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206-146
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 25, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-09 PRUDHOE BAY UNIT WGI-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/25/2022 WGI-09 50-029-23327-00-00 206-146-0 G SPT 7936 2061460 1984 3480 3485 3487 3486 7 14 14 14 4YRTST P Austin McLeod 9/16/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT WGI-09 Inspection Date: Tubing OA Packer Depth 29 2508 2477 2454IA 3487 13 45 Min 2441 60 Min Rel Insp Num: Insp Num:mitSAM220917193547 BBL Pumped:2.7 BBL Returned:2.7 Tuesday, October 25, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.10.25 15:48:30 -08'00' Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-146 6.50-029-23327-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8891 8890 8581 8251 7943 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" X 34" 34 - 114 34 - 114 2280 770 Surface 4605 13-3/8" 33 - 4638 33 - 4518 5020 2260 Intermediate 8350 9-5/8" 31 - 8381 31 - 8072 6870 4760 Production Perforation Depth: Measured depth: 8492 - 8888 feet True vertical depth:8183 - 8579 feet Tubing (size, grade, measured and true vertical depth)7" 26# x 7-5/8" 29.7# L-80 29 - 8297 29 - 7988 8251 7943Packers and SSSV (type, measured and true vertical depth) 7" Baker S-3 Packer Liner 600 7" 8290 7981 - 8581 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 351121000 0226511 219 233995 0 3483 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork david.bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8582 Sundry Number or N/A if C.O. Exempt: 321-269 7" Camco DB-6 Injection Valve 2215 2214 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water Wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028302 PBU WGI-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:13 pm, Jun 14, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.14 11:47:36 -08'00' Bo York RBDMS HEW 6/14/2021DSR-6/14/21 SFD 6/18/2021MGR26JUL2021 ACTIVITYDATE SUMMARY 6/5/2021 T/I/O = 2733/188/22. Temp - 102*. Conduct TBG water wash. Pumped 10 bbls 60/40 for for Spear into TBG. Pumped 50 bbls 120* Diesel into TBG followed with 385 bbls Water w/ F-103. Allowed TBG to soak for 2 hours. Pumped 455 bbls Water w/ F-103 for flush. Pumped 15 bbls 60/40 for FP. Pad Operator notified upon departure. SSV/MV (open), SV/WV (closed), IA/OA (OTG). FWHP's = -15/91/-6 Daily Report of Well Operations PBU WGI-09 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:206-146 6.API Number:50-029-23327-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028302 Property Designation (Lease Number):10. 8. PBU WGI-09 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 Water Wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8891 Effective Depth MD: 11. 6/3/21 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: David.Bjork@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: 7" Camco DB-6 Injection Valve Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8582 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8251 , 7943 2215 , 2214 Date: Liner 600 7"8290 - 8890 7981 - 8581 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 33 - 4638 33 - 4518 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 114 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3 Packer 8492 - 8888 8183 - 8579 7" 26# x 7-5/8" 29.7# Production 8890 8581 none none 34 - 114 770 13-3/8" 9-5/8" Contact Phone:(907) 564-4672 Date: 6/1/2021 4760 80 228020" X 34" Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4605 5020 Intermediate 8350 31 - 8381 31 - 8072 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 3481 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. L-80 29 - 8297 By Samantha Carlisle at 3:47 pm, Jun 01, 2021 321-269 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.01 15:10:26 -08'00' Stan Golis (880) DSR-6/2/21DLB06/01/2021 X MGR02JUN21 10-404 dts 6/3/2021 JLC 6/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.03 11:44:12 -08'00' RBDMS HEW 6/4/2021 Well Work Prognosis Well Name:WGI-09 API Number:50-029-23327-00 Current Status:Gas Injector Leg: Estimated Start Date:June 3rd, 2021 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:2061460 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer:Ryan Thompson Office: 907-564-5280 Cell: 907-301-1240 Gas Injection Rate: ~235,000 Mscf/Day Injection Pressure: 3,481 psi Reservoir Pressure (Estimate): 3200 psi Program Objective(s): WGI-09 is a gas cap injection well that has demonstrated a decrease in injectivity. It has lost 40MMSCF injectivity since the last water wash in 2020. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-146 6.50-029-23327-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8891 8890 8581 8251 None None 7943 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" X 34" 34 - 114 34 - 114 2280 770 Surface 4605 13-3/8" 33 - 4638 33 - 4518 5020 2260 Intermediate 8350 9-5/8" 31 - 8381 31 - 8072 6870 4760 Production Perforation Depth: Measured depth: 8492 - 8888 feet True vertical depth:8183 - 8579 feet Tubing (size, grade, measured and true vertical depth)7" 26# x 7-5/8" 29.7# L-80 29 - 8297 29 - 7988 8251 7943Packers and SSSV (type, measured and true vertical depth) 7" Baker S-3 Packer Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3503100 250,122 150 241,777 3495 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: David Bjork david.bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ 5 SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8582 Sundry Number or N/A if C.O. Exempt: 320-221 7" Camco DB-6 Injection Valve 2215 2214 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Water wash Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028302 PBU WGI-09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:19 am, Aug 10, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.08 10:44:36 -08'00' Bo York DSR-8/10/2020MGR10AUG2020 RBDMS HEW 8/10/2020 SFD 8/10/2020 ACTIVITYDATE SUMMARY 7/17/2020 T/I/O= 2710/90/10 LRS Unit 76- Tubing Wash/Pickle Down TBG: 5 bbls 50/50 50 bbls 120* diesel 347 bbls 130* FW w/ .02% F-103 Surfactant 2 hr soak 233 bbls 130* FW w/ .02% F-103 Surfactant 2 bbls 50/50 DSO notified to POI. SV WV= closed. SSV MV IA OA= open. Final Whp's=Vac/62/1 Daily Report of Well Operations PBU WGI-09 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:206-146 6.API Number:50-029-23327-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028302 Property Designation (Lease Number):10. 8. PBU WGI-09 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 Water Wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8891 Effective Depth MD: L-80 11. 7/13/2020 Commission Representative: 15. Suspended Contact Name: Brown, Don L. Contact Email: browd2@BP.com Authorized Name: Brown, Don L. Authorized Title:Petroleum Engineer 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:Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8582 Plugs (MD):Junk (MD): 5Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 825 / 794 2215 / 2214 Date: Liner 600 7" 82 - 88 79 - 8587240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 3 - 4633 - 451 14. Estimated Date for Commencing Operations: BOP Sketch 3 - 11 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3 Packer CDPFR'%,QMHFWLRQ9DOYH 8492 - 8888 8183 - 8579 7" 26# x 7-5/8" 29.7#2 - 829 Production 889 Effective Depth TVD: 858None None 3 - 11 13-3/8" 9-5/8" Contact Phone:+1 9075644675 Date: 4760 80 20"[Conductor 2260 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4605020 Intermediate 8350 31 - 83831 - 807 Address:P.O. Box 196612 Anchorage, AK 99519-6612 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 3:02 pm, May 29, 2020 320-221 Brown, Don L.Brown, Don L. 2020.05.29 12:25:51 -08'00' X MGR29MAY20 DSR-5/29/2020DLB 05/29/2020 10-404Yes quired? C 6/10/2020 dts 6/9/2020 JLC 6/10/2020 RBDMS HEW 6/12/2020 10-403 Sundry Application for Well PBU WGI-09 PTD #206-146 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Expected Start Date: July 13, 2020 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 250564 Mscf/Day Injection Pressure: 3551 psi Reservoir Pressure (Estimate): 3400 psi Program Objective(s): WGI-09 is a gas injection well with decreased injectivity over the past 5 years. The well has been subject to successful water washes in the past (Nov 2014 and Aug 2017) and are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to subject the well to another tubing water wash to once more increase injectivity and perform general maintenance on Gas Injection Wells. Proposed Program: Pump Diesel followed by Fresh Water and Surfactant as per attached pumping template. 10-403 Sundry Application for Well PBU WGI-09 PTD #206-146 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Pump Schedule: 10-403 Sundry Application for Well PBU WGI-09 PTD #206-146 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Wellbore Schematic: STATE OF ALASKA RECEIVED LASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATI S NOVC 7 1. Operations Performed NO 6 201/ 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 ApprAcOr eCQ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-146 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-23327-00-00 7. Property Designation(Lease Number): ADL 028302 8. Well Name and Number PBU WGI-09 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 8891 feet Plugs measured None feet true vertical 8582 feet Junk measured None feet Effective Depth: measured 8891 feet Packer measured 8250 feet true vertical 8582 feet Packer true vertical 7941 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33-113 33-113 Surface 4604 13-3/8" 32-4635 32-4516 5020 2260 Intermediate 8350 9-5/8" 31-8380 31-8071 6870 4760 Production Liner 600 7" 8289-8889 7979-8580 7240 5410 Perforation Depth: Measured depth: 8492-8888 feet feet True vertical depth: 8183-8579 feet feet Tubing(size,grade,measured and true vertical depth) 7"26#x 7-5/8"29.7#L-80 28-8295 28-7986 Packers and SSSV(type,measured and 7"Baker S-3 Packer 8250 7941 true vertical depth) CA.DB LOCK W/A-1 INJ VALVE 2215 2214 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8492'-8888' (� Treatment descriptions including volumes used and final pressure: SCANNED f •c 1 9 2017 10 Bbls Methanol,140 Bbls Diesel/Xylene,583 Bbls Fresh Water/0.02%F-103 Surfactant z 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 231.983 3496 0 Subsequent to operation: 246,129 3496 0 14.Attachments:(required per 20 AAc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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: 317-314 Authorized Name: Stone,Christopher Contact Name: Stone,Chnstopher Authorized Title: DS &18 PE 0/1/40,.. Contact Email: Christopher.Stonenbp.com Authorized Signature: �1' i v --- Date: Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 V Xl 177-1-- /7 /7/i R�—.--.^ -� w Submit Original Only .r1(;/ //7 5.s e- I rd _ Luji • 040 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 October 26, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for WGI-09 PTD #206-146 Water Wash. 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 • Daily Report of Well Operations WGI-09 ACTIVITYDATE SUMMARY T/I/O = 3580/180/40. Temp = 148°. Install N2 caps on IA/OA. On GI. IA& OA FL @ surface. Used 2 bottle of N2 to pressure up IA/OA to 400/100 psi. Monitored for 30 mins, IA FL @ 90'. OA FL near surface. Hung tags. Final WHPs = 3580/390/100. 8/8/2017 SV= C. WV, SSV, MV= O. IA, OA= OTG. 16:30 T/I/0=2675/250/50 Temp=SI (Tubing Wash) Pumped 10 bbls of 50/50 methanol followed 8/9/2017 by 60 bbls of Diesel/Xylene down the tbg to wash. **WSR continued on 8-10-17** **WSR continued from 8-9-17** Pumped 140 bbls of diesel/xylene (200 bbls total) down the tbg. Flushed w/total of 583 bbls fresh water w/0.02% F-103 surfactant. Capped w/ 10 bbls 8/10/2017 50/50. DSO to POI. FWHP=280-/165/18 SV,WV Closed SSV,MV,IA,OA Open. ***WELL S/I UPON ARRIVAL*** (sssv maint) DRIFTED W/6.05" GAUGE RING TOA-1 @ 2,190' SLM/2,215' MD PULLED 7" CA. DB LOCK W/A-1 INJ VALVE (Serial#BWS-242) FROM 2,215' MD (Flapper broken off) DRIFT &TAG W/3.85" CENT, 3" SAMPLE BAILER TO 8,831' SLM (No sample) SET 7" CA. DB LOCK W/A-1 INJ VALVE (Serial#=BWS-243, Bean=3.50") @ 2,215' MD PERFORMED SUCCESSFUL DRAWDOWN /CLOSURE TEST 10/24/2017 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** Fluids Summary Bbls Type 10 Bbls 50/50 Methanol 140 Bbls Diesel/Xylene 583 Bbls Fresh Water/0.02% F-103 Surfactant TR( 6"CNV WELLHEAD= FAC I-O • MAGND6MPPLLSEEVH3EOIN ACTUATOR= OTIS OKB.BEV 50.59 WELL PICTURES FILE 08/22/14"• BE ELEV= 32.9' KOP= 1950' Max Angle= 23°©6618' Datum ND= 9160' Datum TVD= 8800'SS 7-5/8"TBG,29.7#,L-80 PC VAM TOP, H 2204' 2204' H7-5/8"X 7"XO,D=6276 0.459 bpf,D=6.875" 2215' —7"CAMCO DB-6 NP,ID=6.00" 7"TBG,26#,L-80,TC11,.0383bpf,D=6.276" H 2226' OA MAGE D-SEE VIDEO 08122/14 2226' --I7"X 7-5/8"XO,D=6.276 13-3/8"CSG,68#,L-80,BTC,D=12.415" H 4638• • • r4 3600' --I EST TOP OF CEMENT 11 t A t A • Minimum ID =5.770" @ 8275' t i t 0 7" RN NIPPLE t 7-5/8"TBG,29.7#,L-80 IPC VAM TOP, H 8138' 0.459 bpf,D=6.875' g 8138' —17-5/8"X 7"XO,D=6.250" t 0 • 0 8230' —17"HES"R"NP,D=5.963" • A tol t I VI ►�, • 8251' —9-5/8"X 7"BKR S-3 PKR,D=6.00" ' 9-5/8"CSG,47#,L-80 TCU XO TO L-80 BTC -I 8260' #, 3 E 8275' H7"HES"RN"NP,D=5.770" 3 • t — 8290' —19-518"X 7"C-2 ZXP LTP w/MAC HGR,ID=6.270" 7"TBG,26#,L-80,TC11,.0383 bpf,D=6.276" —{ 8297' t •IM ► 829T —17"MULE SHOE,D=6.276 i i. • • 9-5/8"CSG,47#,L-80 BTC,D=8.681" —I 8381' 7"SOLD LNR,26#,L-80,BTC,.0383 bpf,D=6.276 —I 8492' ,— PSTD —I 8890' I I 7"SLOTTED LNR 26#,L-80,BTC,.0383 bpf,D=6.276 H 8892' A L DATE REV BY COMVE TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/06 N27E ORIGINAL COMPLETION WILL WGI-09 03/04/07 RP/PJC DRLG DRAFT CORRECTIONS P8 Mf Pb:"2061460 02/11/11 MB/JM) AWED SSSV SAFELY NOTE API No: 50-029-23327-00 04/03/11 WK/PJC MIND CORRECTION SEC 11,711N,R14E,5051'FSL,1215'FE_ 08/26/14 LEt7JMD SAFETY NOTE UPDATE(8/22/14) 08/27/14 PJC REFORMATTING BP Exploration(Alaska) •yOF TA • • \���� ks //7 7 ,; THE STATE Alaska Oil and Gas sem of® T sKA Conservation Commission ALA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �_ Main: 907.279.1433 ALAS 11�P Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone DS 2 and 18 PE SCANNEDJUL 2 0201 . BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU WGI-09 Permit to Drill Number: 206-146 Sundry Number: 317-314 Dear Mr. Stone: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0111.— JP° Hollis S. French Chair DATED this I day of July, 2017. RBDMS V JUL 1 3 2017 STATE OF ALASKA OkLASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROV 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate Il • Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Water Wash m • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-146 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0• 6. API Number: 50-029-23327-00-00 • 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? ,."` .. @ .. Will planned perforations require a spacing exception? Yes 0 No 10 PBU WGI-09 EiAID + 9. Property Designation(Lease Number): 10. Field/Pools: J U I 1 0 2017 ADL 0028302 , PRUDHOE BAY,PRUDHOE OIL • Ars 7( +2,'t_) 11. PRESENT WELL CONDITION SUMMARY f"� •� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 8891 • 8582 • 8891 8582 Casing Length Size MD TVD Burst Collapse Structural _ Conductor 80 20"215.5#A-53 33-113 33-113 Surface 4604 13-3/8"68#L-80 32-4635 32-4516 5020 2260 Intermediate 8350 9-5/8"47#L-80 31 -8380 31 -8071 6870 4760 Production Liner 600 7"26#L-80 8289-8889 7979-8580 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8492-8888 8183-8579 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 7"Camco A-1 SSSV 2215, 2213.59 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program m BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ® - Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stone,Christopher be deviated from without prior written approval. Contact Email: Christopher.Stone@bp.com Authorized Name: Stone,Christopher Contact Phone: +1 907 564 5518 Authorized Title: DS 2&18 P Authorized Signature: S/ Date: [[vv���'''���I �_/ ►/ Wi/7'1 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31-7-3l1 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No I Subsequent Form Required: rD-404, APPROVED BYTHE Approved by: OMMISSIONER COMMISSION Date: .i.--111 4c. /" \, V1 IGINAL RBDMS ;`- JUL 1 3 2017 * T -1:t,-ATO.' 12,In Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,f r!ll/7 ;6L 7 /((7 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 tr-'x' JUL 0 2017 RE: BP Exploration (Alaska), Inc. AO ,� n Report of Sundry Approvals (10-403) fi „s . July 7, 2017 To Whom it May Concern: Attached please find the Sundry Application for a Water Wash on Well WGI-09, PTD # 206-146. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR,LHD,EAZ, BPG 10/12/15) General Information Well Name: WGI-09 Well Type: Gas Injection Well API Number: 50-029-23327-00 Well Activity Conventional 4 Classification: Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: Other regulatory AWGRS Job Scope: TUBING WASH/PICKLE None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Well Intervention Engineer: Jamin Laplante Contact numbers: 907-365-9140 907-564-4137 Lead Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Date Created: June 20. 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or I FTP or Injection Oil Rate In) Rate Gas Injection GOR Gas Lift Rate Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (MscflDay) (psi) 6/18/2017 264.240 3.508 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) NA 0 ppm Maximum Deviation(Angle and 23° 6.618' MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 3° 7,754 MD Reservoir pressure(date, 5/19/2015 3.407 psi Minimum ID and Depth 5.770" 8275' psig) Reservoir Temp, F 163° F Shut-in Wellhead Pressure Est. 2525 psi Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 5/20/2015 SBHP Survey Most recent TD tag(date, depth, 5/18/2015 8831'SLM 5.5"LIB.4.50 Cent, 2' 1-7/8"Stem toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, WGI-09 was drilled and completed in 2006 with a 7"injection liner set across all of the Ivishak(all zones are background information, open to injection). In 2011 SL drifted the well and encountered"schmoo"at 8866' MD. A water wash was etc: pumped 11/4/14- 10 bbls Neat McOH. 202 bbls diesel/xylene. 475 bbls KCI/surfactant mix and 105 bbls 1% KCI pumped. Post wash the injectivity of the well increased(-290 MMSCFPD pre wash to 310 MMSCFPD post wash). Currently the well is injecting -290 mmscfpd and appears to have degrading injectivity making it a great candidate for another water wash treatment. The objective of thie fullbore pumping operations is to increase the injectivity of the well by removing deposits from tubing and liner. • • Well Intervention Details Please contact the SOR author if 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total costas soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20% Suspected Well Problem: Reduced injectivity due to depositions. Specific Intervention or Well Objectives: 1 Pump diesel/xylene water wash to restore injectivity by cleaning perfs and tubing. 2 3 Key risks, critical issues: Mitigation plan: 1 High pressure pumping Use pressure cross check checklist Use extreme caution and ensure all personal on 2 Gas Injection Well location are aware of pressure sources and well barriers. Follow well entry gas pad wellwork section 3.8 Hydrostatically the well will be underbalanced during the soak period,expect to see tubing pressure climb 3 Soaking diesel/xylene during pumping process during 4 hour soak as gas comes into well to balance hydrostatically,we will push this back into reservior when we come back on with the pumps Review MSDS pre-job, discuss safety precautions/gear, 4 Working with Xylene how to handle spills, how to handle contact to personal to ensure personal know how to respond Summary Service Line Activity Step# 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Post water wash return well to gas injection service. