 161.54 238.50 99.62 164.43 828.74 -664.31 FAIL 10407.48 8883.80 10600.00 8942.55 163.48 163.47 243.39 104.85 260.84 777.34 -516.50 FAIL 10357.84 8857.93 10700.00 8964.65 172.42 172.44 249.33 112.53 337.10 688.07 -350.97 FAIL 10301.94 8823.83 10800.00 8970.24 179.83 179.87 256.86 120.35 383.76 542.06 -158.30 FAIL 10255.75 8791.91 10900.00 8975.36 185.60 185.67 265.82 129.31 420.78 362.40 58.38 Pass 11146.96 8751.46 11000.00 8981.06 25.49 201.71 269.71 145.65 481.57 693.63 -212.07 FAIL Site: PB G Pad Well: G-25 Rule Assigned: Major Risk Welipath: G-25AP62 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD NID TVD Ref Offset TFO+AZI TFO-HS Casing/FI9)istance Area Deviation Warning ft ft ft R ft ft deg deg in ft ft ft 10297.90 8821.17 10300.00 8820.33 180.34 180.34 222.24 85.74 15.04 985.97 -970.93 FAIL 10376.73 8868.28 10400.00 8870.72 169.05 169.04 229.68 92.19 75.43 912.47 -837.04 FAIL 10418.11 8888.77 10500.00 8913.20 161.55 161.54 238.50 99.62 164.43 828.74 -664.31 FAIL 10407.48 8883.80 10600.00 8942.55 163.48 163.47 243.39 104.85 260.84 777.34 -516.50 FAIL 10365.17 8862.02 10700.00 8972.82 171.11 171.12 250.02 112.95 340.53 681.89 -341.36 FAIL 10315.11 8832.33 10800.00 8991.36 178.17 178.19 257.97 121.46 394.24 533.73 -139.48 FAIL 10269.61 8801.82 10900.00 8997.90 183.88 183.93 267.25 130.74 423.79 349.26 74.53 Pass 10231.07 8773.66 11000.00 9003.24 186.68 186.76 275.06 137.31 473.13 215.02 258.11 Pass ~ ~ ~ a ~ ^ ` ~ ~ ~ ~ _ w ~ w m a w ~, w ~ ;;i s ~ ~, ~ ~aa w W ~ W w _ g ' ~ _ 8 "' a ~ ~ a o w ~y - °o ~ m '~ ~ . g g m., - ~°o m w a-~ m a ~ ~~~ Wm N ~ ~ ~ J m ~ _ ` m w w U m . - m a ~ ~. j ,. ~ i ~t~ ..~ ~ o n 8 ~ ~w . `~ !~t~f~~l~'. W I ~~~~~f~~~ ~~ I ti m g ~, ~ ~ r ~ ~ a N . ~ W N ~~ ~~~ 1.~.. , m m a g w a ~ ~_~"~ ~ 8 _ a ~ ~ A¢ s S a w^m/F ~ °m °o S °o °a N ~~. C i I. ~, Q n4 ~'~~A~ . u~ A ~w a ~-.. U 3 y a ~ m ~ m , N ~ ~ g 8 m W w a~ 3 N N N A W P1 ~ $ $ $ o ~ N W m W U E H ~ m ~ w V Q ' E W ' $ ~ m I ' ~ . ,,'l~ff~-: U ' ~~.I?1I ~ Q~3 q O ~ ~? .^ $G ` ~ . r I ~ $ . I"1 W m _m_ T . W . rJ g a ~ ° m ~ ro w , ~ ° ~ ~ ___ --- w , ~ N ~u m - ---'_`~~ + m w ~ n 8 C w a ~ N ~ _~ -- ~ r~r -~ ~~ ~ : ~~~ ~ Q~ ~ ~ ~' ~ a c°v ~ in $ W ~ ~ ~ ~ g p ~ ~ m w ~ ' ~ ~ ~ ^ N ~I ~ ~ L ~ W $ ~ ~ ~ W ~j ~ N m O ~ W O ~ ~ _ ~ o`~ , ~ m ,~' .~ ~ ~ ~ ~ g.. ~ m ~~ ,.+il i a N II ~ ~ ;: s s ~ .. , N ,~ 8 Q ~ $ { ; ~ / .. . . .. ~. .. ..~ ...~:~. t C i ~ .~... : .. ~ -::s 1 . ... ...- .~iai S ~ ~ M ' : : i ~ ~ / ~ ~ N ;~ '. 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W ~. ~ ~~ ~ 7$ 9 :Ai47A7A3° ~ ~ ~ ~ g^ ~ ~~$ ~ ~i~: tld i!:!d ~ ~ m N ~ ~ ~~~~~~"~R~~~~~~ m ° c~ $ ~ ~ ~ $ ~ $ ~ °s °s ~ ~ ~ ~e ~ _.~........--- [~iMOOZI l+)~w+owl-lyinos' . , , ~ ~ are L ~ ~ I..L bag BAG Dowell ot bag Blind/Shears TOTs pipes 2" combi ram/slips ~ ~ Mud Cross I I Mud Cross fiaW ~~ass ~S 2 3/8" ram TOTs iddle of pipe/slips 2~~ combi ram/slips Swab Valve Flow Tee EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 ~ ~ Alaska Department of Natural Resources Land Administration System Page 1 of 2 . . ~~h ~, d ~~ ~_~~ l~~~s', F~~~rder`s Se~rch State Cabins ~1~~~ ~~~u 5 _....._....._ //„i,,. /F,;. \ \ ........a.v . . .... ~.... . ,. ... ~ File Type AD~ File Number: 28304 ~ Printable C..a. se File_Summa.ry See Township, Range, Section and Acreage? \;~~~~ ~~ :~ c Yes ~~ No ~t1t~ Q~ ~c~5~! ~t,1~1t1t~i°'j~' Last updated on 06/20I2007. http://www.dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=028304... 