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • Q, 0000000 ea O I(1 ). N � N- C N tf) d tO U 0 0 0 0 0 0 0 i CDCD m to CO r- CO i-- CO I- C) N V CO CO r ti CO O N N CO LO O Ln N N CO O CO CO N N N ti 1 1 1 1 1 1 1 1 I- 6) N V 00 M N I- N O N M M M O M N N CO N- N N N- C (1) M � O6) ML000lC) EN CM CO CO O N M O M O N N N 0 CO CO N N CO CO • M 4-0 c C 1 1 I 1 1 1 I 1 N 4-0 QC CA coinO c co N M N O N Cr) a, M co co NM ) N N 00 C Q O O OM C) 0 00 CO C) ' Q J J 00 00 J 00 y *k *k --I N. J N. J CO *k 0 *k 0 *k Co CO - N N N N U N , aD O cM t I- I I— I N O i i r.+ d- O 0 r— N 00 8)O 0 LO r- N C 00 CO M - N 6) d CO O N J LU CC I— C 0 Q W (3 W t� plwck ZZZZ Z W W C OO CCl 00 ODI • Z D D D D 0Cl) z _1F— I— I— I • • Packers and SSV's Attachment WGI-09 ADL0028302 SW Name Type MD TVD Depscription WGI-09 SSSV 2215 2213.81 7" Camco A-1 SSSV WGI-09 TBG PACKER 8250.48 7941.28 7" Baker S-3 Packer WGI-09 TBG PACKER 8300.22 7991.02 7" Baker HMC Packer TREE= 6"CIW WELLHEA9= FINE WGI-09 smy NOTES- WELL REQLIRES A SSSV `-`** PRIIIPILE DAMAGE IN DB-6 MPPLE,SEE VIDEO IN 1 ACTUA TOR= OTIS OKB ELEV= 50 59' , WELL PICTURES RLE 08122/14 ' i BF ['LEV= 32.9' KOP= 1950' Mix Angle= 23°©6618 Datum MD= 9160' Datum 1VD= 8800'SS 7-5/8"TBG,29 7#,L-80 PC VAN)TOP, I— 2204' 2204* 1--7-5/8"X 7"X0,ID=6 2761 0.459 bpf,ID=6.875" I 2215' Hr CAMCO D8-6'MP,ID=6.00" I 0 I DA MA GEO SEE VIDEO 08)22/14 7"TBG,26#,L-80,TC11, 0383bpf,ID=6276" —1 2226' 2226' H 7"X 7-5/8"XO,ID=6,276 ri • • I• *4 . 3600' --FEST TOP OF CEMENT II1: 13-3/8"CSG,68#,L-80,BTC ID=12.415" — 4638' V •, • I I • Pig 11• • I“ • • 11,4 I k.4 M Minimum ID =6.770" @ 8276' IM * 1141 7" RN NIPPLE .4, • .444 117i . to I I 7-518"TBG,29.7#,L-80 PC VAM TOP, H 8138' _ • ,. 8138 —17-5/8"X 7"XO,ID=6.250" 0.459 bpf,10=6 875" • • I 4 14. v ti 8230' Hr HES"Tr NP,I)=5.963" 1,4„: • ), I 4 • • I I 4 • I, I:0......1..... 4 P 8251° H9-5/8"X 7"BKR S-3 PKR,ID=6 00" X 9-5/8"CSG,47#,L-80 TCI XO TO L-80 BTC H 8260" 7 oFii,• N t 8275' --17-HES"RN"NP,ID=5.770" 0., • II,1 • 041 II 4 A - 8290' —9-5/8"X 7"(>2 ZXP LW w/14/C HGR ID=6.270" • • r. r TBG,26#,L-80,TC11, 0383 bpf,C)=6.276" — 829T • ,l_ it.,,,.... A 7 8297' 'H 7"MULE SHOE,ID=6.276 1 ot i• I* • 9-5/8"CSG,47#,L-80 BTC,ID=8 681" ----1 8381' 7"SOLID LNR,26#,L-80,BTC, 0383 bpf,III=6 276 — 8402' 1— PTD H 8890. 1 7-SLOTTED LNR,26#,L-80,BTC,.0383 bpf,ID=6 276 --I 8892' 4I -- - DATE REV BY COMMENTS I DATE REV BY COM/ANTS PRUDHOE BAY UNIT 12/08/06 N27E ORIGINAL COMPLETION WELL YVGI-09 03/04/07 RP/PJC DRLG DRAFT CORRECTIONS PERMIT No '1061460 02/11/11 MB/JMD ADDED SSSV SA I-E I Y NOTE 1API Pb 50-029-23327-00 04/03/11 IMQPJC MIN ID CORRECTION I SEC 11,711N,R14E,5051'ESL,1215'FEL 08/26/14 LEC/JMD SAFE!Y NOTE UPDATE(8/22/14) 08/27/14 PJC FEFORMATTNG , , BP Exploration(Alaska) , • • Im~~~ Prc-~~ct W~I~ Hi~tc~ry Fi(~ aV~r° ~~~~ XHVZE This pagE icinr~tifies those items that were not scanned during tt~e initial production scanning phase. They are av~~ilable in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~ ~ Well History File Identifier Organl7/ng (done) ~,.o=aea iuuiumiuuiu ae.~a,~e~.a uiimiiuuiiuu RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ^ Logs of various kinds: NOTES: BY: Maria pate: ~ ^ Other:: /s/ Project Proofing II (II () II I I III I I III BY: Maria Date: ~ ~ /s/ Scanning Preparation U` x 30 = ~ + ~ =TOTAL PAGES `"1` ~ ~ Count does not include cover sh t ) ( BY: i Maria Date: ~ ~,r: ~ ~ /s/ V V L Production Scanning Stage 7 Page Count from Scanned File: L ~ _ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: r ~ ~ ~ ~ /s/ '~~ Stage T If NO in stage 1, page(s) discrepancies were found: YES NO DIG AL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: a~a~.~~~~~ iiuimiiiiumii 10/6/2005 Well History File Cover Page.doc I77; THE STATE vl� ;P C C. C a G) A /v\ ��,� '`t _ 333 Vv'es1 Seventh A venue GOVERNOR SEAN PARN ',LI. Anchorage, Alaska 99501-3572 Main: 907.279.1 433 to, 901.276.%>':/ Javier Farinez 2 2 2.O\1 GPB GDE Lead PE scoop BP Exploration (Alaska), Inc. a ` P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-09 Sundry Number: 314-218 Dear Mr. Farinez: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this Ay of April, 2014. Encl. RECEIVED • V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR O Z014 APPLICATION FOR SUNDRY APPROVALS A rVGO 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash ✓I• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill umber. ,'/ BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 206-146-0 ' A.qk� 3.Address: Stratigraphic ❑ Service E6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23327-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? _ PBU WGI-09 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8891 . 8582 d 8891 8582 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"X 34"215.5#A53 33-113 33-113 Surface 4604 13-3/8"68#L-80 34-4638 34-4518.36 5020 2260 Intermediate 8349 9-5/8"47#L-80 32-8381 32-8071.8 6870 4760 I . Production None None None None None None Liner 600 7"26#L-80 8290-8890 7980.8-8580.8 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8492-8888 8182.8-8578.8 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7"Camco A-1 SSSV 2215,2213.81' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑r BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑, • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑, . WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name J.'ler Fa' ez Title GPB BDE Lead PE Signature Phone 564-5043 Date Lt/L/,� Prepared by Garry Catron 564-4424 ( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number -3\ - 2`S Plug Integrity Q BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMsA MAY 1 0 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 _ 4 64_ APPROVED BY Approved by: gfl i COMMISSIONER THE COMMISSION Date: /a—/ .-1-- -.,)11‹..f.,06,(-1 .-‘ ,r1�S yttoliLf /0 4. (//: Form 10-403 Revised 1 /2012 OR1GiTAL pvdafor'f months from the date of approval. Submit Form and Attachmeci uplicate j��s�j/ ' r -00 co O O O O O!O Co L) 00 O O 00 00 140 00 0 Q J J J J J J N Q 0 0 0 0 0 0 0 co CO '- CO '- CA CA p LO N LO Cn U N 0 0 0 0 0 0 N- vNvrnO) v = CO N O N CO 00 N m CO N- U) � CO CO N- N Cn C6 N '— CO N co O LO m N- O CD O N N O 0 LO CA N 00 N 0 a0 00 N- N N FFFF--Q O ~ M N CO N CO N 0 Q co M C M COM N N (N N EO 000 (0 CO CO f_ co co Oct?) OM NOOM_ N 0 ' COO CO0 OO N 00 N tl rrt • I— M M N M ("INN CO Q CO CO N N U M Q 0 °;) a00 000 Lo J coo J OOO J J coo CU _$ J J N 4t CD *k O) (A *k CO N CO N CO N N N X � � co torr o N L O O '— 00 R O 0 1- - N C4 CO - ' N LO N CO W C rnO - W w oc < 0000 ZZZOccu_ ZWWCCm _ m m F- Z �UZ7fnHHHH V Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top WGI-09 SSSV 2215 '7"Camco A-1 SSSV 2214 WGI-09 PACKER 8251 _7" Baker S-3 Packer 7942 WGI-09 PACKER 8301 7" Baker ZXP Packer 7992 IIS TREE= 6"CIW _ACTUATOR= = FMC WGI-09 SA f NOTES: WELL REQUIRES A SSSV. ' CTUATOR= OTIS KB.ELEV= 50.59' BF.ELEV= 32.9' KOP= 1950' Max Angle= 23 @ 6618' Datum MD= 9160' Datum TVD= 8800'SS 7-5/8"TBG,29.7#,L-80 IPC VAM TOP, — 2204' 0.459 bpf,ID=6.875" 2204' I-17-5/8"X 7"XO,ID=6.276 0 2215' —7"CAMCO DB-6 NIP,ID=6.00" 7"TBG,26#,L-80,TC11,.0383bpf, ID=6.276" — 2226' ' 2226' —1r X 7-5/8"XO,ID=6.276 13-3/8"CSG,68#,L-80, BTC,ID=12.415" 1 4638' 3600' —EST TOP OF CEMENT ►• A Minimum ID = 5.770" @ 8275' ►t 7" RN NIPPLE •01 • • 01 it ri 7-5/8"TBG,29.7#,L-80 IPC VAM TOP, 8138' 0.459 bpf, ID=6.875" 8138' H7-5/8"X 7"XO,ID=6.250" 04 ♦ : ►a t ►� 8230' H 7"HES"R"NIP,ID=5.963" p ♦ ► 8��� ��� 8251' —19-5/8"X 7"BKR S-3 PKR,ID=6.00" 9-5/8"CSG,47#,L-80 TCII XO TO L-80 BTC -1 8260' I„ . ►� ♦ 8275' —17”HES"RN"NIP,ID=5.770" ♦ ► �� • 8290' —9-5/8"X 7"C-2 ZXP LTP w/HMC HGR,ID=6.270" 7"TBG,26#,L-80,TC11, .0383 bpf, ID=6.276" — 8297' • • • 8297' —17"MULE SHOE, ID=6.276 k4 • • 9-5/8"CSG,47#, L-80 BTC, ID=8.681" —1 8381' 7"SOLID LNR,26#,L-80,BTC,.0383 bpf, ID=6.276 H 8492' 1-- I I PBTD H 8890' I I 7"SLOTTED LNR,26#,L-80,BTC, .0383 bpf,ID=6.276 H 8892' I I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/08/06 N27E ORIGINAL COMPLETION WELL: WGI-09 03/04/07 RP/PJC DRLG DRAFT CORRECTIONS PERMIT No:'2061460 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-23327-00 04/03/11 WK/PJC MIN ID CORRECTION SEC 11,T11 N,R14E,5051'FSL, 1215'FEL BP Exploration(Alaska) r / ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3,DBR,LHD,EAZ 01/15/14) General Information Well Name: WGI-09 Well Type: Injector API Number: 500292332700 Well Activity Classification: Conventional 4 — Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, SM: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 N/A N/A 305 MMscfpd N/A N/A N/A 3,500 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 ppm Maximum Deviation(angle and depth) 23° 6,618'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 5.77"©8,275 Reservoir pressure(date,psig) N/A I 3,300 psi Reservoir temperature,F 176°F Shut in wellhead pressure 2,420 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 4/21/2011.Integirty Test Most recent TD tag,(date,depth,toolstring OD) 4/21/2011.TAGGED HARD BOTTOM 0 8,866'MD W/3.85"CENT,S-BLR(Sample of schmoo) Comments,well history, Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used / background information,etc: successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectevity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step # Service Line Activity 1 Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Pert form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 • O FEES 2 2 L(1la Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue - ` L ) Anchorage, Alaska 99501 O� Subject: Corrosion Inhibitor Treatments of WGI W f Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from WGI 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, 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) WGI Date: 09/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date WGI 1790310 500292036900 Sealed conductor NA NA NA NA NA WGI -02 1790430 500292037900 Sealed conductor NA NA NA NA NA WGI-03 1790490 500292038500 Sealed conductor NA NA NA NA NA WGI-04 1790500 500292038600 Sealed conductor NA NA NA NA NA WGI-05 1900250 500292201500 Dust Cover NA NA NA NA NA WGI-06 1900300 500292202100 0.3 NA 0.3 NA 3.4 9/15/2011 WGI-07 1900400 500292203100 0.3 NA 0.3 NA 3.4 9/15/2011 WGI-08 1900490 500292203800 0.3 NA 0.3 NA 3.4 9/15/2011 x ' 1 1 WGI-09 2061460 500292332700 1.3 NA 1.3 NA 10.2 9/15/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 4 11j bl DATE: Thursday, April 07, 2011 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -09 FROM: Jeff Jones PRUDHOE BAY UNIT WGI -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 6 ,-- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI - 09 API Well Number: 50 029 - 23327 -00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110313172638 Permit Number: 206 - 146 - Inspection Date: 3/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -09 - Type Inj. G 1 TVD 7936 I IA 1 80 I 2240 - 2240 2260 2300 -F - 2320 - P.T.D 2061460 ` SPT' Test psi 1984 OA 180 160 ~ 170 170 170 180 Interval 4YRTST P/F F . Tubing 3440 3440 3440 3440 3440 1 3440 Notes: 4 BBLS methanol pumped. One well inspected; no exceptions noted. Due to the IA not being completely fluid packed prior to the test and the temperature differential between the well head and the test fluid, the IA pressure would not stabilize. Test pressures were monitored for an additional 2 hours and the IA pressure failed to stabilize. AdttiNEVAPR 1 3 201) Thursday, April 07, 2011 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 e' DATE: Friday, March 25, 2011 � ;Hi( P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -09 FROM: Jeff Jones PRUDHOE BAY UNIT WGI -09 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry J NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI - 09 / API Well Number: 50- 029 - 23327 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ110313172638 Permit Number: 206 -146 -0 Inspection Date: 3/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -09- Type Inj. G ' TVD 7936 ' IA 80 2240 '1 2240 2260 2300 ' 2320 - P.T.D 2061460 TypeTest 111 Test psi 1984 OA 180 160 170 170 170 180 Interval4YRTST P/F F • Tubing 3440 3440 i 3440 3440 3440 3440 Notes: 4 BBLS methanol pumped. One well inspected; no exceptions noted. Due to the IA not being completely fluid packed prior to the test and the temperature differential between the well head and the test fluid, the IA pressure would not stabilize. MAR e 0 2U Friday, March 25, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 25, 2011 TO: Jim Regg P.I. Supervisor ` \ q 7 / /( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI -09 FROM: Jeff Jones PRUDHOE BAY UNIT WGI -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :Jae-- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT WGI -09 API Well Number: 50- 029 - 23327 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ110313174615 Permit Number: 206 - 146 - Inspection Date: 3/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI -09- Type Inj. G ' TVD 7936 - IA 275 I 2220 -H 2200 2200 - P.T.D[ 2061460 ' TypeTest SPT Test psi 1984 OA 180 200 200 200 Interval 4YRTST P' p _— Tubing 3580 3580 3580 3580 Notes: 2.2 BBLS methanol pumped. 1 well inspected; no exceptions noted. MOLD MAR 2011. Friday, March 25, 2011 Page 1 of 1 • • ~~,~ _~~" ~_ ,a-~" ` ~ Qs ~ ° ' -~a ~ ~ ~ ~ ~ ~ _ pp x ~. f~ ~ ~y, ~t MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~~o~ DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061460 Well Name/No. PRUDHOE BAY UNIT WGI-09 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23327-00-00 MD 8891 TVD 8582 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /PWD, MWD DIR / GR /PWD, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments wog Sonic 5 Col 1 3000 8285 Case 1/22/2007 USIT, CBL, DSLT, GPIT, GR, CCL 3-Dec-2006 ~(~D D r Asc Directional Survey 0 8891 Open 1/28/2007 ~ ~ C Las 15496 Induction/Resistivity 261 8892 Open 10/3/2007 RPM, GR, ROP w/EMF graphics Field Data ', LIS Verification 261 8891 Open 6/19/2008 LIS Veri, RPD, RPX, RPS, RPM, FET, GR, ROP '~ C Lis 16476 Induction/Resistivity 261 8891 Open 6/19/2008 LIS Veri, RPD, RPX, RPS, ~~ C 16959 Induction/Resistivity 0 0 9/30/2008 RPM, FET, GR, ROP PDF, CGM and EMF data for MD and TVD EWR Logs Induction/Resistivity 25 Col 312 8891 Open 9/30/2008 MD ROP, DGR, EWR II Induction/Resistivity 25 Col 261 8531 Open 9/30/2008 TVD DGR, EWR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comme nts ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~1'ffY Analysis ~- Received? Completion Date 12/6/2006 Completion Status 1GINJ Current Status 1GINJ Daily History Received? / Formation Tops Y / N Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/15/2008 Permit to Drill 2061460 Well Name/No. PRUDHOE BAY UNIT WGI-09 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23327-00-00 MD 8891 TVD 8582 Completion Date 12/6/2006 Completion Status 1GINJ Current Status 1GINJ UIC Y Compliance Reviewed By: Date: l~ ~ ~ v WELL LOG TRANSMITTAL To: State of Alaska September 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: WGI-09 AK-MW-4725793 WGI-09: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23327-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23327-00 Digital Log Images: 1 CD Rom 50-029-23327-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: ~~ Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: - _ , BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: WELL L®G TRAI~TSMITTAL To: State of Alaska June 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: WGI-09 AK-MW-4725793 1 LDWG formatted CD rom with verification listing. API#: 50-029-23327-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMTTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: r BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Ij r Signed: ~ /~~~--~~~ ~` ~~ I~C:iAN I CAL INTEGRITY REPORT - ~ ~ - "~ ~r ~` r : ~ C~ OPER ~ FIELD ~~ ~ ~ ~'' ~~'' .G r~.~S~~~. - ~I`1-Q ~ i.~LL NUMBER ~~~ ~.-(V` ``-~ I n ALL DAT ~_ TD : ~~~ ` ?~.. ~~x~ TVD ; =ETD : ~`~`1 I PID ~*ti ~TVD ry ~ 'V %asi^g: ~ ~~r~ Shoe: ~'~_t~ ~~~ TVD; LV: N~ ?~S1 ~ -Tti"'i ~_ae= . '~~~,~~~~ Shoe . ~ '~ ~~~ ?'`~ ; ~CP . ~'5,~~~ ?-~ ~_I';D u b ~ ~ Y : ~~rPS P ac is er ~-i-~ T'JD ; Set a L ~tJ ~-~l~i ole Site ~~~~~~ and ~~' ; serfs `a\'~~~ to ~~~~~°- -.- . ~rC'r'.~?~=C~._'..r ! NTEGR?"fiY - PART #1 rnnuius ?ress Test: _~ ~~3© 15 rain aa~p .:,a min aa0~ Cor~ents . •~-~:r~~"e~.~~v\~> ~c~.~c~ \e; ~~LC.i ~~~. ~~ 1S-UGC c~es~~~ _~ ~ r '_-~* CH?N1Cr..L INTEGRT'?'~ -PART #2 -~.\ ~4, ~~ti\~ ~~~'~ Cement Volumes : A.mt. Liner NDt Csg ~k~ ~\5 ; DV '~ ~ ~ ~ 'l C~,t Jol to cover oers ~ 30 i ~ X'~ 3C~ ~~~s ~.~ v- S~C~ C'r E ~~~~ 5 tE r _ eoretical TOC ~ 307c~Y.5 '`'' ~~ ~Q ~~~ ~ Cement Bond Log (Yes or No)-~~_; In AOGCC File ~~,~~ C5L Evaluation, --one above perfs VSA ~.e:.~s ~,~~~~~~ ~~; = ~ ~~ ~ ~L~~S~C~ kc~~~ C~~L~~L~~ ~C1C C ~-~~ 2c ~ "3 C~ i i Production Log: Type Evaluation - i i - { CON~;LJS?Ot1S : - ~ ar t 31 ,:,'S ~ r , ~~ - `~ • • WGI-09 (206-146) Notes This well is a newly drilled gas injection well at Prudhoe Bay. It was spudded 11/15/2006 and completed about 3 weeks later with 7" slotted liner on 12!6106. In the operations summary entry for November 25 while drilling 12-1/4" hole, it is noted "Connection gas from surface to 6700' was around 60 units, gas increasing, spikes at 6770'-1500 units, 6825' 2000 units, 6885 2000 units. Well static on flow checks and connections. Very little aeration in the mud." The high connection gas remained while drilling the well to i2-1/4" TD at $385' md. 9-5/8" casing was run and cemented without problems. About 20 bbls was lost will Homing the casing. Full returns are noted while cementing and the casing was reciprocated throughout the job. Cement was in place at 0630 November 29. A UIST log was run on December 3. The USIT log was run in two modes due to the lead and tail slurry. The USIT log shows episodic bonding from about 6825' to TD. The poorly bonded intervals exhibit "gas flags" and a rapid transition from well bonded intervals both above and below. Well-bonded intervals exist from 8280' (pickup) - 8080', 7920' - 7710', 7300' - 7170', 6$20' -6490', 6410' -- 5020'. Pickup is about 100' above the shoe depth. It is reasonable to believe that the cement in that interval is similar to that examined above. It is my assessment that MI is indicated, however the appearance of the lag presentation is unusual. Fti, 6~ ~~~ ~ ~ Date 09-20-2007 Transmittal Number:92904 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) f you have any questions, please contact Douglas Dortch at the PDC at 564-4y73 Deliver Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 09-15A ao'~ -oa9 ~ ~S~l~rl AGI-10Aao~--3S` ~` iS~l$a _____ _. - -__ _ _ F-01A c7(~(o-tb~ * ~5~/~3 4r5~/~~/ F-01 APB1 F-096ao~-~r3 ~ ~5~/1s5 F-42A aU'}- U~3 ~ i S~/~~ L-204L1 c~(~_Uc73 ~ r5~/~~ L-204L2 avt,- bq ~/ ~ tS~/~5f L-204L3 a(~-025 ~/S~/~ L-204L4 a U(o-p~ ~ ~ r Jc-c~ ~ ~ N-22B c7U~o -!!o / fi /5 </9 / V-205L1 c70Co - l1f 1 ~ I s~l~j a V-205L2 c7Ulo-I`lfc7 ~` 1S~`3 W-204L1_c2_UCa-1.59 '~ r_'J: S!`i</_ __ W-204L2 app-l 10.0_ r' 15/45 ____ 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- t 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 b~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to Winton Arlbert@adrnin state.ak us; Bob_Fleckenstein@admin.State.akus; Jim_Ragg@admin.state ak.us. Tom_Nlaunder@admin.state.akus OPERATOR: BP Exploration (Alaska).. Inc. i~` ~t ~ ,j~ ?~ ~'wl ~" FIELD !UNIT /PAD: Prudhoe Bay 1 PBU i WGI pad DATE: 03/12/07 OPERATOR REP: Andrea Hughes AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well WGI-09 Type Inj. G TVD 7,942' Tubing 3,140 3,140 3,140 3,140 Interval P P.T.D. 2061460 Type test P Test psi 2200 Casing 900 2,230 2,210 2,200 PIF P Notes: AOGCC declined to witness MIT-IA post-Initial OA 300 440 440 430 Injection. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I = Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Surrey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU WGI-09 03-12-07 xls T[GVGS V GV ' STATE OF ALASKA FE~ 7 2007 .