6/20/2007 ~ s ss-si~ z52 165 Sondra D. Stewman BP Expioration AK INC. PO Box 196612 MB 7-5 Anchorage, AK 99519-6612 PAY TO THE ~~~ ~ ~~l' ~ ORDER OF =------ _ , ~yy."~'i= DATE ~ ~ ~ ~ ~ , $ ~ ~lrl [~ ('7 ~OLLARS First Nationat Bank AiasKa An~~~ `-' _ ~ ~~~ ME ~: L 25 200060~:99 L46 2 2? L564~~' 0 L65 "Mastercard Check" r- ~ . TRAiYS1d~iI~'~'AI. L.~T'TER CI~~CKLIST i~VVELL vAititE _ ~.~`I .,~'7 oT~S',~ P~n# ~o~a~60 ~ Development _ Service Eac lorato _ iYoa-Conventiona[ Wet[ p n'~ Stratigraphic Z'est Circle Appropriate Letter / Paragraphs to be [nctuded ia 'Transmittal Letter i In accordance with 20 AAC 2~.OU~(~, a!1 record;, data and [o~s ! acquired for the pitot hole must be ciearly differentiated in both ; wetl name ( , (~0- PE~ and AP[ c~umber -_) from records, data and logs ~ acquired for we(I The permit is approved subject to futl cocnpliance with 20 AAC + ~ 2~.07~. Apprqvat to pecfoca:te and aroduce / ini,ect is contingent ; i upon issuance of a conservation order approving a spacing ~ ~ exception. assames the ' ± Irability of any protest to the spacing exception that may occur. j ~ lvon-Conventional j Wel1 ~ f A(t dry ditch sample sets subrnitted to tt~~ommission must be in ;~ i no greater ttcan 30' sample intecvals from below~ the permahost o~ : ~ from wbere samples are frst caught and IO' samp[e interv~als ; ~ through tar~et zones. i r j P(ease note the followiag specia! conditio~ oP this i perrttit: ; ~ production or production testing of coa! bed methane is not atlowed ~ ~ for (name of welh unti! after (Cocnoanv Iv'ame} has designec! and ! ~ imptemented a water wet! testing program to provide base[ine data ; on water quality and quantity. Com art 1~lame) must contact the ~ ! Commission to obtain advance approva! of such water we!( testing ! prot~ram. ~ ' C[-~CK ~ ~~r ~ APPLIES Huu-V v5 (OPT[OtVS) MliGTi LATERA ~ ([P fa~t two digits ~ ~Pt rtumber ; between 60-69) L i The permit i~ for a new weilbore segment of existino we[1 ; ~n I Permit Yo. are , AP[ No. ~0- _ ~ _ Production shou(d coatinue to be reported as a funcrion of the ~ ; originaI 4PI nurnber sra,ted above. ~ P20T E{OLE ! i ~ I i ~ I ' ~ ~ SPACING ! EXCEPTION ; DRY DITCH i SA.ti1PLE i ; T'EXT FOR APPROVqL LETTER Rev: ['2~i06 C: ` jodykransmi ttal_checkl i;t Field & Poot PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT G-25B Program DEV Well bore seg ^ PTD#:2070860 Company BP EXPLORATION (ALASKA) INC Initial Classlfype DEV! PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes - 2 Leasenumberappropriaie--- -------------.------------- --- ---.- Yes----- ----------------- 3 Uniqu@wellnameandnumber____________________________ _________ Yes_____ ________ ------- - - - ------ -- - 4 Welllocatedina_definedpool_____________________________ _____._, Yes ____ ________ - 5 Welllocatedproperdistan~efromdrillingunit_boundary_,_.___.______ ___._....Ye~_____ ______________________________________.._________ __.__________.,_ 6 Welllocatedproperdistancefro_motherwelis_________________ ___ _________ Yes_____ _.. 7 Sufficientacreaqe_ayailablein_drillingunit_______________________ _________ Yes_..__ ___________._.______.____,________,_____.__._, - 8 Ifdeviated,is_wellboreplatincluded________..______ ________ _________ Yes_____ _________.______..__ - 9 Operatoronlyaffectedparty-------------_------_---_--- -----_-- Yes.-_- ---------- 10 Ope[atorhas_appr_~priatebondinforce_______________________ ___..