~ eT-o~ WELL COMPLET ON OR RECOMPLETI~N R~~ ~ssion ~~~ ~~ Revised: 02/07/07, Put on Injection 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs., ~o ® GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class; ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/7/2006 12. Permit to Drill Number 206-146 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/15/2006 13. API Number ~ 50-029-23327-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/1/2006 14. Well Name and Number: PBU WGI-09 ~ 5051 FSL, 1215 FEL, SEC. 11, T11N, R14E, UM Top of Productive Horizon: 1405' FSL, 2088' FEL, SEC. 02, T11 N, R14E, UM 8. KB Elevation (ft): ~ 50.59' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1405' FSL, 2089' FEL, SEC. 02, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 8891 + 8582 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 684979 y- 5972032 Zone- ASP4 10. Total Depth (MD+TVD) 8891 + 8582 Ft 16. Property Designation: ADL 028302 ~ TPI: x- 684065 y_ 5973644 Zone- ASP4 Total Depth: x- 684064 y- 5973644 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR /PWD, MWD DIR / GR /PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING` DERTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP' BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A53 Surface 113' Surface 113' 42" 260 sx Arctic Set A rox. 13-3l8" 68# L-80 34' 4638' 34' 4237' 16" 879 sx Class AS Lite 595 sx 'G' -5/8" 47# L-80 32' 8381' 2' 8072' 12-1/4" 410 sx Li Crete 65 sx Cla 'G' 7" 26# L-80 8290' 8890' 7981' 8581' 8-1/2" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 7" Slotted Section 7-518", 29.7 x 7", 26#, L-80 8296' 8251' MD TVD MD TVD 8492' - 8888' 8182' - 8579' 25. ' ; AGID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED Freeze Protect with 100 Bbls Diesel 26. PRODUCTION TEST Date First Production: February 3, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~~ ~~~ ~ ~ 207 None Form 10-407 Revised 12/2003 f~^~ ~ ~ ~ (\ K;ONTINUED ON REVERSE SIDE {gyp; H L 28. GEOLOGIC MAR 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8384' 8075' None Shublik A 8434' 8125' Shublik B 8447' 8138' Shublik C 8461' 8152' Sadlerochit 8475' 8166' Top CGL 8568' 8259' Base CGL 8654' 8345' 23SB /Zone 26 8713' 8404' 22TS 8747' 8438' 21 TS /Zone 2A 8774' 8465' Zone 1 B 8804' 8495' TDF /Zone 1A 8834' 8525' Base Sadlerochit 8890' 8581' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. F O ~ ~/t/ Signed Terrie Hubble Title Technical Assistant Date PBU WGI-09 206-146 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS Gewew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 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). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only a~~ ~ _. STATE OF ALASKA • / / ~ ..~ ~ U"~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG iz',r~ 0 S 2007 '~~~ ~~a~ ~~~ ~~ K~~ r~n~~ r~r 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.>>o D,O~ ® GINJ ^ WINJ ^ WDSPL No. of Completions One Other /'/ 1b. Well Class: ^ Developmt"°~~'cploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban~,/„ ~1-2Rt2886 ~d'vv'r~' 12. Permit to Drill Number 206-146 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/15/2006 13. AP- Number 50-029-23327-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/1/2006 14. Well Name and Number: PBU WGI-09 5051 FSL, 1215 FEL, SEC. 11, T11N, R14E, UM Top of Productive Horizon: 1405' FSL, 2088' FEL, SEC. 02, T11 N, R14E, UM 8. KB Elevation (ft): 50.59' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1405' FSL, 2089' FEL, SEC. 02, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 8891 + 8582 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 684979 y- 5972032 Zone- ASP4 10. Total Depth (MD+TVD) 8891 + 8582 Ft 16. Property Designation: ADL 028302 ' TPI: x- 684065 y- 5973644 Zone- ASP4 Total Depth: x- 684064 y- 5973644 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ~ 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR /PWD, MWD DIR / GR /PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD $ETTING'DEPTH TVD HOLE AMOUNT SIZE Wr• PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A53 Surface 113' Surface 113' 42" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 34' 4638' 34' 4237' 16" 879 sx Class AS Lite 595 sx 'G' 9-518" 47# L-80 32' 8 81' 32' 8072' 12-1/4" 410 x Lite rete 365 x I 'G' 7" 26# L-80 8290' 8890' 7981' 8581' 8-1/2" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TueING RECORD Bottom Interval, Size and Number; if none, state "none"}: SIZE DEPTH SET MD PACKER SET MD 7" Slotted Section 7-5/8", 29.7 x 7", 26#, L-80 8296' 8251' MD TVD MD TVD 8492' - $888' $182' - 8579' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED Freeze Protect with 100 Bbls Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PfeSS. Casing Pressure CALCULATED 24-HOUR RATE• OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet,, i# necessary). Submit core chips; if none, state "none". " . ` None 3 Irt Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28 GEOLOGIC MARKER 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, Name MD TVD and attach detailed supporting data as necessary. If no tests were conducted state "None". Sag River 8384' 8075' None Shublik A 8434' 8125' Shublik B 8447' 8138' Shublik C 8461' 8152' Sadlerochit 8475' 8166' Top CGL 8568' 8259' Base CGL 8654' 8345' 23SB /Zone 26 8713' 8404' 22TS 8747' 8438' 21TS /Zone 2A 8774' 8465' Zone 1 B 8804' 8495' TDF /Zone 1A 8834' 8525' Base Sadlerochit 8890' 8581' 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. (~ / Si d "' ~S gne Terrie Hubble Title Technical Assistant Date / O Pi3U WGI-09 206-146 Prepared By Namemlumber. Terrie Hubble, 564-4628 Well Number Permit No. I A rOVal NO. Drilling Engineer: Ron Phillips, 564-5913 (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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: WGI-09i Common Name: WGI-09i Test Date j Test Type 11/23/2006 LOT 12/1/2006 FIT --__-_-- Test Depth (TMD) Test Depth (ND) AMW Surtace Pressure Leak Off Pressure (BHP) EMW 4,637.0 (ft) 4,517.0 (ft) 9.50 (ppg) 1,100 (psi) 3,329 (psi) 14.19 (ppg) 8,381.0 (ft) 8,072.0 (ft) 8.80 (ppg) 525 (psi) 4,215 (psi) 10.05 (ppg) • Printed: 12/11/2006 2:36:09 PM • BP EXPLORATION Operations Summary Report Page 1 of 18 Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date I From - To ~ Hours I Task ,Code ; iVPT I Phase 11/12/2006 105:00 - 00:00 19.00 MOB P 11/13/2006 100:00 - 00:00 I 24.001 MOB I P 11/14/2006 100:00 - 03:00 I 3.001 MOB I P 03:00 - 18:00 I 15.001 RIGU I P 18:00 - 20:30 ~ 2.50 RIGU P 20:30 - 22:00 1.50 RIGU P 22:00 - 00:00 2.00 RIGU P 11/15/2006 00:00 - 05:30 5.50 RIGU P Description of Operations PRE Rig released from AGI-10A at 05:00 hrs. Blow down rig Rig down service line Separate rig modules Prepare to move from AGI to WGI pad. Separate modules and install moving systems Clean up location, removing hecurlite and matting boards Transported Pipe shed, motor complex, pump module, pit module and sub base PRE MIRU on WGI -09i, Set 20" Annular / adaptor spool on conductor Set matting boards and Herculite for Sub Base, Spot Sub over well Set matting boards and Herculite for Pipe Shed, Spot Pipe Shed Set matting boards and Herculite for Pits, Spot Pits Set matting boards and Herculite for Pump Room, Spot Pump Room Set matting boards and Herculite for Motor Room, Spot Motor Room Connect services lines in disconnect hallway Finish securing berms and spill protection Moved camp & shop set Tiogas & berm PRE -Finish all berming and spill protection barriers, -Hook up all steam, water and services lines -Connect all Electrical lines between rig modules -R/U pipe shed & skate RIG ACCEPTED C~3 03:00 hrs PRE -Rig up Diverter System and Riser -Hook up Flowlines and Mud Lines -Function Test Drawworks and TDS -Load DP and strap -Take on mud into pits -C/O saver sub on TDS pipe handler -Install drip pan cover Pre-Spud meeting PRE P/U 5" DP and rack back into derrick PRE Test Surface Diverter System -Witness of test;Jeff Jones, AOGCC; Dave Newlon, BP WSL; Dave Richards, NAD Toolpusher -Diverter closing time 1:59; Knife valve open in 17 sec -Koomey test; Initial psi - 3100 /post function 2000 psi, 200 psi recoveryl5 sec, complete recovery 1:25 8 nitrogen bottles -avg. 2300 psi -Check gas sensors and PVT system Tota- Diverter length = 75' PRE P/U 5" DP and rack back into derrick PRE P/U 5" DP & 5" HWDP and stand back in derrick Pre Spud meeting Printed: 12/11/2006 2:36:15 PM i • BP EXPLORATION Page 2 of 18 Operations Summary Report Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date From - To ~ Hours ~ Task Code NPT Phase Description of Operations 11/15/2006 05:30 - 06:00 0.50 RIGU P PRE 06:00 - 08:00 2.00 RIGU P PRE 08:00 - 08:30 0.50 RIGU P PRE 08:30 - 09:00 0.50 RIGU P PRE 09:00 - 09:30 I 0.501 DRILL I P I I SURF 09:30 - 12:00 2.501 DRILL P I I SURF 12:00 - 15:00 I 3.001 DRILL I P I I SURF 15:00 - 16:30 I 1.501 DRILL I P I I SURF 16:30 - 23:00 ~ 6.501 DRILL ~ N ~ SFAL ~ SURF 23:00 - 00:00 I 1.00 DRILL P 11/16/2006 ~ 00:00 - 00:30 I 0.50 ~ DRILL ~ P SURF SURF 00:30 - 03:00 I 2.501 DRILL I N I SFAL I SURF 03:00 - 06:00 I 3.001 DRILL I N I SFAL I SURF 06:00 - 06:30 I 0.50 ~ DRILL P I SURF 06:30 - 09:00 I 2.501 DRILL I N I SFAL I SURF Finish securing Stack and Flowline M/U 16" Bit and PDM, FS & NM Stab Safety Stand Down meeting Pressure test stand pipe to 4000 psi Check mud lines for leaks Good Test Fill Hole and break Circulation, -Check for leaks, Inspected Flowline and Diverter System for Leaks Spud well, Drill f/113' - 312' 650 gpm / 860 psi/ 70 rpm/ WOB 2-10k Standback 3 stds. of HWDP, - P/U MWD, UBHO, # NM Flex DC's Plug-in MWD and QC tool (45 min) Clear floor and Make up Top Drive Drill F/312' _> 455' 650 gpm / 1400 psi/ 60 rpm/ WOB 2-10k/ TO 2 PUW = 82k,SOW=82k, Rt=82k Gravel Clogged flowline and jetlines, -1/2" minus gravel filled trough under shakers, -Gravel in mud system plugging gun lines -Removed all the shaker screens and clean out gravel -cleared gun lines Drill F/ 455' - 465' 550 gpm / 1400 psU 60 rpm/ WOB 2-10k/ TO 2 PUW = 82k,SOW=82k, Rt=82k Controliing ROP to less than 80'/hr until higher circulation rates possible Drill F/ 455' - 465' 550 gpm / 1400 psU 60 rpm/ WOB 2-10k/ TO 2 PUW = 82k,SOW=82k, Rt=82k Controliing ROP to less than 80'/hr until higher circulation rates possible Flowline Plugged with Gravel, 3-4 bbl/min max circ. rate Attempted to jet flowline to flush gravel from flowline unsuccessfully Max rate after jetting 4-5 bbl/min Dismantle flowline from drilling nipple to Disconnect Hallway Flowline 65 -75% plugged Rig up Super Sucker to Remove Gravel Nipple flowline back up Break Circ. and ramp up to 650 gpm Drill F/ 465' - 485' 650 gpm / 1000 psU 60 rpm/ WOB 2-10k/ TO 2 PUW = 82k,SOW=82k, Rt=82k Controlling ROP to less than 80'/hr until higher circulation rates possible Flowline Plugged with Gravel, Jet flowline to flush gravel from flowline Install new Jet into Flowline Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date From - Ta .Hours I _- - Task ~ Code NPT~Phase ~ Description of Operations 11/16/2006 06:30 - 09:00 2.50 DRILL N SFAL SURF Circ. Rate 700 gpm / 1600 psi 09:00 - 13:30 4.50 DRILL P SURF Drill F/ 485' - 815' 700 gpm / 1600 psV 60 rpm/ WOB 2-10W TO 2 PUW = 90k,SOW=88k, RtWt=90k Controlling ROP to less than 150'/hr 13:30 - 14:00 0.50 DRILL N SFAL SURF Change out Hydraulic hose on Rig Floor tugger 14:00 - 16:00 2.00 DRILL P SURF R/U and run HES gyro 16:00 - 17:00 1.00 DRILL P SURF Drill F/ 815 - 907' 700 gpm / 1600 psi/ 60 rpm/ WOB 2-10W TO 2 PUW = 90k,SOW=88k, RtWt=90k Controlling ROP to less than 150'/hr 17:00 - 17:30 0.50 DRILL P SURF Run HES gyro 17:30 - 21:00 3.50 DRILL P SURF Jet flowline, Clear plug flowfine jets, Cleanout possum belly Estabilish Circ. Rate ~ 700 gpm / 1850 psi 21:00 - 22:00 1.00 DRILL P SURF Drill F/ 907'-1000' 700 gpm / 1850 psi/ 60 rpm/ WOB 2-10W TO 2 PUW = 100k,SOW=97k, RtWt=98k Controlling ROP to less than 250'/hr 22:00 - 22:30 0.50 DRILL P SURF Run HES gyro 22:30 - 23:30 1.00 DRILL P SURF Drill F/ 1000'-1095 700 gpm / 1850 psU 60 rpm/ WOB 2-10W TO 2 PUW = 100k,SOW=97k, RtWt=98k 23:30 - 00:00 0.50 DRILL P SURF Run HES gyro 11/17/2006 00:00 - 01:00 1.00 DRILL P SURF Drill F/ 1095 -1190' 700 gpm / 1900 psi/ 60 rpm/ WOB 2-10W TO 2 PUW = 100k,SOW=97k, RtWt=98k 01:00 - 01:30 0.50 DRILL P SURF Run HES Gyro 01:30 - 03:00 1.50 DRILL P SURF Drill F/ 1190'-1285' 700 gpm / 1850 psU 60 rpm/ WOB 2-10W TO 2 PUW = 100k,SOW=97k, RtWt=98k 03:00 - 04:00 1.00 DRILL P SURF Run HES Gyro 04:00 - 05:30 1.50 DRILL P SURF Drill F/ 1285' - 1376' 700 gpm / 1850 psi/ 60 rpm/ WOB 2-10W TO 2 PUW = 100k,SOW=97k, RtWt=98k 05:30 - 06:00 0.50 DRILL P SURF Run HES Gyro 06:00 - 07:00 1.00 DRILL P SURF Drill F/ 1376' - 1472' 700 gpm / 1950 psi/ 60 rpm/ WOB 2-10W TO 2 PUW = 102k,SOW=100k, RtWt=102k 07:00 - 07:30 0.50 DRILL P SURF Run HES Gyro 07:30 - 12:00 4.50 DRILL P SURF Drill F/ 1472' - 1944' 750 gpm /2250 psi/ 60 rpm/ WOB 8-10W TO 2 PUW = 112k,SOW=110k, RtWt=112k 12:00 - 18:30 6.50 DRILL P SURF Drill F/ 1944' - 2607' 750 gpm /2450 psU 60 rpm/ WOB 10-25W TO 3/5 PUW = 112k,SOW=110k, RtWt=112k 18:30 - 19:30 1.00 DRILL P SURF Change Shaker Screens, Cleen Possum belly Clean clay out of Shaker trough Adding Screen clean to manage heavy clay returns 19:30 - 00:00 4.50 DRILL P SURF Drill F/ 1567' - 3080 750 gpm /2450 psi/ 60 rpm/ WOB 10-25W TO 3/5 Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Operations Summary Report Page 4 of 18 ~ Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12!7/2006 Rig Name: NABOBS 27E Rig Number: Date From - To ~ Hours _ - ~ Task Code NPT Phase ~ Description of Operations 11/1.7/2006 19:30 - 00:00 4.50 DRILL P SURF PUW = 138k,SOW=130k, RtWt=135k 11/18/2006 00:00 - 01:00 1.00 DRILL P SURF Circulate and clean hole for Wiper Trip 750 gpm /2450 psi / 80 rpm Monitor Well ,static, MW in 9.2 /out 9.2 ppg 01:00 - 03:00 2.00 DRILL P SURF Pump out of hole 3080 - 2133' 750 gpm / 2400 Clean hole / no issues Monitor welt ~ 2133', well showed static 03:00 - 05:00 2.00 DRILL P SURF POH 2133' - 905' 25k overpull 1100' - 905' pulled slow through without swabbing or problems 05:00 - 06:30 1.50 DRILL P SURF RIH, no problems 06:30 - 08:30 2.00 DRILL N SFAL SURF Repair Mud Pump Suction line leak 08:30 - 16:30 8.00 DRILL P SURF Drill F/ 3080-3835' 750 gpm /3000 psi/ 80 rpm/ WOB 10-35k/ TO 5/6 PUW = 155k,SOW=135k, RtWt=150k 16:30 - 17:30 1.00 DRILL P SURF Circ. ~ reduce rates (300 GPM) -changing screens and adding screen clean to help handle the sticky clays 17:30 - 00:00 6.50 DRILL P SURF Drill F/ 3835' - 4386' 800 gpm /3200 psi/ 80 rpm/ WOB 10-35W TO 5/6 PUW = 165k,SOW=150k, RtWt=155k 11/19/2006 00:00 - 02:00 2.00 DRILL N SFAL SURF Repair #1 Mud Pump -Change out liner & swab 02:00 - 06:00 4.00 DRILL P SURF Drill F/ 4386'-4653' 800 gpm /3100 psi/ 80 rpm/ W OB 10-35k! TO 5/6 PUW = 170k,SOW=150k, RtWt=160k 06:00 - 09:00 3.00 DRILL P SURF Circulate & clean hole to POH & run 13 3/8 casing -pump 50 bbl high Vis sweep with nut plug -800 gpm / 3000 psi / 80 rpm 3x BU - MW = 9.5 ppg in /out Monitor well -static 09:00 - 13:00 4.00 DRILL P SURF POH from 4653 - 1661' Work through areas of tight hole 3743 - 2228' 50 k overpulls ~ 3300-2890' 13:00 - 14:30 1.50 DRILL P SURF RIH back to bottom to circ. hole clean No Issues RIH, No Fill 14:30 - 17:00 2.50 DRILL P SURF Circulate & clean hole to POH & run 13 3/8 casing -800 gpm / 3000 psi / 80 rpm 1.5 x BU - MW = 9.5 ppg in /out Monitor well -static 17:00 - 22:00 5.00 DRILL P SURF POH from 4653 - 198" Pulled clean, no issues, SLM (no change) 22:00 - 23:00 1.00 DRILL P SURF Plug-in to collar & Download HES MWD /LWD logging data 23:00 - 00:00 1.00 DRILL P SURF L/D MWD /LWD collars 11/20/2006 00:00 - 01:00 1.00 DRILL P SURF Break Bit and lay down mud motor and Stab. Clear Floor and R/D BHA handling equip. 01:00 - 03:30 2.50 CASE P SURF Rig up 13 3/8 casing running equipment PJSM with rig crew and NAD casing hands -Make Dry run with casing hanger and landing, joint (O.K.) -M/U Franks fill up tool -P/U long bales ,Elevators and slips -P/U centrilizers from outside Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 5 of 18 ~ Operations Summary Report... Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date !From - To Hours Task Code ~ NPT ~ Phase 11/20/2006 01:00 - 03:30 2.50 CASE P SURF 03:30 - 17:30 14.00 CASE P SURF Description of Operations -Ready casing tongs and backups P/U 13 3/8" BTC casing shoe jt., bakerlocked jt, float collar jt,18 jts of 13 3/8" 68# BTC-M, 67 jts of 13 3/8" 68# BTC, Pup jt, TAM collar, Pup Jt., 23 jts 13 3/8" 68# BTC, FMC fluted hanger with pup jt., Landing jt - landed casing ~ 4637' PUW - 315k /SOW - 215k Centralizers ran on jt 1-25, & jt 88,89 All jts drifted to 12.259" Circ. w/ Franks tool ~ 1472', 1804', 2049', 2131' - 240 gpm (350 psi) to condition thick mud 17:30 - 20:30 20:30 - 21:30 21:30 - 22:00 22:00 - 22:30 22:30 - 00:00 11 /21 /2006 00:00 - 00:30 00:30 - 05:30 3.001 CASE I P 1.001 CASE I P 0.50 CASE P 0.50 CASE N 1.50 CASE P 0.50 CEMT P 5.00 CEMT P SURF SURF SURF SFAL SURF SURF SURF SURF Break circ. ~ 3 bpm ramping up to 9 bpm / 700 psi -treat mud dropping Vis. from 250 to 62 and reducing Yield Point from 50 to 18. -Conducted PJSM and review Cementing procedure with Veco truck drivers, MI Mud Engineers, NAD spill champion -Conducted PJSM and review Cementing procedure with Dowell /Schlumberger personel and rig crews -Removed Franks fill up tool -Rig up 13 3/8" double plug cement head -Rig up cement lines -Blow down TDS, -Blow down hardline to cement unit Circ. and conditon mud for cement job 2" Hardline between rig floor and Cement hose washed out, Rig down hard line and rig up cement line to cement head Circ. and conditon mud for cement job ~ 10 bpm / 400 psi -Conducted PJSM and Cementing procedure with rig crews PJSM and review Surface Cement Job procedure with Nabors Rig crew Flush Cement lines, Test to 3000 psi- good test, Pump 150 bbl of 10.6 ppg Mud Push XL Spacer Pump rate 5.5 BPM ~ 300 psi Drop bottom piug, positive indication plug left Mix & Pump 703 bbl of 10.7 ppg ASIII Lite lead slurry per Schlumberger program Pump rate of 6-7 BPM ~ 800 psi Pump 123 bbl of 15.8 ppg Class G tail slurry per Schlumberger program, Pump rate of 6 BPM C~3 1,200 psi Drop Top Plug, Kick out plug with 10 bbl of water, positive indication plug left Switch to rig pump and start displacing cement 10 BPM ~ 330 psi Mud Push back ~ 120 bbl away -sending mud to vac truck At 4500 stks away 100% of 10.7 ppg cement returns, taking 90% returns to vac truck and 10 % down flowline to cuttings tank continue displacing (a3 6 - 8 BPM till 6500 stks away Bumped ~ 3 bbl /min 1300 psi @ 6760 stks. Held 1860 psi for 5 min. Printed: 12/11/2006 2:36:15 PM • BP EXPLORATION Operations Summary Report Page 6 of 18 Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date I From - To Hours ' Task Code ~ NPT ~ Phase Description of Operations 11/21/2006 00:30 - 05:30 5.00 CEMT P SURF 227 bbls of 10.7+ cement back to surface. -C1P ~ 05:15 Break lines off and check floats, floats holding. 05:30 - 06:30 1.00 CEMT P SURF Rig down Cement equipment, clean and clear rig floor 06:30 - 10:00 3.50 CEMT P SURF Attempted to back out landing joint, backed out of 10' pup below rotary table Screw back into pup, back out landing joint and lay down landing joint 10:00 - 13:00 3.00 DIVRTR P SURF Clear floor, clean riser, prepare for nipple down, Rig up and jet flow line 13:00 - 18:30 5.50 DIVRTR P SURF Nipple down diverter system and remove from cellar 18:30 - 22:30 4.00 WHSUR P SURF Nipple up FMC Big Bore Uni head well head, test flange to 1,000 psi, test passed 22:30 - 00:00 1.50 BOPSU P SURF Nipple up BOPS, clean out flow line, weld 18" onto bell nipple 11/22/2006 00:00 - 12:00 12.00 BOPSU P SURF Nipple up BOPS, clean out flow line, extend bell nipple 18", Install secondary Annulus valve, air boot failed on bell nipple, replace air boot 12:00 - 13:30 1.50 BOPSU P SURF Make up test joint and install test plug 13:30 - 14:00 0.50 BOPSU P SURF Function test BOPs 14:00 - 22:00 8.00 BOPSU P SURF Test BOPs, AOGCC waived witness as per Lou Grimaldi BOP test witnessed by Joey LeBlanc and Chris Clemens WSTL, Wayne Stout and Dave Hanson NTP Low test pressure 250 psi, High test pressure 4,000 psi #1 Annular high test pressure 3,500 psi #2 TIW valve, Top Pipe Rams, choke 1, 2, Kill HCR #3 Choke 3,4,5,6, Manual Kill, pressure bleed off, cycle #6, test passed #4 Choke 7,8,9, Dart Valve #5 Choke 10,11,12 #6 Choke 13,14,15, 16 #7 Manual Choke #8 Choke HCR #9 Lower Pipe Rams #10 Upper Well Control Valve #11 Lower Well Control Valve #12 Blind Rams Accumulator test 1,850 psi after functioning all valves, 28 sec for 200 psi, 1 min 40 sec for full recovery to 3,100 psi Average charge for 8 bottles of Nitrogen is 2,260 psi 22:00 - 23:00 1.00 BOPSU P SURF Rig down test equipment, blow down all lines, clean and clear rig floor 23:00 - 23:30 0.50 WHSUR P SURF Install long wear bushing, run in lock down screws 23:00 - 00:00 1.00 MOB P SURF Bring all equipment to the. rig floor for 12 1/4" drilling BHA 11/23/2006 00:00 - 01:00 1.00 DRILL P INTi Pick up BHA, Motor, Float sub, Stabilizer 01:00 - 02:00 1.00 DRILL P INT1 Service top drive 02:00 - 03:00 1.00 DRILL P INT1 Pick up BHA, XOS, MWD, and bit Orient motor to MWD 03:00 - 03:30 0.50 DRILL P INT1 Up load to MWD tool 03:30 - 05:00 1.50 DRILL P INT1 RIH with collar stand and HWDP/Jars out of derrick 05:00 - 05:30 0.50 DRILL P INT1 RIH with 5" drill pipe from 893' to 1,089' 1x1 picking up 5" drill pipe Pick up first Ghost Reamer, 1,000' behind bit and RIH 2 singles Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Operations Summary Report Page 7 of 18 ~ Legal Weil Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To j Hours ~ Task Code NPT Phase j Description of Operations 11/23/2006 05:00 - 05:30 1 0.50 DRILL P INT1 past TAM collar 05:30 - 06:00 0.50 DRILL P INT1 Pulse test MWD tool 800 GPM C~ 2,160 psi, good test 06:00 - 09:00 3.00 DRILL P INT1 PJSM, Change out back up wrench dies on top drive PJSM, Cut and slip 102' of drilling line Check crown saver 09:00 - 11:00 2.00 DRILL P INT1 PJSM, RIH with 5" drill pipe from 1,089' to 2,324' 1x1 picking up 5" drill pipe 11:00 - 11:30 0.50 DRILL P INTi Fill pipe, break circulation, and pulse test MWD 700 GPM ~ 1,870 psi Blow down top drive 11:30 - 15:30 4.00 DRILL P INT1 RIH with 5" drill pipe from 2,324' to 4,477' 1x1 picking up 5" drill pipe 15:30 - 16:00 0.50 DRILL P INT1 Wash down from 4,477' to 4,540' and circulate before casing test 350 GPM ~ 730 psi PJSM for casing test 16:00 - 16:15 0.25 CASE P INT1 Rig up to test casing Attempt to Pressure test 13 3/8" 68# L-80 BTC Casing to 3,500 psi, at 900 psi encountered sudden loss in pressure, bleed off remaining pressure 16:15 - 17:00 0.75 CASE P INT1 Safety stand down with crew Investigate cause of pressure loss and correct deficiency 17:00 - 18:00 1.00 CASE P iNT1 Pressure test 13 3/8" 68# L-80 BTC Casing to 3,500 psi (98 stks = 3,550 psi), chart for 30 minutes No pressure loss 18:00 - 19:30 1.50 DRILL P INT1 Wash down and tagged up at 4,546', 3' cement on top of plugs PUW=175K, SOW=145K, RTW=160K Drill cement and plugs WOB = 5 klbs, 20 RPMs ~ 4 KfUlbs off bottom, 6 Kft/Ibs on bottom, 650 GPM ~ 1964 psi off, 2,010 psi on Drill float collar at 4,551' WOB = 5-10 klbs Continue drilling cement to Shoe ~ 4,637' WOB = 10-15 klbs Clean rat hole down to 4,653' 19:30 - 21:30 2.00 DRILL P INT7 Displace to new 9.5 LSND mud 800 GPM ~ 1,770 psi, 80 RPMs fe1 5-8 kfUlbs off bottom 60 bbls of water 35 bbls of Hi Vis Spacer 650 bbls of 9.5 ppg LSND mud PUW=179K, SOW=155K, RTW=169K 800 GPM C 1,920 psi, 80 RPMs @ 3 kft/Ibs off bottom Take slow pump rates 21:30 - 22:00 0.50 DRILL P INTi Drill 20' of new hole from 4,653' to 4,673' 800 GPM @ 1,920 psi off, 2,100 psi on, 80 RPMs C~3 3 kft/Ibs off, 6 kft/Ibs on, WOB=15-20 klbs 22:00 - 23:00 1.00 DRILL P INT1 Circulate bottoms up prior to Leak off test 800 GPM @ 1,950 psi, 30 RPMs @ 2.7 kfUlbs ECD base line MW=9.5, PV=9, YP=20, 0 RPMs - 800 GPM @ 1,856 psi, CECD=9.76 (from model), AECD=9.78 Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 8 of 18 Operations Summary Report Legal Well Name: WGI-09i Common W ell Name: WGI-09i Spud Date: 11/15/2006 Event Nam e: DRILL+C OMPLE TE Start : 11/13/2006 End: 12/7/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/7/2006 Rig Name: NABOB S 27E Rig Number: Date From - To Hours Task ; Code NPT Phase Description of Operations II11/23/2006 22:00 - 23:00 1.00 DRILL P INT1 80 RPMs - 800 GPM ~ 1,860 psi, CECD=9.76 (from model), AECD=9.78 23:00 - 00:00 1.00 DRILL P INT1 Leak off test Hole depth 4,673' Shoe depth 4,637' Shoe ND 4,517' MW 9.5 ppg Leak off Pressure 1,100 psi Final test Pressure 1,270 psi EMW = 14.1 pP9 Charted for 10 minutes, Initial shut in pressure 1,270 psi, final shut in pressure 650 psi 11/24/2006 00:00 - 06:00 6.00 DRILL P INT1 Drill ahead from 4,673' to 5,170', Correction slides as needed to maintain sail angle of 20 degrees, BHA has slight building tendency, Control drill < 300'/hr for logs 850 GPM @ 2,260 psi off, 2,540 psi on, CECD=9.64, AECD=9.72, MW=9.5 W0B=12-16K, PUW=180K, SOW=160K, RWT=172K Torque 4.OK off, 6.OK on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Pumped 30 bbl weighted sweep @ 5,170', 11.9 ppg 90 Vis, Returns increased by 3% 06:00 - 12:00 6.00 DRILL P INT1 Drill ahead from 5,170' to 5,691', Correction slides as needed to maintain sail angle of 20 degrees, BHA has slight building tendency, Control drill < 300'/hr for logs 850 GPM ~ 2,260 psi off, 2,450 psi on, CECD=9.61, AECD=9.72, MW=9.45 WOB=10-14K, PUW=195K, SOW=170K, RWT=182K Torque 4.OK off, 4-6K on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Noon Update ADT=7.35 hrs, AST=1.33 hrs, ART=5.91 hrs 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead from 5,691' to 6,630', Correction slides as needed to maintain sail angle of 20 degrees, BHA has slight building tendency, Control drill < 300'/hr for logs 850 GPM C~ 2,750 psi off, 2,950 psi on, CECD=9.67, AECD=9.89, MW=9.5 W0B=10-15K, PUW=205K, SOW=186K, RWT=200K Torque 5.OK off, 6.OK on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Noon Update ADT=8.96 hrs, AST=0.55 hrs, ART=8.52 hrs 11/25/2006 00:00 - 06:00 6.00 DRILL P INT1 Drill ahead from 6,630' to 6,975', Correction slides as needed to maintain sail angle of 20 degrees, BHA has slight building tendency, Control drill < 300'/hr for logs, start drop to vertical around 7,300' 850 GPM C~ 2,800 psi off, 3,100 psi on, CECD=9.68, AECD=9.93, MW=9.5 ECD's averaging 0.2-0.3 over calculated W06=13-15K, PUW=213K, SOW=188K, RWT=202K Torque 5.OK off, B.OK on @ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Pumped 30 bbl weighted sweep @ 6,700', 11.0 ppg, 70 Vis, noticeable increase in cutting, around 15-20% Connection gas from surface to 6,700' was around 60 units, gas increasing, spikes at 6,770' - 1,500 units, 6,825' - 2,000 Printed: 12!11!2006 2:36:15 PM BP EXPLORATION Page 9 of 18 Operations Summary Report ',Legal Well Name: WGI-09i 'Common W ell Name: WGI-09i Spud Date: 11/15/2006 Event Nam e: DRILL+C OMPLE TE Start : 11/13/2006 End: 12/7/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/7/2006 Rig Name: NABOB S 27E Rig Number: Date From - To Hours Task ~ Code NPT Phase ~ Description of Operations 11/25/2006 00:00 - 06:00 6.00 DRILL P INT1 units, 6,885' - 2,000 units but well static on flow checks and connections, very little aeration in the mud Increasing mud weight to 9.7 ppg 06:00 - 12:00 6.00 DRILL P INT1 Drilt ahead from 6,975' to 7,346', start drop to vertical at 7,255', sliding 30-40' per stand and getting 2-3/100' DLS 850 GPM @ 3020 psi off, 3,250 psi on, CECD=9.88, AECD=10.08, MW=9.7 ECD's averaging 0.2 over calculated W06=14-16K, PUW=223K, SOW=192K, RWT=207K ', Torque 10.OK off, 12-13K on ~ 80 RPMs ~ back ream full stand at drilling rate going up, 70% coming down Connection gas remains around 1,500 to 2,000 units, Flow check every connection, well static Noon Update ADT=8.92 hrs, ART=6.30 hrs, AST=2.62 hrs 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead from 7,346' to 7,965', Continue dropping to vertical, sliding 30-40' per stand and getting 2-3/100' DLS 835 GPM ~ 3120 psi off, 3,350 psi on, CECD=9.98, AECD=10.15, MW=9.8 ECD's averaging 0.2 over calculated W06=15-25K, PUW=237K, SOW=200K, RWT=222K Torque 10.OK off, 12-13K on ~ 80 RPMs back ream full stand at drilling rate going up, 70% coming down Pumped 25 bbl weighted sweep ~ 7,450', 11.1 ppg, 60 Vis, no noticeable increase in cutting, around 5% Connection gas remains around 1,500 to 2,000 units through out the day, Flow check every connection, well static Midnight Update ADT=9.33 hrs, ART=5.82 hrs, AST=5.39 hrs 11/26/2006 00:00 - 07:30 7.50 DRILL P INT1 Drill ahead from 7,965' to 8,368', Finished curve at 8,160', rotate to TD i 820 GPM ~ 2,980 psi off, 3,235 psi on, CECD=9.96, AECD=10.00, MW=9.8 ECD's averaging 0.15 over calculated WOB=10-15K, PUW=252K, SOW=207K, RWT=228K Torque 10-12K off, 12-15K on ~ 80 RPM back ream full stand at drilling rate going up, 70% coming down Connection gas remains around 1,500 to 2,000 units, Flow check every connection, well static 07:30 - 09:30 2.00 DRILL P INTi Mad pass from 8,245' to 8,368' while circulating up sample to verify TD '~ POH at 160'/hr for logs 820 GPM ~ 3000 psi, 80 RPM ~ 11.5 Kft/Ibs 1,980 units of Gas on bottoms up 09:30 - 10:00 0.50 DRILL P INT1 Drill ahead from 8,368' to 8,385', rotate ahead looking for a reverse drilling break to pick top of Sag River 820 GPM ~ 2,980 psi off, 3,235 psi on, CECD=9.96, AECD=10.00, MW=9.8 WOB=13K, PUW=252K, SOW=207K, RWT=228K Torque 10-12K off, 13-14K on Cut 80 RPM ADT=4.55 hrs, ART=3.21 hrs, AST=1.34 hrs 10:00 - 11:00 1.00 DRILL P INT1 Circulate for sample to confirm TD in Sag River 820 GPM Cu? 2,970 psi, 80 RPM ~ 11.7 KfUlbs Geologist confirm we are at TD 11:00 - 13:00 2.00 DRILL P INTi Circulate 30 bbls Sweep with nut plug 800 GPM @ 2,770 psi, 80 RPM @ 11.5 KfUlbs Sweep came back 400 strokes after calculated, calculates to 7.5% washout Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 10 of 18 Operations Summary Report 'Legal Well Name: WGI-09i Common Well Name: WGI-09i Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 27E Date From - To ;Hours ' Task Code NPT Spud Date: 11 /15/2006 Start: 11/13/2006 End: 12/7/2006 Rig Release: 12/7/2006 Rig Number: Phase ',11/26/2006 ~ 11:00 - 13:00 ~ 2.00 ~ DRILL ~ P INT1 13:00 - 16:00 3.001 DRILL I P I I INT1 16:00 - 18:00 I 2.001 DRILL I P I I INT1 18:00 - 20:30 I 2.501 DRILL I P I I INT7 20:30 - 22:30 I 2.001 DRILL I P I I INTi 22:30 - 00:00 I 1.501 DRILL I P I I INT1 11/27/2006 100:00 - 02:00 2.00 DRILL I P I I INT1 02:00 - 02:30 I 0.501 DRILL I P I I INT1 02:30 - 05:00 I 2.501 DRILL I P I I INT1 05:00 - 06:30 1.50 DRILL P INTi 06:30 - 08:00 1.50 DRILL P INT1 08:00 - 08:30 0.50 DRILL P I NT1 08:30 - 09:30 1.00 DRILL P I NT1 09:30 - 10:00 0.50 DRILL P I NT1 10:00 - 10:30 0.50 BOPSU P I NT1 10:30 - 11:00 0.50 BOPSU P I NTi Description of Operations MW = 9.8 ppg in, 9.8 ppg out PUW=280, SOW=215, RTW=230 Monitor well prior to wiper trip, fluid level dropping slightly Attempt wiper trip, POH from 8,385' to 6,990' Hole not taking proper fill, trip back to bottom Circulate bottoms up, 800 GPM C~ 2,780 psi, 80 RPM ~ 11.8 KfUlbs trouble shoot on surface, found gates leaking in pits Gas 2,100 units on bottoms up, shakers clean MW = 9.8 ppg in, 9.8 ppg out Monitor well, Fluid level dropping 6 inches per 15 minutes, approximately 0.5 bbls/hr PUW=280, SOW=215 pumps off Wiper trip, pull upper Ghost Reamer into shoe, from 8,385' to 6,683' Hole slick, no over pulls greater than 10K Loss 2.6 bbls on trip out Loss 5 bbls on trip in PUW=278, SOW=200 pumps off Circulate bottoms up, 800 GPM ®2,900 psi, 80 RPM ~ 11.8 Kft/Ibs Very little cuttings on shakers throughout bottoms up, mostly sand and coal, no splintery shale Gas increased to 2,100 units ~ 9,445 strokes, bottoms up was 10,370 strokes shakers clean but still getting gas and ECD below calculated clean hole, 13,700 strokes gas diminished and CECD=9.93, AECD=9.93 Circulate to 16,000 strokes, no more gas, ECD looks good, shakers clean MW=9.8 ppg in, 9.8 ppg out Monitor well, Fluid level dropping 6 inches per 15 minutes, approximately 0.5 bbls/hr PUW=280K, SOW=200K pumps off POH from 8,385 to 7,818' Hole taking proper fill, 3.48 bbls per 5 stands No over pulls, hole slick POH from 7,818' to 4,508' Hole slick, no over pull Hole taking proper fill Monitor well at shoe Fluid level dropping slightly, -1 bbl/hr POH from 4,508' to 893' Hole taking proper fill Handle BHA, rack back HWDP/Jars Lay down 8" drill collars Pull to bit, milk motor, break off bit Down load MWD data Lay down BHA, MWD, Motor, Stabilizer, and float sub Clean and clear rig floor Remove wear ring and install test plug PJSM for changing out Rams Toolpusher reviewed incidents which happened on all rigs this weekend Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 11 of 18 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: W G I-09i WGI-09i Spud Date: 11/15/2006 DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 NABOBS 27E Rig Number: Date ;From - To Hours Task Code 11/27/2006 111:00 - 14:30 I 3.501 BOPSUR P 14:30 - 15:00 0.50 CASE P 15:00 - 20:00 5.00 CASE P 20:00 - 20:30 0.50 CASE P 20:30 - 21:30 1.00 CASE P 21:30 - 22:00 I 0.50 I CASE I P 22:00 - 00:00 I 2.001 CASE I P 11/28/2006 100:00 - 08:00 I 8.001 CASE I P 08:00 - 10:30 ~ 2.501 CASE P 10:30 - 15:00 4.50 CASE ~ P i NPT Phase ~ Description of Operations INT1 Change Top rams to 9 5/8" rams Rig up test equipment Test upper rams, 250 psi low, 4,000 psi high Test witnessed by Chris Clemens WSTL, Dave Hanson NTP Rig down test equipment, pull test plug INT1 Dummy run with landing joint, 32.2' RKB to hanger INT1 Rig up to run 9 5/8" casing INT1 PJSM on running 9 5/8" casing INT1 Fill hole after opening blind rams Blow down Kill line Pick up first joint of casing and modify rig up INT1 Baker lock first two connections on the first 3 joints 3 centralizers, locked down 10' from shoe on first joint, locked down center of joints 2 and 3. Check diamond for BTC, in compliance Fill pipe with Franks tool Test floats, floats test okay INTi RIH from 121' to 1,414', 35 joints in the hole including shoe track 9 5/8" 47# L-80 casing with TCII connections, no centralizers on joints 4-7 one per joint free floating on joints #8 through #35. Torque turn each connection, Optimum torque=17,500 Wlbs, only had to back out one joint, torqued correctly on the second try PUW=102K, SOW=99K INT1 RIH from 1,414' to 4,638', averaging 30 seconds per joint in casing 114 joints in the hole including shoe track, Fill every joint with Franks tool one centralizer per joint free floating on joints #36 through #91 Total 88 centralizers run including shoe track 1x1 picking up 9 5/8" 47# L-80 casing with TCII connections Torque turn each connection, Optimum torque=17,500 fUlbs, had to back out two joints so far, both torqued correctly on the second try Hole taking proper fill, not pushing away any mud Record pick up and slack off weights every 10 joints in casing PUW=250K, SOW=213K INT1 Circulate bottoms up x 1.5 Stage pumps up Rate Pressure Returns 3.5 BPM 240 psi 23% 4.0 BPM 247 psi 25% 5.0 BPM 303 psi 28% 6.0 BPM 391 psi 32% Install cement hose while circulating INT1 RIH from 4,638' to 5,670', averaging 1.5 to 2 minutes per joint in open hole 140 joints in the hole including shoe track, Fill every joint with Franks tool 1x1 picking up 9 5/8" 47# L-80 casing with TCII connections Torque turn each connection, Optimum torque=17,500 fUlbs Printed: 12/11/2006 2:36:15 PM ~ i BP EXPLORATION Page 12 of ~ 8 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To WGI-09i WGI-09i DRILL+C NABOB NABOB Hours ', OMPLE S ALASK S 27E Task ~ TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 11/15/2006 : 11/13/2006 End: 12/7/2006 Release: 12/7/2006 Number: Description of Operations 11/28/2006 10:30 - 15:00 4.50 CASE P INT1 Hole taking proper fill, not pushing away any mud Record pick up and slack off weights every 5 joints in open hole PUW=310K, SOW=248K Circulate Joint# Rate Pressure Returns 140 5.0 BPM 338 psi 28% 15:00 - 21:00 6.00 CASE P INT1 RIH from 5,670' to 8,347', averaging 3 to 4 minutes per joint From Joint 140 to 150, displacement off by 3.8 bbls, slowed down to 3 minutes per joint, full displacement. From joint 178 to TD displacement off, slowed down to 4 minutes per joint. Calculated displacement for casing run 143 bbls, actual displacement 119 bbls. 206 joints in the hole including shoe track, Fill every joint with Franks tool 1x1 picking up 9 5/8" 47# L-80 casing with TCII connections Torque turn each connection, Optimum torque=17,500 it/Ibs, had to break and re-torque a total of 3 joints for the run, all three shouldered on the second attempt Record pick up and slack off weights every 5 joints in open hole PUW=458K, SOW=312K Circulate Joint# Rate Pressure Returns 170 5.0 BPM 415 psi 29% 185 5.0 BPM 450 psi 31% 195 5.0 BPM 445 psi 31% 23:00 - 23:30 0.50 CASE P INT1 Pick up Casing hanger and landing joint RIH, tag 11' high Break circulation and wash to bottom with Frank's tool 23:30 - 00:00 0.50 CASE P INT1 Circulate bottoms up through franks tool, 4,900 strokes Stage pumps up to 8.0 bbls/min BPM PSI Ret 4.5 448 29 5.0 469 30 6.0 485 33 11/29/2006 00:00 - 01:00 1.00 CASE P INT1 Continue Circulating bottoms up through franks tool, 4,900 strokes Stage pumps up to 8.0 bbls/min BPM PSI Ret 6.0 485 33 7.0 545 36 8.0 670 38 1,350 units of gas on bottoms up, no losses while circulating 01:00 - 02:00 1.00 CASE P INT1 Rig down Franks tool Rig up cement head 02:00 - 03:00 1.00 CASE P INT1 Circulating bottoms up through cement head, 4,900 strokes Stage pumps up to 8.0 bbls/min BPM PSI Ret 6.0 460 32 7.0 600 34 8.0 690- 35 no losses while circulating, PJSM for cement job Printed: 12/11/2006 2:36:15 PM i ~ BP EXPLORATION Page 13 of 18 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To . WGI-09i WGI-09i DRILL+C NABOB NABOB Hours OMPLE S ALASK S 27E Task . TE A DRI Code LING NPT Start I Rig Rig Phase ~ Spud Date: 11/15/2006 : 11/13/2006 End: 12/7/2006 Release: 12/7/2006 Number: Description of Operations 11/29/2006 03:00 - 06:30 3.50 CEMT P INT1 Pressure test cement lines to 4,000 psi Pump 150 bbls of MudPUSH II ~ 10.6 ppg 5 BPM Cut 330 psi Drop bottom plug, positive indication plug left Pump 186 bbls of LiteCRETE Lead @ 12.0 ppg average 5.7 BPM @ 364 psi Pump 76 bbls of Class G tail ~ 15.8 ppg 5.7 BPM ~ 364 psi kick top plug out, positive indication plug left cement head Switch over to rig and displace cement as per Schlumberger pumping schedule. 