__. Yes_____ _.Blanke~Bond#6194193_________________.__________,_ -- - ------ - -- 11 Permikcanbeissuedwithoutconservationorder___..__,.__.__,__ ______ ._ Yes_____ _____________________.___.__________________,__. - Appr Date 12 Permikcanbeissuedwithoutadministrative.approval________________ ______ __Yes_____ ____._._______________. -- -- ACS 6l20l2007 13 Can permit be approved before 15-day wait Yes 14 Welllocakedwithinareaznd_stratzauthorizedbylnjectionOrder#(put10#in_comments)_(For_ NA______ _______________________________.______________________._________..__. 15 Allwells_withinl/4_milearea_ofreyiewid_entified(ForseNicewellonly)____ ______.__ NA______ ________________________________.._______________________________ 16 Pre-produced injector: dur_ation_of pre-production I_ess than 3 months_ (For se[vice well only) __ NA_ _____ _.._ - - 17 _N_onconyen,gasconformstoAS31.05,030Q.1..A),(~.2.A-D)_____________ ____..__ NA._____ _________________ _________ Engineering 18 Conducto[string_provided__________________ ____________ _________N_A______ __Con_ductorsetinG-25,1_86-162._____________,___.____.___._ 19 Surfacecasing_prQtectsalLknownUSDWs___,___.___.________ _________ NA,___._ __Allaquifers~xemple~AE01,.._,___________________.__.____________.__ 20 CMT_voladequatetocirculate_onconductor&surf,csg_______________ _________ NA____._ __SurfacecasingsetinG-25.__,___.________..___ 21 CM7_vol adegua#e_tg tie-in long string to su_rf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ . Production_ casin set in,G-25, liner set in G25A, 201-065. _ g - - 22 CMT_willcover_allknown_productivehorizons_____________________ _________ Yes_____ _. - - 23 CasingdesignsadepuateforC,_T,B&.permafrost________ ________ _______, Yes__.__ ____________.,__.....__________ - 24 Adequate tankage_or Ceserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig is equipped with steel_pits. No r_eserve_pit_planned. All waste lo approved disposal welis._ _ _ _ _ _ _ _ _ _ _ 25 If a_re-drill, has,a 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ 307-205._ _ _ _ _ _ _ _ _ _ _ _ _ _ - 26 _A_dequate wellbore separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ ProximitX analysis perf_o[med, Nearest segment is abandoned portion_ of G-25A and paths diverge, _ _ _ _ _ _ _ _ _ 27 If_diverterrequired,doesitmeetregu_lations____ __________________ _________NA_ BOPstack_willalready_b_e.inplace,____________________________.___.____________ Appr Date 28 Drilling fluid.prpgram schematic_& ec~uip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Maximum expected formalion ~re&su[e 7,0_EMW._ Planned MW 8,6_ppg._ _ _ _ _ _ _ _ _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ TEM 6/27l2007 29 BOPEs,_dotheymeekregulation---.---------- ---------- --- ---- Yes----- -------------------- ----------------.---------------------- -- - ~~h.1~ ' IV ~ 30 _B_OPE_press rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . , - _ _ MASP ~alculated_at 2340psi, 3500.psi. BOP test_planned. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ 31 Choke_manifoldcomplieswlAPl_RP-53(May84)____________________ ________ Yes_____ ________________________________.________._________ 32 Workwilloccurwithoutoperationshutdown_______________________ ____ ___Yes_____ .