3,610 strokes first plug landing on float collar 3,960 strokes to catch cement 11 BPM ~ 160 psi, 8.0 BPM after catching cement 6,001 strokes to bump the plug, bumped plug with 1,745 psi Held for 5 minutes, release pressure and floats held Reciprocate pipe throughout cement job Full returns throughout cement job, no losses to well. 06:30 - 09:30 3.00 CEMT P INT1 Rig down cement head, cement hose, blow down cement line, clear rig floor of casing equipment, back out landing joint 09:30 - 10:30 1.00 WHSUR P INT1 Install pack off and test to 5,000psi Pressure test injection line to 3,500 psi Inject 5 bbls down 9 5/8" x 13 3/8" OA to insure annulus is open 1 BPM, formation broke down at 1,100 psi, injection pressure was 1,050 psi 10:30 - 13:30 3.00 BOPSU P INTi Install test plug and change upper rams to 3 1/2" x 6" variable bore rams 13:30 - 15:30 2.00 BOPSU P INT1 BOP test, test upper rams Low test to 250 psi, High test to 4,000 psi Test witnessed by Bill Decker WSTL and Dave Hanson NTP Rig down test equipment, pull test plug Install wear ring 15:30 - 16:30 1.00 BOPSU P INT1 Service top drive, crown, and draw works Derrick inspection, clear rig floor Inject 5 bbls down 9 5/8" x 13 3/8" OA to insure annulus is open 1 BPM ~ 1,050 psi 16:30 - 18:30 2.00 DRILL P PROD1 PJSM for picking up BHA Pick up Bit, Motor, float sub, stabilizer, DGR/PWD, and MWD. 18:30 - 19:00 0.50 DRILL P PROD1 Test and upload to MWD 19:00 - 19:30 0.50 DRILL P PROD1 Pick up 6 3/4" collars Inject 5 bbls down 9 5/8" x 13 3/8" OA to insure annulus is open 1 BPM Cut 1,050 psi 19:30 - 20:30 1.00 DRILL P PRODi RIH from 160' to 886' with 5" HWDP/Jars from the derrick Freeze protect 9 5/8" x 13 3/8" annulus with Little Red Services, Inc. down to 2,200' start 1 BPM ~ 1,250 psi 1.5 BPM 50 bbls 1,100 psi 1.5 BPM 100 bbls 1,250 psi 1.5 BPM 140 bbls 1,350 psi Final OA pressure after freeze protection was 950 psi Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well 'Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ~ WGI-09i WGI-09i DRILL+C NABOBS NABOBS Hours OMPLE ALASK 27E Task TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 11/15/2006 : 11/13/2006 End: 12/7/2006 Release: 12/7/2006 Number: Description of Operations 11/29/2006 20:30 - 21:00 0.50 DRILL P PROD1 Shallow hole test MW D, good test 21:00 - 21:30 0.50 DRILL P PROD1 RIH from 886' to 1,453' picking up 5" drill pipe from the pipe shed (18 joints) 21:30 - 22:30 1.00 DRILL P PROD1 RIH from 1,453' to 2,399' with 5" drill pipe out of derrick 22:30 - 00:00 1.50 DRILL P PROD1 Stripping drill ..,11/30/2006 00:00 - 01:00 1.00 DRILL P PROD1 Rig down stripping drill equipment Blow down all lines 01:00 - 05:00 4.00 DRILL P PROD1 RIH from 2,399' to 8,190' with 5" drill pipe out of derrick Change out two joints due to damaged wear bands ~ Wash down from 8,190' to 8,298' as a precaution, tag float equipment 05:00 - 06:30 1.50 CASE P PROD1 Test 9 5/8" casing to 4,000 psi Chart and record for 30 minutes Test witnessed by Joey LeBlanc W STL and Dave Richards NTP 06:30 - 08:00 1.50 DRILL P PROD1 Drill float equipment and cement from 8,298' to 8,376', stop 5' above shoe 30 RPM ~ 10 kft/Ibs, 500 GPM ~ 1,830 psi, WOB = 10K PUW=272K, SOW=210K, RTW=217K 08:00 - 09:00 1.00 DRILL P PROD1 Circulate bottoms up ~ 400 GPM @ 1,500 psi, 30 RPM ~ 12.0 kft/Ibs ~~ Reciprocating pipe 09:00 - 12:00. 3.00 DRILL P PROD1 Rig Service -Lubricate Rig /Top Drive, Crown, change out ICI swing on cement stand pipe, clean pits, weld door on rig floor i cabinet, weld door in pits 12:00 - 16:30 4.50 DRILL P PROD1 Safety stand down meeting 16:30 - 20:30 4.00 DRILL P PROD1 PJSM, Change out valve in pits Displace to FloPro PUW=257K, SOW=181 K, RTW=212K 480 GPM 1,900 psi, 45 RPM C~ 12.5 KfUlbs ,reciprocating pipe 100 bbs of water 25 bbl Hi Vis spacer, 8.3 ppg 300+Vis 560 bbls FloPro 8.8 ppg After displacement 480 GPM C~ 1,300 psi, 40 RPM ~ 3.5 KWlbs PUW=234K ,SOW=212K , RTW=219K 20:30 - 23:00 2.50 DRILL P PROD1 PJSM, Cut and slip 85' of drilling line 23:00 - 00:00 1.00 DRILL P PROD1 Clean pits and install shaker screens ',12/1/2006 00:00 - 01:00 1.00 DRILL P PROD1 Finish installing shaker screens Adjust brakes on draw works 01:00 - 05:00 4.00 DRILL P PROD1 Safety Stand Down ~ 05:00 - 05:30 0.50 DRILL P PROD1 Drill last 5' of cement, shoe, and 20' of new hole, from 8,376' to i 8,405' 500 GPM @ 1,520 psi, 50 RPMs ~ 3.5 Kft/Ibs WOB = 10K PUW=240K ,SOW=225K , RTW=230K 05:30 - 06:30 1.00 DRILL P PROD1 Circulate bottoms up prior to FIT 500 GPM @ 1,460 psi 06:30 - 07:00 0.50 DRILL P PROD1 Pulled BHA Into Casing, 8,381" -Closed Upper Pipe Rams and Preformed FIT To 10.0 PPG EMW Strokes Pmp'd Pressure 4 130 psi 8 340 psi Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT ( Phase ~ Description of Operations 12/1/2006 06:30 - 07:00 0.50 DRILL P PROD1 12 525 psi 07:00 - 17:00 I 10.001 DRILL I P I I PROD1 17:00 - 18:00 I 1.001 DRILL I P I I PROD1 18:00 - 18:30 I 0.501 DRILL I P I I PROD1 18:30 - 19:30 I 1.001 DRILL I P I I PROD1 19:30 - 20:30 I 1.001 DRILL I P I I PROD1 20:30 - 00:00 3.50 DRILL P PROD1 12/2/2006 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 02:00 1.00 DRILL P PROD1 02:00 - 02:30 0.50 DRILL P PROD1 02:30 - 03:30 1.00 DRILL P PROD1 03:30 - 05:00 1.50 CASE P LNR1 05:00 - 06:00 1.00 CASE P LNR1 06:00 - 06:30 0.50 CASE P LNR1 06:30 - 12:00 5.50 CASE P LNR1 12:00 - 12:30 0.50 CASE P LNR1 12:30 - 13:00 I 0.501 CASE I P I I LNR1 13:00 - 16:00 ~ 3.00 ~ CASE ~ P ~ ~ LNRi Held Test F/ 10 minutes with no Pressure Loss. MW 8.8 PPG, Window TVD 8,072' Pressure 525 psi = 10.05 PPG. EMW. Bled Pressure To 0 Psi. -Opened Pipe Rams. Drill ahead from 8,405' to 8,891', Rotate to TD 600 GPM ~ 1,920 psi off, 2,045 psi on, CECD=8.98, AECD=9.15, MW=8.8 ECD's averaging 0.2 over calculated W0B=15-25K, PUW=240K, SOW=215K, RWT=227K Torque 5.0 KfUlbs off, 6.OKWIbs on ~ 100 RPM back ream full stand at drilling rate going up, 70% coming down Connection gas around 850 to 900 units through out section, Flow check every connection, well static ADT=7.59 hrs, ART=7.59 hrs, AST=0.0 hrs Circulate Weighted Sweep around before short trip 600 GPM fp? 1,920 psi, 25 bbl 10.3 ppg 45 Vis At bottoms up gas was 770 units 3% increase in cuttings when sweep came back MW = 8.8 ppg in, 8.8 ppg out Monitor well, well static Wiper trip to the shoe, hole slick taking proper fill Run back in the hole, hole slick, correct displacement Circulate Hi Vis Sweep around before short trip 600 GPM @ 1,900 psi, 25 bbl 8.8 ppg 170+Vis No gas at bottoms up 50% increase in cuttings when sweep came back MW = 8.8 ppg in, 8.8 ppg out Monitor well, well static Pull to the shoe, drop dart Monitor well, well static Open cir sub, pump dry job Blow down top drive and pull out of hole Pull out of hole to 1,830' Pull out of hole from 1,830' to BHA Lay down BHA, jars, 2 HWDP, and collars Down load data from MW D tools Lay down BHA, TM, DM, GR/PWD, Motor, Stab, Float sub, and bit PJSM -Rig up casing running equipment RIH with 10 joints 7" 26# L-80 BTC-M slotted liner, 4 joints 7" 26# L-80 BTC-M solid liner, and one 16.5' 7" 26# L-80 BTC-M solid pup joint to 575' Pick up 7" x 9 5/8" Baker C-2 ZXP Liner Top Packer/HMC Liner Hanger Run in hole with 5" drill pipe out of derrick from 575' to 8,381' Circulate 1 pipe volume at the shoe before going into open hole 2.3 BPM at 730 psi, PUW=233K, SOW=205K RIH with 5" drill pipe out of derrick from 8,381' to 8,891' Pick up 1' off bottom PUW=245K, SOW=215K Drop 29/32" ball in an attempt to set HMC liner hanger and C-2 ZXP liner top packer Circulate ball down, 4 BPM @ 500 psi Printed: 12/11/2006 2:36:15 PM BP EXPLORATION Operations Summary Report Page 16 of 18 Legal Well Name: WGI-09i Common Well Name: WGI-09i Spud Date: 11/15/2006 Event Name: DRILL+COMPLETE Start: 11/13/2006 End: 12/7/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/7/2006 Rig Name: NABOBS 27E Rig Number: Date I From - To Hours Task i Code NPT Phase , Description of Operations 12/2/2006 13:00 - 16:00 3.00 CASE P LNR1 At 3,100 strokes pressure dropped to 200 psi with same flow rate Check out surface equipment, everything checked out okay Ball must have blown through seat Drop 1 3/4" ball and set hanger at 1,950 psi, and packer at 3,150 psi ', Top of packer set at 8,290' Top of Solid Liner at 8,314' Top of Slotted Liner at 8,491' Shoe at 8,890' Pressured up to 2,000 psi to test packer, test good 16:00 - 20:00 4.00 CASE P LNR1 Displace well to brine 25 bbl 10.0 ppg spacer followed by 8.8 ppg brine 4.2 BPM at 1,950 psi Blow down Top drive, choke, and kill line MW = 8.8 ppg in, 8.8 PP9 out Monitor well, well static Pump dry job and pull out of hole 20:00 - 00:00 4.00 CASE P LNR1 Pull out of hole from 8,381' to 5,555' laying down drill pipe 12/3/2006 00:00 - 02:00 2.00 CASE P LNR1 Pull out of hole from 5,555' to 3,755' laying down drill pipe 02:00 - 02:30 0.50 CASE P LNRi Crew late due to plane situation, Pre tour on rig after crew change out on rig 02:30 - 06:00 3.50 CASE P LNR1 Pull out of hole from 5,555' to 632' laying down drill pipe 06:00 - 07:00 1.00 CASE P LNR1 Pull out of hole laying down 5" HW DP, Lay down running tool making service breaks as per Baker hand '~. 07:00 - 08:30 1.50 EVAL P INT1 PJSM -Rigging up Wireline to run USIT ', 08:30 - 15:30 7.00 EVAL P INT1 Run in hole with USIT and log from 8,275' to Top of Cement at 3,500' Adequate cement for injector well 15:30 - 16:00 0.50 EVAL P INT1 Rig down Schlumberger Wireline 16:00 - 20:30 4.50 BOPSU P RUNCMP Pull wear ring, install test plug Change out upper rams to 7 5/8" rig up test joint test upper rams, low 250 psi, high 4,000 psi Rig down test equipment and pull test plug 20:30 - 22:00 1.50 BUNCO RUNCMP Rig up to run 7 5/8" VAM TOP 29.7# L-80 tubing 22:00 - 23:00 1.00 BUNCO RUNCMP Run in hole with completion assembly Bakerlok Packer assembly to RN nipple/mule shoe assembly Make up R nipple assembly to packer assembly, first attempt did not shoulder correctly, break joint, second attempt did not shoulder correctly, back joint out, clean off threads, attempt a third try, shouldered okay but pup on top of packer was crushed. 23:00 - 00:00 1.00 BUNCO SFAL RUNCMP Broke connection again and pin of pup on "R" nipple assembly was galled. Lay down "R" nipple assembly, S-3 Packer j assembly, and RN nipple/mule shoe assembly, send to Baker for repairs and Schlumberger for pressure testing. 12/4/2006 00:00 - 06:30 6.50 BUNCO SFAL RUNCMP Waiting on Baker to repair completion equipment and Schlumberger to pressure test it. Work on Mule and lights in derrick 06:30 - 07:30 1.00 BUNCO RUNCMP PJSM on running 7 x 7 5/8 completion tubing BOT and Vam reps. In Attendance at meeting M/U, Mule shoe / 7" "RN" nipple to 7 x 9 5/8" Baker S-3 Printed: 12/11/2006 2:36:15 PM • BP EXPLORATION Page 17 of 18 ~ Operations Summary Report Legal Well Name: WGI-09i Common Well Name: WGI-09i Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Start: 11 /13/2006 Rig Release: 12/7/2006 Rig Number: Spud Date: 11 /15/2006 End: 12/7/2006 Date ;From - To Hours Task Code + NPT 12/4/2006 106:30 - 07:30 I 1.00 07:30 - 18:00 I 10.50 18:00 - 18:30 I 0.50 18:30 - 22:00 I 3.50 22:00 - 23:30 I 1.50 23:30 - 00:00 I 0.50 12/5/2006 ~ 00:00 - 01:30 1.50 01:30 - 02:00 0.50 RNTBH~ P 02:00 - 04:00 2.00 CHEM P 04:00 - 05:00 I 1.001 RU 05:00 - 06:30 I 1.50 06:30 - 07:00 0.50 BUNCO 07:00 - 09:00 2.00 BOPSU P Phase Description of Operations RUNCMP Packer, did not shoulder correctly the on the first attempt but did shoulder up on the second attempt, using double stack tongs. 7" "R" nipple made up no problem on the first attempt RUNCMP RIH with 143 joints of 7 5/8" 29.7# L-80 VAM Top tubing, Torque turn each connection Avg 12 joints per hour for the first 85, 15 joints per hour from 86-143 joints correct displacement RUNCMP Pick up DB-6 Nipple assembly, place between joints 143 and 144, top of nipple ~ 2,215' RUNCMP RIH with 53 joints of 7 5/8" 29.7# L-80 VAM Top tubing, Torque turn each connection, Total 196 joints in the hole Avg 15 joints per hour, correct displacement PUW=270K, SOW=239K Pick up joint 197, RIH tag up at 11' in on joint 197, end of stinger at 8,301' Pick up, rotate 180 deg. and tag top of packer at 0' in on joint 197, end of stinger at 8,290' confirmed we were stung in on first attempt RUNCMP Space Out Tubing Lay down joint 197, 196, and 195 Pick up 9.8' Pup and 2.14' Pup, this will space out stinger to 8,296', mule shoe will be 6' into tie back receptacle Make up joint 195, crossover pup from VAM Top to TCII, and FMC tubing hanger, rotate string 180 degrees PUW = 272k / 239k SOW RUNCMP Pick up -anding joint Run in hole 21' on landing joint RUNCMP Circulate bottoms up 3 BPM @ 200 PSI 272k PUW / 237k TUBHGR Land tubing hanger and run in lock downs as per FMC Back out landing joint and put in mouse hole CLEAN PJSM for circulation Reverse circulate 120 bbls corrosion inhibited brine with rig, 3 BPM ~ 500 psi Pressure test Little Red Hot Oil Service lines to 4300 psi Little Red Hot Oil Services pumped 36 bbls of diesel to freeze protect IA, 3 BPM ~ 500 psi RUNCMP Run in hole with landing joint Drop the ball and rod assembly, lay down landing joint Close blind rams and Pressure up to 4,000 psi to set the packer RUNCMP Hold 4,000 psi and record on chart for 30 minutes Bleed tubing pressure to zero Pressure tubing up to 2,000 psi, Little Red pressured up IA to 4,000 psi Record on chart for 30 minutes Bleed IA to 0 psi, bleed tubing to 0 psi RUNCMP Set two way check valve, test from above to 1,000 psi PJSM for Nipple down BOPS RUNCMP Drain Stack and Blow down all mud lines, choke lines & killl Printed: 12/11/2006 2:36:15 PM • • BP EXPLORATION Page 18of ~s Operations Summary Report Legal Well Name: WGI-09i Common Well Name: WGI-09i Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date From - To Hours Task Code ~ NPT Start: 11 /13/2006 Rig Release: 12/7/2006 Rig Number: Spud Date: 11/15/2006 End: 12/7/2006 Phase Description of Operations 12/5/2006 07:00 - 09:00 2.00 BOPSU~ P RUNCMP line. 09:00 - 15:30 6.50 BOPSU P RUNCMP PJSM, Remove Drilling nipple, choke & kill line, turnbuckles, 15:30 - 19:00 I 3.501 WHSUR I P 20:00 - 23:00 3.00 RU CONS' 23:00 - 00:00 I 1.00 12/6/2006 010:30 - 03:00 1.50 RUNCOI~P 03:00 - 06:00 3.00 WHSUR P 06:00 - 00:00 18.00 WHSUR P 12/7/2006 100:00 - 00:00 I 24.00 i RIGD I P drip pan cover and drains, remove stack and set on carrier. WHDTRE Nipple up Tree and test to 5000 psi for 15 mins. Tree passed pressure test. WHDTRE Rig up DSM lubricator and pull TWC RUNCMP Rig SWS slick line lubricator and test to 1000 psi f/ 10 min, good test R/U slick line RUNCMP RIH and retrieve ball and rod Tag up C~ to 8275' WHDTRE R/D SWS lubricator and Slick line unit RUNCMP R/U Little Red and test lines to 4000 psi, Bullhead 100 bbl of freeze protect, Break down C~ 1650 psi / ICP ~ 3 bpm =1000 psi / FCP ~ 3 bpm =1600 R/D Little Red Services WHDTRE Rig up DSM lubricator and set BPV. d Secure Well and tree. WHDTRE Finish cleaning pits, - Prep Rig for move - Remove BP equipment; ie cutting tanks, subs. wellhead equip RUNCMP Prep Rig for rig Move Demobilize BP equipment & tools Rig released ~ 24:00 hrs Printed: 72/11/2006 2:36:15 PM • Halliburton Company Survey Report Company: BP AI710C0 llatc: 1"'2001 fimc: 15:21 :36 Pa~;c: 1 Field: Prudhoe Bay (various) Col~rdinatci~Gl Ref erunce_ W ell: WGI-09, True North tine: WGI ~ ertical f'f~Di Refer ence: W GI 09: 50.6 I «"dl: WGI-09 Sc~elion (VS) Referen ce: W ell (D.OON,O.OOE,331.84Az1) I Wellpath: WGI-09 --- _ = Survey Calculatimi ti leth«i: Mi --- nimum Curvature - llb: Oracle -- - J Field: Prudhoe Bay (various) Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: WGI-09 Slot Name: Well Position: +N!-S 1018.72 ft Northing: 5972032.22 ft Latitude: 70 19 42.924 N +E/-W -594.95 ft Easting : 684979.14 ft Longitude: 148 29 58.768 W Position Uncertainty: 0.00 ft Wellpath: WGI-09 Drilled From: Well Ref. Point 500292332700 Tie-on Depth: 32.90 ft Current Datum: WGI-09: Height 50.59 ft Above System Datum: Mean Sea Level Magnetic Data: 11/14!2006 Declination: 24.27 deg Field Strength: 57663 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.90 0.00 0.00 331.84 Survey Program for Definitive Wellpath Date: 9/29/2006 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 100.00 1278.00 WGI-09 GYRO (100.00-1278.00) CB-GYRO-SS Camera based gyro single shots 1306.70 8837.66 WGI-09 IIFR+MS+Sag ( 1306.70-88 MWD+IFR+MS MWD +IFR + Multi Station Survey MD lncl Azim TVD tiffs 1'VI) N/S E/W Mapti 1~apE I'r~l ft deg deg ft ft ft ft ft ft 32.90 0.00 0.00 - 32.90 - -17.69 - - 0.00 0.00 5972032.22 684979.14 TIE LINE 100.00 0.14 122.12 100.00 49.41 -0.04 0.07 5972032.18 684979.21 CB-GYRO-SS 200.00 0.44 176.75 200.00 149.41 -0.49 0.19 5972031.73 684979.35 CB-GYRO-SS 300.00 0.10 110.01 300.00 249.41 -0.91 0.30 5972031.32 684979.46 CB-GYRO-SS 400.00 0.33 122.24 400.00 349.41 -1.09 0.62 5972031.15 684979.79 CB-GYRO-SS 500.00 0.24 52.85 500.00 449.41 -1.12 1.03 5972031.13 684980.20 CB-GYRO-SS 600.00 0.32 70.02 599.99 549.40 -0.89 1.46 5972031.36 684980.63 CB-GYRO-SS 700.00 0.35 66.18 699.99 649.40 -0.68 2.01 5972031.59 684981.16 CB-GYRO-SS 750.00 0.32 64.65 749.99 699.40 -0.55 2.27 5972031.72 684981.42 CB-GYRO-SS 805.00 0.50 81.60 804.99 754.40 -0.45 2.65 5972031.83 684981.80 CB-GYRO-SS 850.00 0.19 48.32 849.99 799.40 -0.37 2.90 5972031.92 684982.05 CB-GYRO-SS 900.00 0.29 119.16 899.99 849.40 -0.38 3.07 5972031.91 684982.22 CB-GYRO-SS 994.00 0.53 354.02 993.99 943.40 -0.06 3.23 5972032.24 684982.37 CB-GYRO-SS 1090.00 2.64 337.07 1089.95 1039.36 2.41 2.32 5972034.69 684981.40 CB-GYRO-SS 1184.00 3.87 336.47 1183.79 1133.20 7.32 0.22 5972039.54 684979.17 CB-GYRO-SS 1278.00 4.08 337.39 1277.57 1226.98 13.31 -2.34 5972045.47 684976.48 CB-GYRO-SS 1306.70 3.84 334.52 1306.20 1255.61 15.12 -3.14 5972047.26 684975.63 MWD+IFR+MS 1401.96 2.97 324.74 1401.29 1350.70 20.02 -5.94 5972052.08 684972.71 MWD+IFR+MS 1496.74 1.16 315.81 1496.00 1445.41 22.71 -8.03 5972054.72 684970.56 MWD+IFR+MS 1590.23 0.90 311.91 1589.48 1538.89 23.88 -9.23 5972055.86 684969.32 MWD+IFR+MS 1684.56 1.11 294.47 1683.80 1633.21 24.75 -10.62 5972056.70 684967.92 MWD+IFR+MS 1777.87 1.06 306.67 1777.09 1726.50 25.64 -12.13 5972057.55 684966.38 MWD+IFR+MS 1872.83 1.34 311.55 1872.03 1821.44 26.90 -13.67 5972058.78 684964.82 MWD+IFR+MS 1966.81 1.25 307.79 1965.98 1915.39 28.26 -15.30 5972060.09 684963.15 MWD+IFR+MS 2062.38 2.40 322.70 2061.50 2010.91 30.49 -17.33 5972062.27 684961.06 MWD+IFR+MS 2156.95 4.01 332.99 2155.92 2105.33 35.01 -20.04 5972066.72 684958.25 MWD+IFR+MS 2252.04 4.90 341.99 2250.73 2200.14 41.84 -22.80 5972073.48 684955.31 MWD+IFR+MS 2346.04 6.56 340.58 2344.25 2293.66 50.72 -25.83 5972082.28 684952.07 MWD+IFR+MS 2440.34 9.18 333.46 2437.66 2387.07 62.53 -30.98 5972093.96 684946.63 MWD+IFR+MS • Halliburton Company Survey Report Company: BP AmOCO Fic1d: Prudhoe Say (various) Sitr. WGI 1i'cll: WGI-09 1idlpath: WGI-09 llate: 1;3.'2007 fimc 15:21 :36 Page: .'