____.._______________ ___ - 33 Is presence of H2S gas prQbable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ H2S has been reported atG pad, Rig i~ equipped with sen~ors and alarms. _ _ . _ . _ . . _ _ _ _ _ 34 Mechanical_condition of wells within AOR verified (Fo(seCUice well onlX) _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ . _ _ - - Geology 35 Permitcanbeissuedw/ohydrogensulfidemeasu[es_______ _________ ________ No_____ ._____,___________.____..___ 36 Data_presentedon_potentialoverpressurezones___________________ ________ NA______ ______,___.________,__________ Appr Date 37 Seismicanaly&i&ofshallo~rgas_zones_________ ________________ ________NA_..._ ____,._.__________ ACS 6120/2007 38 Seabed condition survey_(if off-sh_o[e) _ . _ _ _ NA_ . _ _ . . _ - 39 Contact namelphone forweekly_progress re~o[ts [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Garre_t $#audinqe[- 564-4242 _ _ , _ _ _ _ _ _ _ _ _ _ Geologic Engineering P I~~ Commissioner: Date: Date Commissioner: mis 'oner Date Vw~~~~ ~ ~ ~ Well Histo.ry File APPENDIX Information of detailed nature that is not C~ pahicula~iy germane to the Well PeRnitting Process but is part of the history file. To improve the readability of the We~l History file and to sim.pfify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organiz.e this category of information. ! ~ **** REEL HEADER **** MWD 08/01/11 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/07/29 1491558 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las --Version Information VERS. 1.20: WRAP. NO: ~Well Informa tion Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10220.0000: STOP.FT 11549.0000: STEP.FT 0.5000: Ni7LL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. G-25BPB1 Prudhoe Bay Unit 70 deg 19' 19.434"N 148 deg 43' 0.699"W 2617'FNL, 1973' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 29-Ju1-07 API . API NiTMBER: 500292165272 -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 , TOWN.N T11N . R71NG . R 13 E . PDAT. MSL . EPD .F 0 . LMF . RKB . FAPD.F 72.4 . DMF . RF . EKB .F 0 . EDF .F 72.4 . EGL .F 0 . CASE.F N/A . OS1 . DIRECTIONAL . -Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~ I~'~- -t~5 <O ~ c5 ~5 ~~~ ! ~ (1) All depths are Measured Depths (I~ID)unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (SSTVD) are SubSea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer pownhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra 51im Resistivity Sub. (7) Data presented here is final and has not been depth adjusted to PDCL (Primary Depth Control Log). The INTEQ MWD Gamma Ray is the PDC for this wellbore. (8) The sidetrack was drilled from G-25 through a milled window in 3.5" casing. Top of window 10220 ft.NID (8692.83 ft.SSTVD) Bottom of window 10225 ft.I~ID (8696.71 ft.SSTVD) (9) Tied to G-25 at 9752.0 ft.NID (8289.0 ft.SSTVD) (10) The interval from 11517 to 11549 ft.NID (8854.84 to 8851.84 ft.SSTVD) was not logged due to sensor bit offset at TD. (11) The wellbore G-25B was kicked off this wellbore G-25BPB1 at 10257 f t . I~m (8720.65 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 68 records... 14 bytes 132 bytes *** INFORMI~TION TABLE: CONS MNEM VALU WDFN G-25BPB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN G-25BPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDCL ~ ~ The INTEQ MWD Gamma Ray is the PDC for this wellbore. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame 5ize is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 6 8 1 OHI~I 4 4 4 RAS MWD 6 8 1 OF~II~I 4 4 5 RPD MWD 68 1 OHNIM 4 4 6 RPS MWD 68 1 OHI~I 4 4 24 Total Data Records: 74 Tape File Start Depth = 10220.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 87 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 • 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN G-25BPB1.xtf LCC 150 CN BP Exploration (Alaska) WN G-25BPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ----------------- CNAM ODEP GRAX - GRAX ------------ GRAX ----------------- 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification B1ock Sub-type is: FRAIKE SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code 5amples Units 1 GRAX MWD 68 1 AAPI 2 ROPS N1WD 68 1 F/HR 3 RACL MWD 6 8 1 OHI~II"I 4 RACH MWD 68 1 OHI~IM 5 RPCL MWD 68 1 OHNII~4 6 RPCH MWD 68 1 OHNINI 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 ~ Total Data Records: 148 ~ Tape File Start Depth = 10220.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 161 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/07/29 1491558 01 **** REEL TRAILER **** MWD 08/01/11 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ ~ ~ Tape Subfile 1 is type: LIS ~ Tape Subfile 2 is type: LIS DEPTH GR ROP RPD RPS 10220.0000 19.9000 O.OOOC 0.7260 2.5850 10220.5000 19.7000 0.500C 0.2050 7.9390 10300.0000 21.7000 46.200C 25.9060 28.0000 10400.0000 23.7000 62.200C 37.7690 45.3830 10500.0000 28.4000 76.9000 30.6270 38.6090 10600.0000 54.1000 21.8000 29.8790 53.6630 10700.0000 55.2000 1560.0000 27.9960 32.7860 10800.0000 97.8000 68.4000 36.3380 44.9020 10900.0000 75.6000 32.4000 16.8990 17.8430 11000.0000 87.4000 58.7000 29.3890 30.3710 11100.0000 96.0000 67.2000 26.3030 34.8790 11200.0000 172.0000 53.4000 25.1410 30.3710 11300.0000 91.9000 46.1000 21.2390 28.9130 11400.0000 169.4000 41.2000 10.2720 11.5030 11500.0000 29.4000 86.9000 30.3840 35.5160 11549.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10220.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ~ RAD 2162.8501 2162.8501 16.0410 17.1880 14.2240 11.7670 14.8660 15.4090 12.4780 17.5580 14.1060 15.0930 11.9940 9.7570 14.3650 -999.2500 RAS 6933.3096 6933.3096 21.3300 25.3620 22.3970 16.9900 21.0390 26.8040 15.1060 25.9180 18.2750 17.9250 14.7760 8.3310 23.7360 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RPCL RPCH 10220.0000 19.9000 0.0000 0.7260 2.5850 10220.2500 19.8000 0.2000 71663.2031 3.5610 10300.0000 21.7000 46.2000 25.9060 28.0000 10400.0000 23.7000 62.2000 37.7690 45.3830 10500.0000 28.4000 76.9000 30.6270 38.6090 10600.0000 54.1000 21.8000 29.8790 53.6630 10700.0000 55.2000 1560.0000 27.9960 32.7860 10800.0000 97.8000 68.4000 36.3380 44.9020 10900.0000 75.6000 32.4000 16.8990 17.8430 11000.0000 87.4000 58.7000 29.3890 30.3710 11100.0000 96.0000 67.2000 26.3030 34.8790 11200.0000 172.0000 53.4000 25.1410 30.3710 11300.0000 91.9000 46.1000 21.2390 28.9130 11400.0000 169.4000 41.2000 10.2720 11.5030 11500.0000 29.4000 86.9000 30.3840 35.5160 11549.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10220.000000 Tape File End Depth = 11549.