. Cu-urdinate~~Ei Rcferona•: Well: WGI-09 True North Verticaiff~"lliReferencc WGI-09:50.6 Section 1~"S) Reference: Well (O.OON.O.OOE.331 .84Azi) Sarver Calcnlatiou Method: Minimum Curvature llb: Oracle Survey MD Incl Azim TVD Sys~fVD N/S I~J~V ~tapN MapE; Tool ft deg deg ft ft ft ft ft ft 2535.63 11.31 328.57 2531.43 2480.84 77.31 -39.25 5972108.53 684938.00 MWD+IFR+MS 2630.42 12.32 327.22 2624.21 2573.62 93.74 -49.57 5972124.70 684927.27 MWD+IFR+MS 2724.30 13.15 328.72 2715.78 2665.19 111.29 -60.54 5972141.97 684915.88 MWD+IFR+MS 2819.42 14.72 328.91 2808.10 2757.51 130.88 -72.40 5972161.27 684903.54 MWD+IFR+MS 2915.16 17.18 332.47 2900.14 2849.55 153.84 -85.22 5972183.91 684890.16 MWD+IFR+MS 3010.27 19.50 336.18 2990.42 2939.83 180.83 -98.13 5972210.56 684876.59 MWD+IFR+MS 3102.59 19.61 337.27 3077.42 3026.83 209.21 -110.33 5972238.63 684863.69 MWD+IFR+MS 3198.60 20.08 333.61 3167.73 3117.14 238.84 -123.89 5972267.91 684849.41 MWD+IFR+MS 3294.04 21.67 329.15 3256.91 3206.32 268.64 -140.21 5972297.31 684832.36 MWD+IFR+MS 3388.72 21.37 328.62 3344.99 3294.40 298.38 -158.15 5972326.59 684813.69 MWD+IFR+MS 3482.96 21.04 328.74 3432.84 3382.25 327.50 -175.87 5972355.26 684795.26 MWD+IFR+MS 3578.15 20.39 332.38 3521.88 3471.29 356.80 -192.43 5972384.15 684777.99 MWD+IFR+MS 3671.74 19.18 333.77 3609.95 3559.36 385.04 -206.78 5972412.02 684762.94 MWD+IFR+MS 3768.06 19.94 334.11 3700.71 3650.12 414.01 -220.95 5972440.63 684748.07 MWD+IFR+MS 3862.50 20.80 333.31 3789.24 3738.65 443.48 -235.51 5972469.73 684732.78 MWD+IFR+MS 3955.92 20.30 334.20 3876.72 3826.13 472.89 -250.01 5972498.77 684717.56 MWD+IFR+MS 4049.87 19.42 334.50 3965.08 3914.49 501.66 -263.83 5972527.19 684703.04 MWD+IFR+MS 4145.30 18.80 333.54 4055.25 4004.66 529.74 -277.51 5972554.93 684688.67 MWD+IFR+MS 4241.00 19.27 333.70 4145.72 4095.13 557.71 -291.38 5972582.54 684674.12 MWD+IFR+MS 4335.01 20.30 332.29 4234.18 4183.59 586.05 -305.84 5972610.52 684658.97 MWD+IFR+MS 4430.47 20.92 329.75 4323.53 4272.94 615.43 -322.12 5972639.49 684641.96 MWD+IFR+MS 4526.33 20.32 329.63 4413.25 4362.66 644.58 -339.16 5972668.20 684624.21 MWD+IFR+MS 4580.74 19.67 330.23 .4464.38 4413.79 660.68 -348.48 5972684.06 684614.49 MWD+IFR+MS 4632.23 19.32 330.66 4512.92 4462.33 675.62 -356.96 5972698.80 684605.65 MWD+IFR+MS 4727.07 20.74 331.42 4602.02 4551.43 704.05 -372.68 5972726.82 684589.24 MWD+IFR+MS 4821.42 22.07 332.92 4689.86 4639.27 734.50 -388.74 5972756.87 684572.43 MWD+IFR+MS 4916.16 22.98 333.51 4777.37 4726.78 766.90 -405.10 5972788.86 684555.28 MWD+IFR+MS 5009.24 23.14 332.83 4863.01 4812.42 799.44 -421.55 5972820.97 684538.03 MWD+IFR+MS 5104.78 23.33 331.19 4950.80 4900.21 832.72 -439.24 5972853.80 6845f9.53 MWD+IFR+MS 5199.76 21.18 329.21 5038.70 4988.11 863.94 -457.09 5972884.57 684500.92 MWD+IFR+MS 5293.34 21.08 328.90 5125.99 5075.40 892.87 -474.44 5972913.07 684482.86 MWD+IFR+MS 5386.99 19.71 328.65 5213.77 5163.18 920.78 -491.35 5972940.55 684465.27 MWD+IFR+MS 5480.60 18.76 328.90 5302.15 5251.56 947.15 -507.34 5972966.52 684448.63 MWD+IFR+MS 5575.43 19.07 328.88 5391.86 5341.27 973.47 -523.22 5972992.43 684432.11 MWD+IFR+MS 5670.19 19.46 329.65 5481.32 5430.73 1000.34 -539.20 5973018.90 684415.47 MWD+IFR+MS 5765.29 19.30 330.65 5571.03 5520.44 1027.71 -554.91 5973045.88 684399.10 MWD+IFR+MS 5860.16 18.98 331.29 5660.65 5610.06 1054.91 -570.00 5973072.69 684383.34 MWD+IFR+MS 5955.45 19.90 331.22 5750.51 5699.92 1082.71 -585.25 5973100.11 684367.41 MWD+IFR+MS 6050.32 20.80 331.86 5839.46 5788.87 1111.72 -600.97 5973128.72 684350.98 MWD+IFR+MS 6143.83 21.67 332.83 5926.62 5876.03 1141.72 -616.69 5973158.32 684334.53 MWD+IFR+MS 6239.50 22.51 333.22 6015.26 5964.67 1173.79 -633.00 5973189.97 684317.43 MWD+IFR+MS 6334.07 21.49 332.61 6102.95 6052.36 1205.33 -649.13 5973221.10 684300.53 MWD+IFR+MS 6429.22 21.66 332.58 6191.43 6140.84 1236.39 -665.23 5973251.76 684283.67 MWD+IFR+MS 6522.97 22.44 332.43 6278.32 6227.73 1267.61 -681.48 5973282.56 684266.65 MWD+IFR+MS 6618.34 23.36 333.05 6366.18 6315.59 1300.60 -698.48 5973315.12 684248.85 MWD+IFR+MS 6708.02 21.91 332.61 6448.95 6398.36 1331.31 -714.23 5973345.43 684232.34 MWD+IFR+MS 6806.75 21.90 332.64 6540.55 6489.96 1364.01 -731.17 5973377.71 684214.61 MWD+IFR+MS 6902.29 20.00 331.66 6629.77 6579.18 1394.22 -747.12 5973407.51 684197.92 MWD+-FR+MS 6997.87 18.41 331.89 6720.03 6669.44 1421.92 -761.99 5973434.84 684182.37 MWD+IFR+MS 7092.49 18.98 332.09 6809.65 6759.06 1448.70 -776.23 5973461.25 684167.48 MWD+IFR+MS 7187.17 19.82 332.52 6898.96 6848.37 1476.54 -790.84 5973488.73 684152.18 MWD+IFR+MS 7281.76 18.04 333.83 6988.43 6937.84 1503.92 -804.70 5973515.75 684137.65 MWD+IFR+MS • Halliburton Company Survey Report Compun~: BP Amoco I~icld: Prudhoe Bay (vBtivUa') Site: WGI 1i'ctl: WGI-09 ~1'eupath: WGI-09 Survey bate: 1/3/2007 Time: 15:21:36 Page: 3 Co-ordinatc(NEI Reference: Well: WGI-09, True NOrih Fertical CI'~'Dl Reference WGI-09: 50.6 Section f~~S) KeCrrence: Well (O.OON,O.OOE,331.84Azi) Sarver ('alculation Slcthod: Minimum Curvature Db: OraCle ~1D incl Azim 'C~ll ft deg deg ft 7375.59 15.30 332.95 7078.31 7470.98 13.50 330.44 7170.70 7565.12 13.71 331.45 72~i2.19 7659.13 12.38 332.95 7353.78 7753.86 9.54 332.58 7446.77 7848.49 7.77 329.67 7540.32 7943.88 5.68 331.30 7635.05 8038.72 3.22 341.08 7729.60 8134.49 0.86 335.15 7825.30 8229.12 0.32 191.89 7919.92 8320.98 0.31 183.13 8011.78 8407.59 0.09 184.14 8098.39 8502.13 0.18 216.65 8192.93 8597.73 0.14 17921 8288.53 8692.63 0.14 265.00 8383.43 8788.07 026 289.74 8478.87 8837.66 0.31 305.02 8528.46 8891.00 0.31 305.02 8581.80 S~s'I'VA l~~/11' - llapN MapF. -- - -Tool fl ft ft ft 7027.72 -816.74 5973539.51 684125.02 MWD+IFR+MS 7120.11 -827.96 5973560.13 684113.29 MWD+IFR+MS 7211.60 -838.71 5973579.21 684102.07 MWD+IFR+MS 7303.19 -848.62 5973597.72 684091.70 MWD+IFR+MS 7396.18 -856.86 5973613.53 684083.07 MWD+IFR+MS 7489.73 -863.70 5973625.84 684075.93 MWD+IFR+MS 7584.46 -869.22 5973635.41 684070.17 MWD+IFR+MS 7679.01 -872.34 5973641.96 684066.89 MWD+IFR+MS 7774.71 -873.52 5973645.13 684065.63 MWD+IFR+MS 7869.33 -873.87 5973645.51 68406527 MWD+IFR+MS 7961.19 -873.93 5973645.01 68406522 MWD+IFR+MS 8047.80 -873.95 5973644.70 68406521 MWD+IFR+MS 8142.34 -874.05 5973644.51 684065.12 MWD+IFR+MS 8237.94 -874.13 597364427 684065.03 MWD+IFR+MS 8332.84 -87425 5973644.14 684064.92 MWD+IFR+MS 842828 -874.57 597364420 684064.60 MWD+IFR+MS 8477.87 -874.78 5973644.31 684064.38 MWD+IFR+MS 853121 -875.02 5973644.47 684064.14 PROJECTED to TD N/S ft 1527.99 1548.88 1568.24 1587.00 1603.02 1615.50 1625.21 1631.85 1635.04 1635.43 1634.93 1634.63 1634.44 163420 1634.07 1634.14 163425 1634.42 1 I _ ~~ WELLHEAD= ?? ACTUATOR = ?? KB. ELEV = BF. ELEV = ?? ?? KOP = ?? -Max Angle = 23 @ 5809' Datum MD - 916q' Datum TV D = 880q' SS P ~ ~.x QRAFT I7-5/8" TBG, 29.7#, L-80 IPC VAMTOP, I 2204' 0.459 bpf, ID = 6.875" 7" TBG, 26#, L-80, TC11, .0383bpf, ID = 6.276" 2226' 13-3/8" CSG, 68#, L-80, BTC, ID = 12.415" 4638' Minimum ID = 5.963" @ 8230' 7" RN NIPPLE 7-5/8" TBG, 29.7#, L-80 IPC VAM TOP, $~ $$' 0.459 bpf, ID = 6.875" 2204' -~ 7-5l8" X 7" XO, ID = 6.276 2215' 7" CAMCO OB-6 NIP, ID = 6.00" 2226' 7" X 7-5/8" XO, ID = 6.276 8138' (~ 7-5/8" X 7" XO, ID = 6.250" 7" HES "R" NIP, ID = 5.963" 9-5/8" CSG, 47#, L-80 TCII XO TO L-80 BTC ~-~ $260' ~ 7" TBG, 26#, L-80, TC11, .0383 bpf, ID = 6.276" ~--~ $297' 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" 7" SOLID LNR, 26#, L-80, BTC, .0383 bpf, ID = 6.276 8492' I PBTD 8890° ~ 7" SLOTTED LNR, 26#, L-80, BTC, .0383 bpf, ID = 6.276 $$92` 825- 9-5i8" X 7" BKR S-3 PKR, ID = 6.00" I 8275' 7" HES "RN" NIP, ID = 5.770" $290' 9-5/8" X 7" G2 ZXP LTP w /HMC HGR ID = 6.270" $2~ 7" MULE SHOE, ID = 6.276 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/08!06 N27E ORIGINAL COMPLETION 12!13106 ?1PJC DRLG DRALT CORRECTIONS PRUDHOE BAY UNtT WELL: WGI-09 PERMff No: °"2061460 APt No: 50-029-23327-00 SEC 11, T11N, R14E, 5051' FSL, 1215' FEL BP Exploration (Alaska) SAF~IOTES: WG I-09 • • 05-Jan-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well WGI-09 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,891.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~ ~~„~, ~Arp'7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 01/22/2007 Schlumb~erger Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth vac ~~~ _1~1~ Wnll - _Inh ~! 1 nn 1]ascrinfinn NO. 4112 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay rla4a RI Cnlnr Cn MPS-10A 11076475 CH EDIT SCMT (PDC-GR) 10/17/05 1 15-08CL1 10942196 CH EDIT JEWELRY (PDC-GR) 03/01/05 1 Z-12 11513657 RST 12/06106 1 1 L3-11 11533392 RST 12/31106 1 1 AGI-10A 11485869 USIT 11/09/06 1 GNI-02A 11485873 USIT 11!15/06 1 GNI-02A 11485874 MDT 12/03/06 1 12-18 NIA USIT 11/17106 1 NGI-07A 11212892 USIT 10113/06 1 DS 12-14AL1 11540230 CORROSION & CBL 12/18/06 1 01-23 11549351 USIT 12/16106 1 WGI-09 11486172 USIT 12/03106 1 YLtASt AGKNUWLEUGt Ktl;t1Y 1 t3Y SIGNING ANU KtTURNING UNt GUPY EACH TU: BP Exploration (Alaska} Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & ~orislllGng ~t}rvices 2525 Gambell SfYeef; Fite 400 I _ Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: r_ • • Re: WGI-09 flow line fluid flow sensor dispeon ~~ ,,,,. ~ ~~ Subject: Re: WGI-09 flow line fluid flow censor dispensation From: Winton Aubert <wnton_aubert@admin.state.ak.us> Date: Thu, 16 Nov 2006 10:37:34 -0900 To: "Phillips, Ron" <Ron.Phillips@bp.com> CC: Admn AOGCC Prudhoe Bay <aogcc_prudhoe_bay@admin.state.ak.us> Ron, Pursuant to 20 AAC 25.033 Q), AOGCC hereby approves the alternate drilling fluid system on well WGI-09 (PTD 206-146), as described below. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Phillips, Ron wrote: Winton, Section 20 AAC 25.033 (c) (3) states: " A drilling fluid system intended to maintain the well bore in overbalanced condition must include a drilling fluid flow sensor with a readout convenient to the driller's station to enable the operator to determine whether drilling fluid returns equal drilling fluid pump discharge rates." ', Last night Nabors 27E on WGI-09i had their flow line plug off with sticks and gravel. I talked with Chuck Scheve up on the slope and got verbal approval to pull the paddle from the flow line and write a dispensation ', in the morning. BP requests a dispensation to Section 20 AAC 25.033 (c) (3), while drilling the gravels in the permafrost of WGI-09's surface hole. No hydrates should be present in this hole section. Besides the drilling fluid pit level indicator with both visual and audible warning devices, another person will man the pits to ensure the correct fluid level is maintained. Thanks, Ron Phillips Operations Drilling Engineer GPB Rotary Office (907) 564-5913 Cell (907) 748-7868 1 of 1 11/16/2006 10:38 AM • ALASSA OIL AI1TD GA5 CO1~T5ERQATI011T COMl~IISSIOrT Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-09 BP Exploration (Alaska) Inc. Permit No: 206-146 Surface Location: 5051' FSL, 1215' FEL, SEC. 1 1, Tl 1N, R14E, UM Bottomhole Location: 1407' FSL, 2086' FEL, SEC. 02, T11N, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster Commissioner DATED this day of October, 2006 cc: Department of Fish 8:; Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~E~~ @ll, (~B~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 OCT 1 0 2006 Alaska Oil & Gas Cons. Cofnmission 1 a. Type of work 1 b. Current Well Class ^ Exploratory ^ Development Gas 1 c. Specify if well is 9or: ® Drill ^ Redrill ®Service / ^ Multiple Zone ^Coalbed Methane ^ Gas Hydrates ^ Re-Entry ^ Stratigraphic Test ^ Development Oil ^ Single Zone ^ Shale Gas 2. Operator Name: 5. Bond: ®Blanket ^ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU WGI-09 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8901 TVD 8586 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: R14E 5051' FSL 121 ' FE 1 1 UM ~ S C ADL 028302 , , 5 L, E . 1, T 1 N, Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1407' FSL, 2086' FEL, SEC. 02, T11 N, R14E, UM November 1, 2006 ~ Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1407' FSL, 2086' FEL, SEC. 02, T11 N, R14E, UM ~ 2560 16,765' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool: Surface: x-684979 y-5972032 Zone-ASP4 (Height above GL): 51.1 feet 680' 16. Deviated Wells: Kickoff Depth: 1950 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole An le: 20 de rees Downhole: 3523 Surface: 2717 ~ 18 Casin `Pro ram: 5 ifications To - Settin De th -Bo ttom uar~ti of Cement a.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A5 Weld 80' 33' 33' 113' 113' 260 sx Arctic Set A rox. 16" 13-3/8" 68# L-80 BTC 4629' 33' 33' 4662' 4531' 867 sx Class AS Lite 567 sx Class 'G' 12-1/4" -5/8" 47# L-80 TC-II 8348' 33' 33' 83 1' 60' 469 sx LiteCrete 408 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 470' X431'' 8116' 8901' 8586' Uncemented Slotted Liner Z~I' W 19. PRESE NT WELLCONDITION SUMMARY (To be completed for Redrill'and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing: Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 Ron Phillips, 564-5943" Printed Name Gre bb Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4191 Date Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill API Number: } ~ ~ 3 50 d 2 9 ~ Permit Approval See cover letter for Number: -' .7 , - . Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ~ S~- ~ ~ ~ ~ ~~ 4. d p O ~ ~ i Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~ No ^ ' No d:~Yes A~Z ~ t (~ vtti ~,~ qr~a. (,t,• ~ ~~ q r~j~C-~ ct HZS Measures: Yes ^ No Directional Survey Req Other: (/ { ® L '~NivS`t,twc.~ ~"D ZDi9~L 2`J . o~ s ~k ~!!1~ ~ a ~ C~'/~~e ~Ol~rf` ~°5~ /J1~+ ~ / 5 ~/~Yd ~/~od . / PROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 GRlGlN~L Submit In Duplicate • ~ Well Name: WGI-09i Planned Well Summary Well WGI-09i Well Slant Gas l Target Ivishak T e Injector Ob'ective Zone 1 B AFE Number API Number: Current Status New well, insulated conductor 20",x 34", 215.5 ppf, A53 ERW set C~ 113.5 RKB Estimated Start Date: 01-Nov-2006 Time to Com lete: 21.3 Da s Surface Northin Eastin Offsets TRS Location 5,972,032 684,979 5,051' FSL / 1215' FEL 11 N, 14E, 11 Target Northin Eastin TVDss Offsets TRS Location 5,973,646 684,067 -8,000 1407' FSL / 2086' FEL 11 N, 14E, 2 Bottom Northin Eastin TVDss Offsets TRS Location 5,973,646 684,067 -8,535 1407' FSL / 2086' FEL 11 N, 14E, 2 Planned TD: 8,901' MD / 8,586' TVD Ri Nabors 27E ~ CBE: 17.6' Directional -Sperry wp-03 RTE: 51.1' Maximum Hole An le: ~20° in the 16" surface hole and 12'/a" intermediate section Close Approach Wells: All wells should pass major risk close approach criteria after re gyroing WGI- 01.The closest well is WGI-01 at 30.91' ctr-ctr (-22.21' allowable deviation) at 2,002' tanned MD. Surve Pro ram: MW D Standard + IFR /Cassandra / MS Nearest Pro a Line: 16,765' to the PBU property line Nearest Well within Pool: Li-15A is 680' away from planned well WGI-09 at BHL. WGI-09i Permit to Drill Application Page • • Formation Markers WGI-OlA (Based on SOR) Formation Estimated Formation Tops TVDss (RKB-51.1 ') (TVDrkb) (MDrkb) Estimated Pore Press. ( EMW / Psi) G1 532 583 583 SV6 1600 1651 1651 BPRF 1861 1912 1912 EOCU 2340 2391 2392 SV5 3095 3146 3184 SV4 3275 3326 3376 SV3 3820 3871 3957 SV2 3970 4021 4117 SV1 4400 4451 4576 UG4 4780 4831 4981 UG3 5040 5091 5259 UG1 5500 5551 5750 WS2 6105 6156 6395 WS1 6300 6351 6603 CM3 6555 6606 6875 CM2 6950 7001 7297 CM1 7420 7471 7785 THRZ 7765 7816 8131 BHRZITop Putriver 7990 8041 8356 LCUlTJA 8000 8051 8366 TSGR 8015 8066 8381 TSHA 8055 8106 8421 TSHB 8065 8116 8431 TSHC 8075 8126 8441 TSAD 8080 8131 8446 7.2 42SB 8125 8176 8491 7.2 TCG L 8200 8251 8566 7.2 BCGL 8265 8316 8631 7.2 23SB 8320 8371 8686 7.2 22TS 8370 8421 8736 7.2 21 TS 8395 8446 8761 7.2 TZ1 B 8440 8491 8806 7.2 TDF 8480 8531 8846 7.2 BSAD 8530 8581 8896 TD Criteria: Approx. 5 ft TVD below BSAD or sufficient rat hole required to complete lowest Z1 B sand. Final TD will be determined by both the town & wellsite geo. Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg ~ / (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 42" 20" 215.5# A53 Weld 80' 33' / 33' 113' / 113' 16" 13 3/8" 68# L-80 BTC 5,020 2,260 4,629' 33' / 33' 4,662' / 4,531' 12-1/a" 9 5/8" 47# L-80 TC-II 6,870 4,760 8,348' 33' / 33' 8,381' / 8,060' 8-lh" 7" 26# L-80 BTC-M Slotted Slotted 470' 8,431' / 8,901' / 8,116' 8,586' WGI-09i Permit to Drill Application Page 2 • • Tubing 7" 26# L-80 BTC-M 7,240 5,410 200' 8,231' / 8,431' / 7,916' 8,116' Tubing 7" 26# L-80 Vam 7,240 5,410 115' 8,116' / 8,231' / To HC 7,801' 7,916' Tubing 7-5/8" 29.7# L-80 Vam 6,890 4,970 8,083' 33' / 33' 8,116' / To HC 7,801' Mud Program Hole Section / o eration: Drillin 16" interval, surface to Base of Permafrost T e Densit Viscosit PV YP Chlorides API FL H Spud- Freshwater mud 88.92 250-300+ 30-55 50-70 <1000 NC-8.0 9.0-9.5 Hole Section / o eration: Drillin 16" interval, Base of Permafrost to 4,662' (TD) T e Densit Viscosit PV YP Chlorides API FL H Spud- Freshwater mud g 2 9 5~ 225 - 250 30 - 55 45 - 60 <1000 8.0 9.0 - 9.5 ~... Hole Section / o eration: Drillin 12-'/a" interval, surface shoe- 7,931' (Top HRZ) T e Densit Viscosit PV YP Chlorides API FL H LSND 9.1 -9.3 45-60 15-22 25-30 <600 6.0-8.0 9.0-9.5 Hole Section / o eration: Drillin 12-'/a" interval, 7,931' (HRZ)- 8,381' (Int TD) T e Den Viscosit PV YP Chlorides API FL H LSND 9.6 45-60 18-25 25-35 <600 <5.5 9.0-9.5 e~:.~ Hole Section / o eration: Drillin 8-'/z" production interval to 8,901' (TD) T e Densit Viscosit PV YP LSRV API FL H Flo-Pro SF g.4 - 8.6 45 - 55 8 - 15 24 - 30 >20,000 7.0 - 9.0 9.0 - 9.5 Logging Program Hole Section: Required Sensors /Service 16" surface: Surface G ro will need to be run to 1000' or as conditions dictate. MWD Dir/GR 12'h" intermediate: MWD Dir/GR/PWD 8'/2" roduction: MWD Dir/GR/PWD O en Hole: None Cased Hole: USIT in Intermediate section, to verif ood cement for state in'ector re uirements. Cement Program Casin Strin 13-3/8", 68#, L-80, BTC Surface casin Slurry Design Basis: Tail slurry. 1,000' of 13-3/8" x 16" annulus with 40% excess, plus ~86' of 13- 3/8", 68#, shoe tract. Tail TOC Ca3 3,662' MD. Lead Slurry. 3,662' of 13-3/8" x 1 ulus with 250% excess in permafrost and 40% below. Lead TOC at s rface Mud Push II: 140 bbls at 11.0 Slur T e 10.7 ASt_ slur Lead Slurry: Mix method Batch Mix BHST / BHT 70° F / 80° F Slur Volume 685 bbl / 3846 cf 86 sx / 10.7 / 4.4 cf/sk Slur T e 15.8 Class ` er slur with ` BLOK' additive Tail Slurry: Mix method Batch mix BHST / BHCT 70° F / 80° F Slur Volume 118 bbls / 663 cf 56 sx Class `G'/ 15.8 / .1 cf/sk. ~~ WGI-09i Permit to Drill Application Page • • Casin Strin 9 b/8", 47#, L-80, TC-II Intermediate casin lon strin Slurry Design Basis: (Stage 1) Tail slurry. 1,000' of 9 5/e' x 12-'/a" annulus with 40% excess, plus ~86' of 9 5/8", 47#, shoe tract. Tail TOC C«~ 7,381' MD. Lead Slurry. 2,719' of 9 5/8" x 12-'/a" annulus with 40% excess. Lead TOC to 4,662 md, at 13'/" surface casin shoe. Mud Push 11: 150 bbls at 11.5 Slur T e 12.0 Lite Crete slur Lead Slurry: Mix method Batch Mix (Stagel) BHST / BHT 170° F / 90° F °, Slur Volume 213 bbl / 1196 cf 469 ~x Litecrete/ 12.0 2.5 f/sk Slur T e 15.8 Class ` finer slur with `GASBL additive Tail Slurry: Mix method Batch mix (Stage 1) BHST / BHCT 170° F / 90° F Slur Volume 85 bbls / 477 cf 40 sx Class `G'/ 15.8 / 1.1 f/sk. Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. WGI-09i is on the end of the row 30 ft North East of WGI-01. WGI-02 is the next closest well at 150' away. Close Approach Shut-in Wells: All wells should pass major risk close approach criteria after re gyroing WGI-01. The closest well is WGI-01 at 30.91' ctr-ctr (-22.21' allowable deviation) at 2,002' planned MD. Hydrogen Sulfide WGI of designated as an H2S site. #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) Date of Well Name H2S Level Reading WGI-02 Gas in'ector - WGI-03 no sam les NGI-06 Gas in'ector - NGI-09 no sam les NA H2S Samples are not taken on WGI Faults The proposed WGI-09 well is located in a localized high and the structural dip is expected to be to the west. No seismically mapped fault crossings are expected, however, a number of faults are located in the near vicinity of the proposed well. Three faults are mapped in the top of Shublik near the proposed WGI-09 well, while four faults are mapped in the BSAD in the near vicinity of WGI-01 A. The coordinates for these faults will be provided in the directional plan details. The risk of fault- and fracture-associated lost circulation is considered low to medium. Significant losses (>100 barrels) were recorded in a few of the surrounding WGI, NGI, and L1 wells with the majority of the losses observed below the BSAD and a few observed in Zone 2 and one in Zone 1. Also, the NGI-06 well had a gas kick just below the BSAD. WGI-09i Permit to Drill Application Page 4 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 12'/2" intermediate interval to TSGR Maximum antici ated BHP: 3,523 si at 8,066' tvd. Maximum surface ressure: 2,717 psl (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: 206 bbls with 11.0 p EMW LOT Planned BOPE test ressure: 250 si low /-~9@ si hi h -14 da test c cle Drillin o erations / ROPE configuration for 9 5/a" intermediate casing (top to bottom . ~ Annular preventor, 9 5/8"pipe rams, blind/shear rams. Well Interval: 8'h" injection interval in Ivishak Zones 1, 2, 3 and 4 sands Maximum antici ated BHP: 3,215 psi at 8,586' tvd. Maximum surface pressure: 2,3 psi (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: I init with 10.0 p EMW FIT. Planned BOPE test ressure: si low /~66' si hi h - 14 da test c cle Drillin o erations -' Planned com letion fluid: 8.6 seawater 7.1 pp Diesel ROPE and drilling fluid system schematics are current) on file with the AOGCC. ¢ono v~Gh` BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular No annular injection in this well. Injection• Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at Handlin DS-04. Any metal cuttings should be sent to the North Slope Borough. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for disposal. WGI-09i Permit to Drill Application Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.20 ppg EMW. This pressure is estimated based on offset well pressures. II. Lost Circulation/Breathing A. The risk of fault- and fracture-associated lost circulation is considered low. Significant losses (>100 barrels) were recorded in a few of the surrounding WGI, NGI, and L1 wells but no losses were observed in the WGI-01. The majority of the losses in the surrounding wells were observed below the BSAD with a couple observed in Zone 2 (WGI-02 and NGI-07) and one in Zone 1 (WGI-02). However, since no losses were recorded in the WGI-01, the risk of lost circulation is considered low. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 206 bbls with 9.6 ppg mud; 11.0 ppg LOT, and an 8.4 ppg pore pressure at the top of the Sag River. This FIT should prove up adequate formation strength for expected ECD's. Kick tolerance drops to 50 bbls at a reservoir pressure of 9.6 ppg. B. Recent sidetrack AGI-07A experienced gas cut mud in the reservoir, although reservoir pressure was predicted at 7.7 ppg. After weighting up to 9.0+ ppg the gas ceased, but minor static losses ensued and did not cease throughout the remainder of the well and completion. Gas-detection/mud logging equipment will be available to aid the mud weight decision process if gas cut mud occurs in this well. C. The Kick Tolerance for the production hole section is infinite with 8.4 ppg mud, 10.0 ppg FIT, and an 7.2 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. D. Integrity Testing Test Point Test Depth Test EMW (Ib/gal) t e 13-3/8" 20-ft minimum from the 13-3/8" LOT 11.0 minimum shoe shoe 9-5/8" shoe 20-ft minimum from the 9-5/8" FTT 10.0 minimum shoe IV. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal with the short, vertical, slotted liner completion. VI. Hydrogen Sulfide A. WGI is not~designated as an H2S site since samples are not taken on the pad, however Standard Operating Procedures for H2S precautions should be followed at all times. VII. Faults The proposed WGI-09 well is located in a localized high and the structural dip is expected to be to the west. No seismically mapped fault crossings are expected, however, a number of faults are located in the near vicinity of the proposed well. Three faults are mapped in the top of Shublik near the proposed WGI- 09 well, while four faults are mapped in the BSAD in the near vicinity of WGI-01 A. VIII. Anti-Collision Issues All wells should pass major risk close approach criteria after re gyroing WGI-01. The closest well is WGI- 01 at 30.91' ctr-ctr (-22.21' allowable deviation) at 2,002' planned MD. WGI-09i Permit to Drill Application Page 6 • • WGI-09i OPS Summary Rig Operations: 1. MIRU Nabors 27E. 2. Nipple up diverter spool and function test diverter. PU DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR and drill surface hole to base of permafrost and trip for a new bit. 4. RIH and drill the remainder of the surface hole to approximately 4,662 MD (~ SV1). POOH and % laydown BHA. 5. Run and cement the 13-3/8" 68.0-1b/ft. surface casing haelc'"fo surface. A TAM Port Collar may be run as a contingency. 6. ND diverter spool and NU casing /tubing head. NU BOPE and test to 4,00 psi. 7. MU 12-1/4" drilling assembly with MWD/GR/PWD and RIH to t collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 13-3/8" casing to 4,000 psi for 30 minutes. 8. Drill shoe track and displace over to new 8.8 ppg LSND mud. 9. Drill new formation to 20' below 13-3/8" shoe and perform LOT (Notify ODE if 11.0 ppg LOT is ~ not obtained). 10. Drill to 200' above the HRZ, ensure mud is conditioned and weighted to 9.6 ppg. Ensure pre- reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 11. Drill ahead to target TD at 8,381' MD, (Top set Sag). 12. Circulate and condition hole, POOH to run casing. Perform wiper trip ONLY if hole conditions dictate. 13. Run and cmt the 9-5/8" intermediate casing. Bump plug and ensure that the float holds. Install 9-5/8" casing packoff and test per FMC rep. 14. Freeze protect the 13-3/a" x 9 5/8" annulus. 15. MU 8-'/2" drilling assembly with MWD / GR / PWD and TIH to float equipment. /.. 16. Test casing to 4,000 psi. Drill out Float equipment and displace to clean 8.4 ppg Flo-Pro SF. 17. Drill shoe and 20' of new formation. Perform FIT to 10.0 ppg EMW. 18. Drill to Proposed TD @ 8,901'. Short trip as required; condition hole to RIH w/ 7" slotted liner. POOH. 19. Run 7", 26 slotted liner. There will be 150°. of overlap into the 9 5/8" intermediate casing, the top 200' of otted liner will be 5 joints of u slot liner. The 150' of liner lap and 50' of Shublik ~ formation-do riot need slotted liner. Set li~cker. Release from liner, displace well to filtered seawater and POOH. 20. RU Schlumberger wireline and run USIT from liner top packer to TOC. '~ 21. Run 7 5/8" 29 ppf, VamTop HC completion. RILDS. Install TWC and test. ~,.- 22. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 23. RU LRHOS. Reverse in SW, CI and diesel then allow to U-tube. Set production packer @ 8,211'. 24. Notify AOGCC for witnessing tubing and annulus to 4,000 psi. 25. Install BPV in tubing hanger. Install a VR plug in the 9 5/8" x 7" annulus valve and secure the well. Ensure that IA/OA are both protected with two barriers. 26. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC. 2. Pull VR plug. WGI-01A Permit to Drill Application Page 7 ~ ~ Variance Request Issue Compliance with,iAOGCC testing requirements for BOP rams after they have been used in the normal oarse ~ operations. ~~_=- Request The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity ofi the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure #hat ram type equipment has integrity after it has been utilized in a wellbore.:.for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "ifi BOP sealing ram type equipment has been used, it must be fiunction pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible #luid, except that an annular type preventer need not be tested to more than 50 percent ofi its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type eauiament only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(8) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the ROPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; WtLLtitAU = ACTU_AT_O_R = KB. ELEV =- 51.10' BF. ELEV = KOP= Max Angle = 20.3 @ 2847'-7364' Datum MD = Datum TVD = WGI~9i Proposed ~ 2200' 7" A 1 INJECTION VALV E SEATED IN CAMCO DB6 NIPPLE (ID = 6") 4662' 13-3/8" 68#, L-80, BTC, 0.1497 bpf, ID = 12.415" 8116' 7-5/8" 29.7#, L-80, VAM TOP HC, IPC, 0.04591 bpf, ID = 6.875" 8200' HES R Nipple, ID = 5.963" 8211' 8225' 7" x 9-5/8" S-3 PKR, ID = 6.05" HES RN Nipple, ID = 5.770" 8231" 7" 26#, L-80, VAM TOP HC, IPC, 0.03826 bpf, ID = 6.276" $231' HMC HANGAR W/ ZXP LINER TOP PKR, ID = 6.25', 10' TBS w/ 7.5" ID 8381' 9-5/8" 47#, L-80, TC-II, 0.07321 bpf, ID = 8.681" 8431' 7" Solid LNR, 26#, L-80, BTC-M, 0.0371 bpf, ID = 6.184" i 1 I I I 1 I i I 1 t I 1 1 I i I 1 1 1 1 1 I I I I J ` 8901' 7" Slotted LNR, 26#, L-80, BTC-M, 0.0371 bpf, ID = 6.184" DATE REV BY COMMENTS 10/02/06 RLP ORIGINAL COMPLETION BP Exploration (Alaska) PRUDHOE BAY UNIT WELL: WGI-09i PERMIT No: API No: 50-029- SEC 11, T11 N, R14E, 5,051' FSL / 1215' FEL --- - ~ . ~ } -- I -_ 4 ~ J rJn~ U M N O ~c o v rl ~. -- . . .. _ _ : -- i -. ,,{ in -alp i o M o - --- - J 3 o 1 •- ~~ ~. ~ j - ~ ~ i c `E Z - x o ~ U U ~ - i , , F x M w E vt G OOVIN~ONN 00RMV~-.-. • ._ ~ ~ . . ~ .Z -aim p D 3 j oo_~~aMM yOZS _ _ J z 3 0 ;, - ^^- . _ ~ N a j a I ~ U J 3 ~ ~ ~ oooxooo _ ~ ~ ~ p .oxo ~D M a ~ ~Txx , a Y ^ y - ~ 000r 000 w N 0 -- ., ~ -- ~ i ~ - q 0~ 0 0 F. n~ '~ ._ o? o J q 3 Z f ' ~ --~-- -- . - ~ -, ~ ~ a J - .o oo~n^oo^ ., ~ C 0 r ~n 0 ~n O ~ oo-rioNC ` _ - _ ;. .. __ _ . n~z F R x z F c ~ o m c .N.1 . _ ~ - -- z - rl ,.~~ :n ._° F - F' ~ oo~nx aNri ua w ~.c~rr '~ _ a w ,'~ a '~ 41 ~ xxx - - -- . . _ _ x z ~ -_ _- . 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M: M: ^, e.orr.c-aa~n M, v~.oe-.^. -,c ,o-o -?~xrv,-~ zv~ea ora xM, ut yJxrv M,e Yav^M,x M. v^ V T vi ~0a^-MM- ,aNr M. ~^.,xNr-M,MMeeeeKVl ~D 'Jrr zxx -- M. eeevl v, ~; .n ~:rr xx xxx xx xxxxxxxxxx G z 000000000000000000000000-:0000000:0 L - ----------------------------------- ^ -aervr rvv, M,av~~n v,o0r-~~n :,o- iMr~n-rrv=taMx ,. > ,xr„o a,.~-~oooe 0~n-,.,~°n~..oc-----zxz°.r oeceh~ -- M ,ee ev, ono xxxx xx xx zxx Z -rv'^~ev~.~r xa=_riMe~r,Vrxa^rvr~ni~r~~rri ri rirr~^. r,M~ S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/3/2006. Time: 15`.15:52 Page: L Field: Prudhoe Bay (various) Co-ordinate(NE) Referenc e: Well: WG1-09, True North Site: WGI Vertical (TVD) Reference: 33.5RKB+ 17.5 51.1 Well: WGI-09 Section (VS)]teference: Well (O.OON,O.OOE,331,93Azi) Wellpath: Plan WGI-09 Survey Calculation Method: Minimum Curvature Db: Oracle.. Plan: Plan WGI-09 Wp 3 Date Composed: 9/29/2006 Version: 13 Principal: Yes Tied-to: From Well Ref. Point Field: Prudhoe Bay (various) Map SysterrilS State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumiVAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: WGI TR-11-14 UNITED STATES : NoRh Slope Site Position: Northing: 5971028.59 ft Latitude: 70 19 32.905 N From: Map Easting: 685599.07 ft Longitude: 148 29 41.399 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.42 deg Well: WGI-09 Slot Name: Well Position: +N/-S 1019.11 ft Northing: 5972032.62 ft Latitude: 70 19 42.927 N +E/-W -594.70 ft Easting : 684979.38 ft Longitude: 148 29 58.760 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 4661.72 4531.10 13.375 17.500 13 3/8" 8381.33 8066.10 9.625 12.250 9 5/8" 8924.77 0.00 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 583.10 583.10 G1 0.00 0.00 1651.10 1651.10 SV6 0.00 0.00 1912.10 1912.10 BPRF 0.00 0.00 2392.65 2391.10 EOCU 0.00 0.00 3184.16 3146.10 SV5 0.00 0.00 3376.19 3326.10 SV4 0.00 0.00 3957.61 3871.10 SV3 0.00 0.00 4117.63 4021.10 SV2 0.00 0.00 4576.37 4451.10 SV1 0.00 0.00 4981.76 4831.10 UG4 0.00 0.00 5259.14 5091.10 UG3 0.00 0.00 5749.88 5551.10 UG1 0.00 0.00 6395.31 6156.10 WS2 0.00 0.00 6603.34 6351.10 WS1 0.00 0.00 6875.39 6606.10 CM3 0.00 0.00 7296.78 7001.10 CM2 0.00 0.00 7784.77 7471.10 CM1 0.00 0.00 8131.33 7816.10 THRZ 0.00 0.00 8356.33 8041.10 BHRZ/TPTR 0.00 0.00 8366.33 8051.10 LCU/TKNG 0.00 0.00 8381.33 8066.10 TSGR 0.00 0.00 8421.33 8106.10 TSHA 0.00 0.00 8431.33 8116.10 TSHB 0.00 0.00 8441.33 8126.10 TSHC 0.00 0.00 8446.33 8131.10 TSAD 0.00 0.00 8491.33 8176.10 42SB 0.00 0.00 8566.33 8251.10 TCGL 0.00 0.00 8631.33 8316.10 BCGL 0.00 0.00 8686.33 8371.10 23SB 0.00 0.00 8736.33 8421.10 22TS 0.00 0.00 8761.33 8446.10 21TS 0.00 0.00 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/3/2006 Time: 15:15;52 Page: 2 Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: WGI-09, True North Site: WGf Vertical (TVD) Reference: 33.5RK6+. 17.551:.4 Well: WGI-09 Sect ion (VS) Refe rence: Well (O.OON,O.OOE,331 :93Azi ) Wellpath: Plan WGI-09 Survey Calculatio n Method: Minimum Curvature Dh: Oracle Formations MD TVD Formations Lithology Dip Angle Dip Direction . ft fY deg deg 8806.33 8491.10 TZ1B 0.00 0. 00 8846.33 8531.10 TDF 0.00 0. 00 8896.33 8581.10 BSAD 0.00 0.00 Targets Map .Map <_-__ Latitude. ----><--- .Longitude --- Name Description TVD +N/-S +E/-W Northing Easting Deg M in Sec Deg M in.. Sec Dip. Dir. ft ft ft ft ft WGI-01A Shublik Rev 1 8091.10 1635.00 -872.00 5973645.52 684067.39 70 19 59.007 N 148 30 24.223 W -Polygon 1 8091.10 1703.35 -1068.78 5973709.00 683869.00 70 19 59.679 N 148 30 29.969 W -Polygon 2 8091.10 1568.42 -1033.09 5973575.00 683908.00 70 19 58.352 N 148 30 28.926 W -Polygon 3 8091.10 1460.77 -683.62 5973476.00 684260.00 70 19 57.294 N 148 30 18.721 W -Polygon 4 8091.10 1481.95 -569.05 5973500.00 684374.00 70 19 57.502 N 148 30 15.376 W -Polygon 5 8091.10 1797.57 -711.32 5973812.00 684224.00 70 20 0.606 N 148 30 19.531 W -Plan hit target WGI-01A Fault 1 8581.10 2431.19 -1375.94 5974429.00 683544.00 70 20 6.837 N 148 30 38.942 W -Polygon 1 8581.10 2431.19 -1375.94 5974429.00 683544.00 70 20 6.837 N 148 30 38.942 W -Polygon 2 8581.10 2470.48 -1062.86 5974476.00 683856.00 70 20 7.224 N 148 30 29.799 W -Polygon 3 8581.10 2337.76 -792.03 5974350.00 684130.00 70 20 5.919 N 148 30 21.890 W -Polygon 4 8581.10 2319.31 -571.41 5974337.00 684351.00 70 20 5.737 N 148 30 15.447 W -Polygon 5 8581.10 2472.07 -72.46 5974502.00 684846.00 70 20 7.240 N 148 30 0.876 W -Polygon 6 8581.10 2571.08 699.26 5974620.00 685615.00 70 20 8.213 N 148 29 38.339 W -Polygon 7 8581.10 2548.69 876.78 5974602.00 685793.00 70 20 7.993 N 148 29 33.155 W -Polygon 8 8581.10 2571.08 699.26 5974620.00 685615.00 70 20 8.213 N 148 29 38.339 W -Polygon 9 8581.10 2472.07 -72.46 5974502.00 684846.00 70 20 7.240 N 148 30 0.876 W -Polygon 10 8581.10 2319.31 -571.41 5974337.00 684351.00 70 20 5.737 N 148 30 15.447 W -Polygon 11 8581.10 2337.76 -792.03 5974350.00 684130.00 70 20 5.919 N 148 30 21.890 W -Polygon 12 8581.10 2470.48 -1062.86 5974476.00 683856.00 70 20 7.224 N 148 30 29.799 W -Plan out by 942.15 at 8581.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W WGI-01A Fault 2 8581.10 2147.67 -466.60 5974168.00 684460.00 70 20 4.049 N 148 30 12.386 W -Polygon 1 8581.10 2147.67 -466.60 5974168.00 684460.00 70 20 4.049 N 148 30 12.386 W -Polygon 2 8581.10 2190.30 116.66 5974225.00 685042.00 70 20 4.469 N 148 29 55.353 W -Polygon 3 8581.10 2147.67 -466.60 5974168.00 684460.00 70 20 4.049 N 148 30 12.386 W -Plan out by 653.48 at 8581.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W WGI-01A Fault 3 8581.10 .3035.53 -731.81 5975049.00 684173.00 70 20 12.781 N 148 30 20.133 W -Polygon 1 8581.10 3035.53 -731.81 5975049.00 684173.00 70 20 12.781 N 148 30 20.133 W -Polygon 2 8581.10 3123.82 -255.46 5975149.00 684647.00 70 20 13.650 N 148 30 6.221 W -Polygon 3 8581.10 3127.26 334.84 5975167.00 685237.00 70 20 13.684 N 148 29 48.981 W -Polygon 4 8581.10 3123.82 -255.46 5975149.00 684647.00 70 20 13.650 N 148 30 6.221 W -Plan out by 1407.39 at 8581.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W WGI-01A Fault 4 8581.10 1376.72 -1331.92 5973376.00 683614.00 70 19 56.466 N 148 30 37.651 W -Polygon 1 8581.10 1376.72 -1331.92 5973376.00 683614.00 70 19 56.466 N 148 30 37.651 W -Polygon 2 8581.10 750.76 482.30 5972795.00 685443.00 70 19 50.311 N 148 29 44.679 W -Plan out by 527.55 at 8581.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W WGI-01A T1 rev 2 8586.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W -Circle (Radius: 150) -Plan hit target WGI-01A T1 rev 1 8611.10 1635.14 -872.00 5973645.66 684067.38 70 19 59.008 N 148 30 24.223 W -Circle (Radius: 150) Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ftdeg/100ftdeg/1OOft deg 33.50 0.00 0.00 33.50 0.00 0.00 0.00 0.00 0.00 0.00 1950.00 0.00 0.00 1950.00 0.00 0.00 0.00 0. 00 0.00 0.00 2235.71 5.00 334.00 2235.35 11.20 -5.46 1.75 1. 75 0.00 334.00 2851.40 20.39 331.88 2834.19 130.62 -68.14 2.50 2. 50 -0.34 -2.78 7335.82 20.39 331.88 7037.70 1508.51 -804.35 0.00 0. 00 0.00 0.00 8151.33 0.00 0.00 7836.10 1635.14 -872.00 2.50 -2. 50 0.00 1 80.00 8901.33 0.00 0.00 8586.10 1635.14 -872.00 0.00 0. 00 0.00 0.00 WGI-01 A T1 rev 2 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/3/2006 Time: 45:15:52 Page: 3 Field: Prudhoe Bay (various) Co-ordinate( NE) Reference: Well: WGI-09, True North Site: WGI Vertical (TVD) Reference: 33. 5RK6+ 17:5 51:1 Well: WGI-09 Section(VS) Reference: Well (O.OON,O.OOE,331.93Azi) Wellpath: Plan WGI-09 Survey Calculation. Methods Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft ft ft 33.50 0.00 0.00 33.50 -17.60 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 100.00 0.00 0.00 100.00 48.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 200.00 0.00 0.00 200.00 148.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 300.00 0.00 0.00 300.00 248.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 400.00 0.00 0.00 400.00 348.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 500.00 0.00 0.00 500.00 448.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 583.10 0.00 0.00 583.10 532.00 0.00 0.00 0.00 0.00 5972032.62 684979.38 G1 600.00 0.00 0.00 600.00 548.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 700.00 0.00 0.00 700.00 648.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 CB-GYRO 800.00 0.00 0.00 800.00 748.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 900.00 0.00 0.00 900.00 848.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1000.00 0.00 0.00 1000.00 948.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1100.00 0.00 0.00 1100.00 1048.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1200.00 0.00 0.00 1200.00 1148.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1300.00 0.00 0.00 1300.00 1248.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1400.00 0.00 0.00 1400.00 1348.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1500.00 0.00 0.00 1500.00 1448.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1600.00 0.00 0.00 1600.00 1548.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1651.10 0.00 0.00 1651.10 1600.00 0.00 0.00 0.00 0.00 5972032.62 684979.38 SV6 1700.00 0.00 0.00 1700.00 1648.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1800.00 0.00 0.00 1800.00 1748.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1900.00 0.00 0.00 1900.00 1848.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 MWD+IFR 1912.10 0.00 0.00 1912.10 1861.00 0.00 0.00 0.00 0.00 5972032.62 684979.38 BPRF 1950.00 0.00 0.00 1950.00 1898.90 0.00 0.00 0.00 0.00 5972032.62 684979.38 Start Dirt. 2000.00 0.88 334.00 2000.00 1948.90 0.38 0.34 -0.17 1.75 5972032.96 684979.20 MWD+IFR 2100.00 2.63 334.00 2099.95 2048.85 3.43 3.09 -1.51 1.75 5972035.67 684977.80 MWD+IFR 2200.00 4.38 334.00 2199.76 2148.66 9.53 8.57 -4.18 1.75 5972041.09 684974.99 MWD+IFR 2235.71 5.00 334.00 2235.35 2184.25 12.45 11.20 -5.46 1.75 5972043.68 684973.64 Start Dirt. 2300.00 6.61 333.32 2299.31 2248.21 18.95 17.02 -8.35 2.50 5972049.43 684970.61 MWD+IFR 2392.65 8.92 332.78 2391.10 2340.00 31.46 28.17 -14.03 2.50 5972060.43 684964.66 EOCU 2400.00 9.10 332.74 2398.36 2347.26 32.61 29.19 -14.56 2.50 5972061.45 684964.11 MWD+IFR 2500.00 11.60 332.41 2496.72 2445.62 50.58 45.14 -22.84 2.50 5972077.18 684955.44 MWD+IFR 2600.00 14.10 332.20 2594.21 2543.11 72.82 64.84 -33.18 2.50 5972096.62 684944.61 MWD+IFR 2700.00 16.60 332.04 2690.63 2639.53 99.30 88.24 -45.56 2.50 5972119.70 684931.66 MWD+IFR 2800.00 19.10 331.93 2785.81 2734.71 129.95 115.30 -59.96 2.50 5972146.40 684916.60 MWD+IFR 2851.40 20.39 331.88 2834.19 2783.09 147.32 130.62 -68.14 2.50 5972161.51 684908.05 End Dir 8 2900.00 20.39 331.88 2879.74 2828.64 164.25 145.55 -76.12 0.00 5972176.24 684899.70 MWD+IFR 3000.00 20.39 331.88 2973.48 2922.38 199.09 176.28 -92.53 0.00 5972206.55 684882.53 MWD+IFR 3100.00 20.39 331.88 3067.21. 3016.11 233.92 207.01 -108.95 0.00 5972236.86 684865.36 MWD+IFR 3184.16 20.39 331.88 3146.10 3095.00 263.24 232.86 -122.77 0.00 5972262.37 684850.92 SV5 3200.00 20.39 331.88 3160.95 3109.85 268.76 237.73 -125.37 0.00 5972267.17 684848.20 MWD+IFR 3300.00 20.39 331.88 3254.69 3203.59 303.60 268.46 -141.79 0.00 5972297.48 684831.03 MWD+IFR 3376.19 20.39 331.88 3326.10 3275.00 330.14 291.87 -154.29 0.00 5972320.58 684817.95 SV4 3400.00 20.39 331.88 3348.42 3297.32 338.43 299.18 -158.20 0.00 5972327.79 684813.86 MWD+IFR 3500.00 20.39 331.88 3442.16 3391.06 373.27 329.91 -174.62 0.00 5972358.10 684796.69 MWD+IFR 3600.00 20.39 331.88 3535.89 3484.79 408.11 360.64 -191.04 0.00 5972388.41 684779.52 MWD+IFR 3700.00 20.39 331.88 3629.63 3578.53 442.95 391.36 -207.45 0.00 5972418.73 684762.35 MWD+IFR 3800.00 20.39 331.88 3723.36 3672.26 477.78 422.09 -223.87 0.00 5972449.04 684745.18 MWD+IFR 3900.00 20.39 331.88 3817.10 3766.00 512.62 452.82 -240.29 0.00 5972479.35 684728.02 MWD+IFR 3957.61 20.39 331.88 3871.10 3820.00 532.69 470.52 -249.74 0.00 5972496.81 684718.13 SV3 4000.00 20.39 331.88 3910.84 3859.74 547.46 483.54 -256.70 0.00 5972509.66 684710.85 MWD+IFR 4100.00 20.39 331.88 4004.57 3953.47 582.29 514.27 -273.12 0.00 5972539.97 684693.68 MWD+IFR 4117.63 20.39 331.88 4021.10 3970.00 588.44 519.69 -276.02 0.00 5972545.31 684690.65 SV2 ment • S err -Sun P Y BP Planning Report Company: BP Amoco Date: 10/3/2006 Time: 15:15:52 Page: 4 Fields Prudhoe Bay (various) Co-ordinate(NE) Reference: Well: WGI-09, True North Site: WGI Vertical (TVD) Reference: 33.5RKB+ 17.5 51.1 Well: WGI-09 Section (VS) Reference: Well (O:OON,O.OOE,331:93Azi) Wellpath: Plan WGI-09 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 4200.00 4300.00 4400.00 4500.00 4576.37 4600.00 4661.72 4700.00 4800.00 4900.00 4981.76 5000.00 5100.00 5200.00 5259.14 5300.00 5400.00 5500.00 5600.00 5700.00 5749.88 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6395.31 6400.00 6500.00 6600.00 6603.34 6700.00 6800.00 6875.39 6900.00 7000.00 7100.00 7200.00 7296.78 7300.00 7335.82 7400.00 7500.00 7600.00 7700.00 7784.77 7800.00 7900.00 8000.00 8100.00 8131.33 Incl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft 20.39 331 .88 4098. 