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~ RACL 2162.8501 1622.3010 16.0410 17.1880 14.2240 11.7670 14.8660 15.4090 12.4780 17.5580 14.1060 15.0930 11.9940 9.7570 14.3650 -999.2500 RACH 6933.3096 6933.3096 21.3300 25.3620 22.3970 16.9900 21.0390 26.8040 15.1060 25.9180 18.2750 17.925~ 14.7760 8.3310 23.7360 -999.2500 . ~ Tape Subfile 4 is type: LIS < ~ ~ **** REEL HEADER **** MV~ID O8/01/11 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/08/04 1491558 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las --Version Information VERS. 1.20: WRAP. NO: -Well Informa tion Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10220.0000: STOP.FT 12653.0000: 5TEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. G-25B Prudhoe Bay Unit 70 deg 19' 19.434"N 148 deg 43' 0.699"W 2617'FNL, 1973' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 04-Aug-07 API . API NUMBER: 500292165202 -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 . TOWN.N T11N . RANG. R13E . PDAT. MSL . EPD .F 0 . LMF . RKB . FAPD.F 72.4 . DMF . RF . EKB .F 0 . EDF .F 72.4 . EGL .F 0 . CASE.F N/A . OS1 . DIRECTIONAL . -Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 c'b`'~-O~ # 1S`6~~~ • ~ (1) All depths are Measured Depths (NID)unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) Al1 True Vertical Depths (SSTVD) are SubSea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer pownhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (7) Data presented here is final and has not been depth adjusted to PDCL (Primary Depth Control Log). The INTEQ MWD Gamma Ray is the PDC for this wellbore. (8) The sidetrack was drilled from G-25 through a milled window in 3.5" casing. Top of window 10220 ft.I~ID (8692.83 ft.SSTVD) Bottom of window 10225 ft.I~ID (8696.71 ft.SSTVD) (9) Tied to G-25BPB1 at 10240.76 ft.NID (8706.7 ft.SSTVD) (10) This wellbore G-25B was kicked off the wellbore G-25BPB1 at 10257 ft.NID (8720.65 ft.5STVD) (11) The interval from 12623 to 12653 ft.I~ID (8906.72 to 8906.71 ft.SSTVD) was not logged due to sensor bit offset at TD. MNEMONICS: GRAX -> Gamma Ray MWU-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 68 records... 14 bytes 132 bytes *** INFORMATION TABLE: CON5 MNEM VALU ------------------------------------ WDFN G-25B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN G-25B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDCL ~ • The INTEQ MWD Gamma Ray is the PDC for this wellbore. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RP5 RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR N1WD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 6 8 1 OHNIIK 4 4 4 RAS MWD 6 8 1 OHI"tNI 4 4 5 RPD MWD 68 1 OHIKM 4 4 6 RPS MWD 68 1 O~ 4 4 24 Total Data Records: 136 Tape File Start Depth - 10220.000000 Tape File End Depth = 12653.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape 5ubfile: 2 149 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 . • 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN G-25B.xtf LCC 150 CN BP Exploration (Alaska) WN G-25B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT -- CNAM ODEP GRAX ---------------- GRAX ----------- GRAX ------------------ 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX N1WD 68 1 AAPI 2 ROPS MWD 68 1 F/HR 3 RACL MWD 68 1 OHI~IM 4 RACH MWD 68 1 OHMI~4 5 RPCL MWD 68 1 OHNBK 6 RPCH MWD 68 1 OHI~IIK 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 271 r~ u Tape File Start Depth = 10220.000000 Tape File End Depth = 12653.000000 Tape File Level 5pacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 284 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/08/04 1491558 01 **** REEL TRAILER **** MWD 08/01/11 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ • ~ Tape Subfile 1 is type: LI5 ~ ~ Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10220.0000 19.9000 0.0000 2162.8501 6933.3096 0.7260 2.5850 10220.5000 19.7000 0.5000 2162.8501 6933.3096 0.2050 7.9390 10300.0000 20.4000 61.9000 16.0850 19.7910 23.0560 24.7610 10400.0000 28.5000 95.2000 16.4470 19.2810 25.5360 26.7820 10500.0000 180.3000 17.8000 12.3790 10.7020 12.4200 11.9380 10600.0000 22.1000 88.9000 23.0210 38.1660 56.2990 60.7320 10700.0000 37.3000 127.6000 21.5230 37.2830 58.2360 64.4150 10800.0000 70.7000 159.5000 23.0020 33.0250 43.2930 42.0200 10900.0000 57.9000 78.0000 21.8080 28.6070 39.0930 39.3210 11000.0000 41.4000 159.2000 21.6170 28.0070 43.2930 45.1200 11100.0000 79.2000 82.8000 23.4370 30.4300 46.3410 50.3440 11200.0000 50.0000 109.4000 21.8760 30.5460 44.2690 48.1410 11300.0000 55.6000 156.5000 21.0200 26.6440 38.1620 39.9570 11400.0000 180.1000 19.2000 23.2310 17.9530 15.0320 11.6920 11500.0000 55.5000 84.7000 21.5260 24.3080 27.1880 25.5870 11600.0000 54.3000 196.9000 19.8760 26.4510 44.2890 51.5420 11700.0000 36.3000 179.5000 16.7340 16.8960 24.0570 25.5870 11800.0000 83.7000 101.9000 14.0330 11.3550 13.9320 14.0790 11900.0000 111.8000 385.2000 13.6530 13.1690 16.2860 16.8040 12000.0000 111.3000 60.1000 -999.2500 -999.2500 -999.2500 -999.2500 12100.0000 83.7000 44.9000 -999.2500 -999.2500 . -999.2500 -999.2500 12200.0000 121.9000 84.1000 -999.2500 -999.2500 12300.0000 69.3000 60.3000 -999.2500 -999.2500 12400.0000 51.4000 57.0000 -999.2500 -999.2500 12500.0000 81.0000 77.0000 -999.2500 -999.2500 12600.0000 43.9000 105.9000 -999.2500 -999.2500 12653.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10220.000000 Tape File End Depth = 12653.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 i ~ Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 10220.0000 19.9000 0.0000 2162.8501 6933.3096 0.7260 2.5850 10220.2500 19.8000 0.2000 1622.3010 6933.3096 71663.2031 3.5610 10300.0000 20.4000 61.9000 16.0850 19.7910 23.0560 24.7610 10400.0000 28.5000 95.2000 16.4470 19.2810 25.5360 26.7820 10500.0000 180.3000 17.8000 12.3790 10.7020 12.4200 11.9380 10600.0000 22.1000 88.9000 23.0210 38.1660 56.2990 60.7320 10700.0000 37.3000 127.6000 21.5230 37.2830 58.2360 64.4150 10800.0000 70.7000 159.50~0 23.0020 33.0250 43.2930 42.0200 10900.0000 57.9000 78.0000 21.8080 28.6070 39.0930 39.3210 11000.0000 41.4000 159.2000 21.6170 28.0070 43.2930 45.1200 11100.0000 79.2000 82.8000 23.4370 30.4300 46.3410 50.3440 11200.0000 50.0000 109.4000 21.8760 30.5460 44.2690 48.1410 11300.0000 55.6000 156.5000 21.0200 26.6440 38.1620 39.9570 11400.0000 180.1000 19.2000 23.2310 17.9530 15.0320 11.6920 11500.0000 55.5000 84.7000 21.5260 24.3080 27.1880 25.5870 11600.0000 54.3000 196.9000 19.8760 26.4510 44.2890 51.5420 11700.0000 36.3000 179.5000 16.7340 16.8960 24.0570 25.5870 11800.0000 83.7000 101.9000 14.0330 11.3550 13.9320 14.0790 11900.0000 111.8000 385.2000 13.6530 13.1690 16.2860 16.8040 12000.0000 111.3000 60.1000 -999.2500 -999.2500 -999.2500 -999.2500 12100.0000 83.7000 44.9000 -999.2500 -999.2500 • -999.2500 -999.2500 12200.0000 121.9000 84.1000 -999.2500 -999.2500 12300.0000 69.3000 60.3000 -999.2500 -999.2500 12400.0000 51.4000 57.0000 -999.2500 -999.2500 12500.0000 81.0000 77.0000 -999.2500 -999.2500 12600.0000 43.9000 105.9000 -999.2500 -999.2500 12653.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10220.000000 Tape File End Depth = 12653.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~ ~ Tape Subfile 4 is type: LIS