31 4047.21 617.13 544.99 20.39 331 .88 4192. 04 4140.94 651.97 575.72 20.39 331 .88 4285. 78 4234.68 686.80 606.45 20.39 331 .88 4379. 51 4328.41 721.64 637.17 20.39 331 .88 4451. 10 4400.00 748.25 660.64 20.39 331 .88 4473. 25 4422.15 756.48 667.90 20.39 331 .88 4531. 10 4480.00 777.98 686.86 20.39 331 .88 4566. 99 4515.89 791.31 698.62 20.39 331 .88 4660. 72 4609.62 826.15 729.35 20.39 331 .88 4754. 46 4703.36 860.99 760.08 20.39 331 .88 4831. 10 4780.00 889.47 785.20 20.39 331 .88 4848. 19 4797.09 895.83 790.80 20.39 331 .88 4941. 93 4890.83 930.66 821.53 20.39 331 .88 5035. 66 4984.56 965.50 852.26 20.39 331 .88 5091. 10 5040.00 986.10 870.43 20.39 331 .88 5129. 40 5078.30 1000.34 882.98 20.39 331 .88 5223. 14 5172.04 1035.17 913.71 20.39 331 .88 5316. 87 5265.77 1070.01 944.43 20.39 331 .88 5410. 61 5359.51 1104.85 975.16 20.39 331 .88 5504. 34 5453.24 1139.68 1005.89 20.39 331 .88 5551. 10 5500.00 1157.06 1021.21 20.39 331 .88 5598. 08 5546.98 1174.52 1036.61 20.39 331 .88 5691. 81 5640.71 1209.36 1067.34 20.39 331 .88 5785. 55 5734.45 1244.20 1098.07 20.39 331 .88 5879. 29 5828.19 1279.03 1128.79 20.39 331 .88 5973. 02 5921.92 1313.87 1159.52 20.39 331 .88 6066. 76 6015.66 1348.71 1190.24 20.39 331 .88 6156. 10 6105.00 1381.91 1219.53 20.39 331 .88 6160. 49 6109.39 1383.54 1220.97 20.39 331 .88 6254. 23 6203.13 1418.38 1251.70 20.39 331 .88 6347. 96 6296.86 1453.22 1282.42 20.39 331 .88 6351. 10 6300.00 1454.38 1283.45 20.39 331 .88 6441. 70 6390.60 1488.05 1313.15 20.39 331 .88 6535. 44 6484.34 1522.89 1343.87 20.39 331 .88 6606. 10 6555.00 1549.15 1367.04 20.39 331 .88 6629. 17 6578.07 1557.73 1374.60 20.39 331 .88 6722. 91 6671.81 1592.57 1405.33 20.39 331 .88 6816. 64 6765.54 1627.40 1436.05 20.39 331 .88 6910. 38 6859.28 1662.24 1466.78 20.39 331 .88 7001. 10 6950.00 1695.96 1496.52 20.39 331 .88 7004. 11 6953.01 1697.08 1497.51 20.39 331 .88 7037. 70 6986.60 1709.56 1508.51 18.78 331 .88 7098. 16 7047.06 1731.07 1527.49 16.28 331 .88 7193. 50 7142.40 1761.19 1554.06 13.78 331 .88 7290. 07 7238.97 1787.13 1576.93 11.28 331 .88 7387. 68 7336.58 1808.83 1596.07 9.16 331 .88 7471. 10 7420.00 1823.87 1609.34 8.78 331 .88 7486. 14 7435.04 1826.25 1611.43 6.28 331 .88 7585. 27 7534.17 1839.36 1623.00 3.78 331 .88 7684. 88 7633.78 1848.13 1630.73 1.28 331 .88 7784. 77 7733.67 1852.55 1634.63 0.50 331 .88 7816. 10 7765.00 1853.04 1635.06 E/W DLS MapN ft deg/100ft ft -289.54 0.00 5972570.28 -305.96 0.00 5972600.59 -322.37 0.00 5972630.90 -338.79 0.00 5972661.21 -351.33 0.00 5972684.35 -355.21 0.00 5972691.52 -365.34 0.00 5972710.22 -371.62 0.00 5972721.83 -388.04 0.00 5972752.14 -404.46 0.00 5972782.45 -417.88 0.00 5972807.23 -420.87 0.00 5972812.76 -437.29 0.00 5972843.07 -453.71 0.00 5972873.38 -463.42 0.00 5972891.30 -470.12 0.00 5972903.69 -486.54 0.00 5972934.00 -502.96 0.00 5972964.31 -519.38 0.00 5972994.62 -535.79 0.00 5973024.93 -543.98 0.00 5973040.05 -552.21 0.00 5973055.24 -568.63 0.00 5973085.55 -585.04 0.00 5973115.86 -601.46 0.00 5973146.17 -617.88 0.00 5973176.48 -634.29 0.00 5973206.79 -649.94 0.00 5973235.68 -650.71 0.00 5973237.10 -667.13 0.00 5973267.41 -683.55 0.00 5973297.72 -684.09 0.00 5973298.74 -699.96 0.00 5973328.03 -716.38 0.00 5973358.34 -728.76 0.00 5973381.19 -732.80 0.00 5973388.65 -749.21 0.00 5973418.96 -765.63 0.00 5973449.27 -782.05 0.00 5973479.58 -797.94 0.00 5973508.92 -798.46 0.00 5973509.89 -804.35 0.00 5973520.75 -814.48 2.50 5973539.47 -828.68 2.50 5973565.68 -840.90 2.50 5973588.24 -851.13 2.50 5973607.12 -858.22 2.50 5973620.21 -859.34 2.50 5973622.28 -865.51 2.50 5973633.68 -869.65 2.50 5973641.32 -871.73 2.50 5973645.16 -871.96 2.50 5973645.59 MapE Tool/C ft 684676.51 MWD+IFF 684659.34 MWD+IFF 684642.17 MWD+IFF 684625.01 MWD+IFF 684611.89 SV1 684607.84 MWD+IFF 684597.24 13 3/8" 684590.67 MWD+IFF 684573.50 MWD+IFF 684556.33 MWD+IFF 684542.29 UG4 684539.16 MWD+IFF 684521.99 MWD+IFF 684504.83 MWD+IFF 684494.67 UG3 684487.66 MWD+IFF 684470.49 MWD+IFF 684453.32 MWD+IFF 684436.15 MWD+IFF 684418.98 MWD+IFF 684410.42 UG1 684401.81 MWD+IFF 684384.65 MWD+IFF 684367.48 MWD+IFF 684350.31 MWD+IFF 684333.14 MWD+IFF 684315.97 MWD+IFf 684299.61 WS2 684298.80 MWD+IFF 684281.64 MWD+IFF 684264.47 MWD+IFF 684263.89 WS1 684247.30 MWD+IFF 684230.13 MWD+IFF 684217.19 CM3 684212.96 MWD+IFF 684195.79 MWD+IFF 684178.62 MWD+IFF 684161.46 MWD+IFF 684144.84 CM2 684144.29 MWD+IFF 684138.14 Start Dir 684127.54 MWD+IFF 684112.69 MWD+IFF 684099.91 MWD+IFF 684089.21 MWD+IFF 684081.80 CM1 684080.63 MWD+IFF 684074.17 MWD+IFF 684069.84 MWD+IFF 684067.67 MWD+IFF 684067.43 THFtZ S er -Sun , P rY BP Planning Report Company: BP Amoco Date: 10/3/2006 Time: 15:15:52 Page: 5 Field: Prudhoe Bay (various) Co-ordinate( NE) R eference: Well: WGI-09, 1`rue North Site: WGI Vertical (TVD) Reference: 33. 5RK6+ 17:5 51.1 Well: WGI-09 Section (VS) Refer ence: Well (O.OON,O.OOE,331.93Azi) Wellpath: Plan WGI-09 Survey Calculation Method: Minimum Curvature Db: Oracle.. Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg. ft ft fit ft ft deg/100ft ft ft 8151. 33 0.00 0.00 7836.10 7785.00 1853.12 1635.14 -872 .00 2.50 5973645.66 684067.38 End Dir 1 8200. 00 0.00 0.00 7884.77 7833.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8300. 00 0.00 0.00 7984.77 7933.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8356. 33 0.00 0.00 8041.10 7990.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 BHRZ/TPT 8366. 33 0.00 0.00 8051.10 8000.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 LCU/TKNG 8381. 33 0.00 0.00 8066.10 8015.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 9 5/8" 8400. 00 0.00 0.00 8084.77 8033.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8406. 33 0.00 0.00 8091.10 8040.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 WGI-01A 8421. 33 0.00 0.00 8106.10 8055.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TSHA 8431. 33 0.00 0.00 8116.10 8065.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TSHB 8441. 33 0.00 0.00 8126.10 8075.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TSHC 8446. 33 0.00 0.00 8131.10 8080.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TSAD 8491. 33 0.00 0.00 8176.10 8125.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 42SB 8500. 00 0.00 0.00 8184.77 8133.67 1853.12 1635.14 -872. 00 0.00 5973645.66 684067.38 MWD+IFR 8566. 33 0.00 0.00 8251.10 8200.00 1853.12 1635.14 -872. 00 0.00 5973645.66 684067.38 TCGL 8600. 00 0.00 0.00 8284.77 8233.67 1853.12 1635.14 -872. 00 0.00 5973645.66 684067.38 MWD+IFR 8631. 33 0.00 0.00 8316.10 8265.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 BCGL 8686. 33 0.00 0.00 8371.10 8320.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 23SB 8700. 00 0.00 0.00 8384.77 8333.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8736. 33 0.00 0.00 8421.10 8370.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 22TS 8761. 33 0.00 0.00 8446.10 8395.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 21 TS 8800. 00 0.00 0.00 8484.77 8433.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8806. 33 0.00 0.00 8491.10 8440.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TZ18 8846. 33 0.00 0.00 8531.10 8480.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 TDF 8896. 33 0.00 0.00 8581.10 8530.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 WGI-01A 8900. 00 0.00 0.00 8584.77 8533.67 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 MWD+IFR 8901. 33 0.00 0.00 8586.10 8535.00 1853.12 1635.14 -872 .00 0.00 5973645.66 684067.38 WGI-01A Went 5 ablik ~It 1 rev Nmrw N'(i1JN N S lulu-II w'hu. urrnlLS ~ Ii -N' Narcthmp liaising lrunxk Lnn~inW. 51ot -WJ U 549_'Ui^_.G2 (>1tJ4"4 i% JII l4'{~4~N IJF'24L?N](UVA '.v.A ANTI-C'DLLISIDN SETTINGS lnmgwlannn McthuJ:MD Intcnal: i(LUU DCInh R.mgC From' i3 )U TO' KHIII i3 Maxunum Ranee IUS6 7h Retuenu: Plun: Ilan NYiI-U9 N-p i cuAlpnNr un;\as nl' Amo.o t I I nl n,.XL hI c urwc [ • :I. - nc \\Sq 1.~r AlvunN Ire+CtlinJ.r ~rrnu Imur Surf ~.: I:Ilipliual - l':vun_, ti ammg AlutMnL Rulca IL+~rI tivevev pKIx~K:\AI Ucprh tin UcpIL lb Sun-cc I'I:Wn -tool iql %nU1M 11 r~~PI N I AAp:~ll cli-(1vKUS5 %auNl xwn.. \ I r nv+l. PI:.. NN law \cp e ri1 m\cu lFK Ms Plan N I f LI':\ I I I I)I 1:\ILS 16O From Colour To MD '~'"'"`1119 1SO 34 8250 Krg K.(o~min: laswcu-I,s ~Lnra 8250 8500 33 0 8soo 87so ,,,~, N;.S ~.,, rr.,rr, I,I> 8750 9000 311 v* IIIN, n INI I. 9000 9250 , 12S 92so 9soo 9500 9750 "~ 9750 10000 10000 10250 10250 1000 L''(11ND lOO 10500 10750 - LI-I~ILI I?r.nlnl,~rKr+A ' IO75O --- ' y -"--- I IOOO LI-I!ILI-I~,\I. A1nlur Kr.A ~ LI I ILI I \I nll All KI.+A / /~. l 11000 ~- - - 11250 ~ Nl I N INl IJ),I. AI ~ K L N<I ItN(~I Lnl) K w 30 L // ~ /~ I I25O V I ISOOO X111111\1( INi;IM1 IJ IN II~:KKI)kti ' 5 75 ~ / / ~9 ~ N tl Ntl 1?4%I I K+k ` i/ / / / ~ // ~ a ~ N I uIN(I NI nl.1,rK+A ~ // ~ ~ / ~ ////~ ~ I'I \1l I IXr\\p r 0 ~. 2S ~~ 0 270 90 2S 0 7S 240 ~ ~, 120 100 ~; 125 ~ ~~` \ -`~ 21 \ _ ~~ SI ('I I()N 1)11'1:\ILS ' l.r All) IrX ur I\1) N S 1 \1 I>Lv~; Iha.c \4.. Ier__.1 1S0 ~ I 1441.UI1 II UII ??J571 S.W II1X1 iIJ.INI I45111N1 ??1515 Il lln II.JI 111X1 111X1 n. NI nlNl -5.J4 1.]c };J-W I'_i`, 160 6 J XIJII n14 11 4 % ~ i iil.%% 111 %X %17.14 „ 1111! ISIw SI filt lJ '.41 ?X IJ-'_ NUJ 1$ II IXI I11N1 I W+G 1 80 . . L 11.- -, Y11.11 IM1~ IJ "V IYII I I" - 4 I.1~ n x nlXl ~„ n lui IJ -, _, x , x I -.I'_ U(.I-,il \ I I r.v'_ Travelling Cylinder Azimuth (TFO+AZI) [ deg] vs Centre to Centre Separation [SOft/in] J • S err -Sun i P Y Anticollision Report Company: BP Amoco Date: 10/3/2006 Time: 15:14:56 Page: 1 Field: Prudhoe Bay (various) Reference Site: WGI Co-ordinate(NE) Reference: Well: WG I-09, True North. Reference Well: WGI-09 Vertical ( TVD) Reference: 33.5RK6+ 17.5 51.1 Reference Wellpatb'Jan WGI-09 Db: Oracle. GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - TRefe~aarec'FIGHT ~IihcipekRlarfi$IfdIANNED PROGRAM Interpolation Meth odMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 33.50 to 8901.33 ft Scan Method: Trav Cylinder North Maximum Radius:1 086.78 ft Error Surface : Ellipse + Casing Survey Program fo r Definitive Wellpath Date: 9/29/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 33.50 8901.33 Planned: Plan WGI-09 Wp 3 V13 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 4661.72 4531.10 13.375 17.500 13 3/8" 8381.33 8066.10 9.625 12.250 9 5/8" 8924.77 0.00 7.000 8.500 7" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctt• No-Go Allowable Site Well Wellpath MD MD Distanc e Area . Deviation Warning ft ft ft ft ft Lis DS 01 L1-15 L1-15 V1 8797.43 10200.00 473.68 163.06 310.62 Pass: Major Risk Lis DS 01 L1-15 L1-15A V6 8797.43 10200.00 473.68 163.06 310.62 Pass: Major Risk Lis DS 01 L1-15 L1-15APB1 V1 8797.43 10200.00 473.68 163.03 310.65 Pass: Major Risk NGI NGI-06 NGI-06 V1 8786.91 9400.00 940.96 345.05 595.91 Pass: Major Risk NGI NGI-09 NGI-09 V2 7146.83 8050.00 806.33 353.83 452.51 Pass: Major Risk WGI WGI-01 Plan WGI-01A V2 Plan: 4163.42 4200.00 21.36 1.13 20.23 Pass: NOERRORS WGI WGI-01 WGI-01 V3 2001.63 2000.00 30.91 53.12 -22.21 FAIL: Major Risk WGI WGI-02 WGI-02 V1 1999.80 2000.00 153.56 39.61 113.94 Pass: Major Risk WGI WGI-03 WGI-03 V1 2002.13 2000.00 283.70 32.75 250.95 Pass: Major Risk WGI WGI-04 WGI-04 V1 2000.54 2000.00 401.60 35.53 366.07 Pass: Major Risk Site: Lis DS 01 Well: L1-15 Rule Assigned: Major Risk Wellpath: L1-15 V1 Inter-Si te Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HBistanceArea Deviation Warning ft ft ft ft ft ft deg .deg in ft ft ft 7696.54 7384.29 8850.00 7498.12 13.01 27.17 94.72 122.83 9.625 1066.00 123.21 942.79 Pass 7746.92 7433.79 8900.00 7535.49 12.98 27.56 95.79 123.90 9.625 1039.68 123.97 915.70 Pass 7797.20 7483.38 8950.00 7572.70 12.96 27.94 96.88 125.00 9.625 1013.07 124.76 888.31 Pass 7847.40 7533.06 9000.00 7609.81 12.93 28.31 97.99 126.11 9.625 986.22 125.56 860.66 Pass 7897.46 7582.75 9050.00 7646.80 12.90 28.69 99.12 127.24 9.625 959.11 126.38 832.72 Pass 7947.31 7632.35 9100.00 7683.69 12.87 29.05 100.28 128.39 9.625 931.73 127.21 804.51 Pass 7996.89 7681.77 9150.00 7720.46 12.84 29.41 101.46 129.58 9.625 904.10 128.05 776.05 Pass 8046.11 7730.92 9200.00 7757.10 12.81 29.75 102.69 130.81 9.625 876.24 128.89 747.34 Pass 8095.01 7779.79 9250.00 7793.65 12.78 30.06 103.96 132.08 9.625 848.24 129.65 718.59 Pass 8143.63 7828.40 9300.00 7830.19 12.75 30.35 105.29 133.41 9.625 820.19 124.14 696.05 Pass 8182.04 7866.81 9350.00 7866.71 12.75 30.63 106.69 106.69 9.625 792.28 131.55 660.73 Pass 8218.57 7903.34 9400.00 7903.24 12.76 30.90 108.18 108.18 9.625 764.83 132.84 631.99 Pass 8255.04 7939.81 9450.00 7939.71 12.78 31.20 109.79 109.79 9.625 737.90 134.34 603.56 Pass 8291.40 7976.17 9500.00 7976.07 12.80 31.51 111.53 111.53 9.625 711.51 135.91 575.61 Pass 8327.67 8012.44 9550.00 8012.34 12.82 31.82 113.40 113.40 9.625 685.74 137.60 548.15 Pass 8363.83 8048.60 9600.00 8048.50 12.84 32.14 115.42 115.42 9.625 660.67 139.38 521.30 Pass 8399.87 8084.64 9650.00 8084.54 12.87 32.47 117.60 117.60 9.625 636.38 141.25 495.13 Pass 8435.79 8120.56 9700.00 8120.46 12.89 32.79 119.96 119.96 9.625 612.98 143.07 469.91 Pass 8471.59 8156.36 9750.00 8156.26 12.91 33.10 122.52 122.52 7.625 590.66 145.00 445.66 Pass 8507.27 8192.04 9800.00 8191.94 12.93 33.42 125.29 125.29 7.625 569.65 147.10 422.54 Pass 8542.96 8227.73 9850.00 8227.63 12.95 33.68 128.27 128.27 7.625 550.19 149.12 401.07 Pass Plan: Plan WGI-09 Wp 2 (WGI-09/Plan WGI-09) 2401 2301 220 210 200 190 180 170 160 + ~ 1S0' O z ^, l40 t 130 120 110 100 90 80 70 60 SO L i . ~ ~ ~ ;-,- ~-~ ~- NGI-U9 NGI-U9) I : j T +--I - _ , - ~- - ,_ ~ _, r _ _a.~ ~_ L_ _ _.- am'- -- _ - . _ - I~ r ~ ~ T _, ,~ i ++ L _ . - ~I -I _. "_ l 1_._1 ~ t r -~ ~ ' - ~ r r-{ F t ~ r-- . . ~"-. , . ~_- ~~~T- -r~ i-~ - i+ L ~ i~ i 4. I r T ~ ~ { r i r r ~~ -+ i -~ ~. r+ ~ - ~ r I _ +~ ~-( _. t -.. i - -~-1-,- 1 Y {{ r! - - ~ ~ ~ 1 ! ' ~ - } ~ i LI-1S LI ISA _ NGI-U 6 NGl-06 ~ r fi T. ~ _. : _ . r I t _.. _ t - ~ . - i ~ - . ~f ~-1 ~ I I 7-I- .-~ ~ ~ L i - ' ~ Pla ~ n W'GI-09 W -~- - i ~ it r ~ - _ ~. - : - + - +,- - _ l . _ -~- _ ~ __ _ _ i ~ - - + ~_ t ~~r i , { r ? f ~ ~ i 4 '_~- ~ i , ~ . - -- - _ _ L., _~- r - ~ t ~ ~~ ( -- - ~ ---- -- ~ i r + I - ~ ~~ _-_ LI-IS Ll-1SAPB1 _ _ __ _ - - t----- ~ I t - - i - i _ _~ - . ... ' fi I i 7 ! -rte __ ~ 1 T ~ , r .f_ .~. {. ~1 .r i . - _ . . , - ~. ~- ' , . - r -h -~ ~~ -- -_ - h ,- - r - ~ ~ ' - - ~ r.i ~-. .~~, _ _ i L1-15 LI-IS I r 1 i a ~ ~ t _ r _ - ._ - - , - r.~w r ~ -a ~- I ~ ~ I ~1 t I - i Tt -~ T~ ~ 1. ~ - r- ti_ + , T ~ - ~ - - --- .~ I ~ -. ~ _.. _ .__ ._ - ~ __I - ..,:._ - I _ I _ ~_. ._ _ { -. . I - ~ i .. -- t _ - i - -*- ~~-1 -Y ~. _ 1 t _. .._. .' _ _ Y- .Y~ 1_-IT i ~'_Y' T _ 1 - ~ Y .i .. -2300 -ZZUU -ZIUU -ZUW -19UU -I2SUU -I/UU -16UU -ISVU -l4VU -ISUU -IZUU -IIUU -1000 -YUU -2SUU -iuu -buu -~uu -4VV -svu -[VV -I VV u Ivu [uv wv vuu wv buv West(-)/East(+) [ft] • • - LI-IS (Ll-1S) Ll-IS (LI-ISA) LI-IS (LI-1SAPB1) NGI-01 (NGI-01) NGI-06 (NGI-06) NGI-09 (NGL09) - Plan WGI-09 Plan WGI-09 Wp 2 WGI-09 i ^2 ^ 3 LEGEND ^ 4 AS-STAKED CONDUCTOR ~ EXISTING CONDUCTOR ^ 6 ^ 7 ^ $ ^ 5 WGI PAD NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 2. BASIS OF HORIZONTAL LOCATION IS WGI OPERATOR MONUMENTS, WOA WGI-PAD MONUMENTATION. 3. BASIS OF ELEVATION IS WGI PAD OPERATOR MONUMENTS ELEVATIONS ARE BPX MEAN LOWER LOW WATER (M.L.L.W.) DATUM. 4. MEAN WGI PAD SCALE FACTOR IS 0.9999390. 5. DATE OF SURVEY: OCTOBER 7, 2006. 6. REFERENCE FIELDBOOK: P806-09 PGS. 35-37. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 14 E., UM1AT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION N0. COORDINATES COORDINATE POSITION DMS) POSITION(D.DD) PAD ELEV. OFFSETS WGI-09 Y= 5,972,031.93 N 1,120.00 70'19'42.921" 70.3285892' 17 9, 5,051' FSL ' X= 684,979.04 E -370.00 148'29'58.771" 148.4996586' ' FEL 1,215 r. nwcT~ JACOBS CHECKED: ~^'~ O'HANLEY N DATE: 10/8/06 ~'' DRAWING: SHEET: ~BOS wcI 0,-Oe EOA WGI PAD ~~~O~Q JD9 ND: AS-STAKED CONDUC70R 0 10 8 0 155Um FOR INFORMATION ~ LOH cxaxws .wo wm sw,craxs SCALE: ~ ~ N0. DATE REV15fON BY CHK ~~~~. ~%• aosn 1~= 200• WELL WGI-09 Terri Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF "Mastercard Check" First National Bank Alaska Anchorage, AK 99501 MEMO, '~ ~:1 2 5 200060~:991462271556~~• 0307 • ss-siizs2 307 DATE I ~ • `~ •~ ~ ~ i • • T~tANSMITTAL LE~"~'ER C~IECKLIS'I' WELL tiAME _~ ~l~~--1.~~% PTD# ~_ ~3 ~ - ,l ~.~ Development ~ Service Exploratory Stratigraphic Test Yon-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS TEXT FOR APPROVAL LETTER WHAT j (OPTIONS) APPLIES I ~ ~ MliLTI LATERAL I The permit is for a new wellbore segment of existing wei( (If last two digits in i permit No. , API No. ~0- - _ ;API number are I between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE I In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both j well name ( PH) and API number (~0- - -_) from records, data and logs acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2~.05~. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing ~ exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH i A1[ dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or j from where samples are first caught and 10' sample intervals through target zones. Non-Conventional ~ Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and j implemented a water well testing program to provide baseline data on water quality and quantity. ~Companv Name} must contact the ~ Commission to obtain advance approval of such water well testing program. I Rev: 1 /25/06 C:ljody\transmittal checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY PRUDHOE OIL-64015D _ Well Name: PRUDHOE BAY UN PBU WGI-09 _ Program SER __ Well bore seg 'i..' PTD#:2061460 Company BP EXPLORATION (ALASKA~INC _ _ __ ___ ____ Initial ClasslType SER L1_GINJ___GeoArea ___ ___ Unit ____ __ _ ONOff Shore On Annular Disposal I_~ Administration 1 Permit fee attached Yes X12 Lease numberappropriate _ _ Yes '3 Unique well. name and number Yes ~I4 Well located in adefined pool _ _ _ _ Yes '5 Well located proper distance from_ drilling unit boundary Yes X16 Well located proper dstance_ from. other wells Yes 7 I Sufficienfacreage available in drilling unit_ Yes 18 )f deviated, is wellbore plat_included Yes ~9 operator only affected party Yes 10 Operator has approprate_bond in force Yes 11 Permit_can be issued without conservation order _ _ _ - _ _ _ Yes _ I~12 Permit can be issued without administrative-approval Yes - A r PP Date 13 Can permit be approved before l5-day_wait Yes - RPC 10!12!2006 ~ 14 Well located within area and strata authorized by Injection Order # (put_10# in comments)_(For. Yes A10 4C X15 All wells wiihm 114_mile area of review identified (For service well only) Yes WGI-01;WGI-01A;WGI-02;WGI-06;NGI-O6;NGI-09 L1-15;L1-15A 16 Pre-produced mlector, duration ofpre-production less. than 3 months_(For service well only) N_A 17 Nonconuen, gas conforms to AS3105.030(j.1.A),(j,2.A-D) NA ~ 18 __ _ _ Conductor strmg_ptovided Yes _ _ --- 20" @ 113.. _ Engineer ing 119 Surface casing protects all known_ USDWg Yes II20 C_MT_vol_ adequate to circulate on conductor_& surf_csg - Yes Adequate excess. ~i21 CMT_vot adequate to tie-in long string to surf csg_ Yes ',22 CMT will cover all known-productive horizons_ Yes 23 Casing designs adequate for C, T, B &_permafrost_ _ Yes - 24 Adequate tankage_ot feserve pit Yes _ _ Nabors 27E. 25 If_a_re-drill, has a 10.403 fo_r abandonment been approved N_A_ New well 26 Adequate wellbore separation_proposed Yes ',27 If diverter required., does it meet regulatians_ Yes 28 Drilling fluid program schematic & equip list adequate_ Yes Max MW 9.6 ppg, '29 D BOPES, do they meet regulation Yes WGA 10l 12006 30 BOPE-press rating appropriate; test to (put psig in comments)- - - - Yes Test to 41)00_ psi M$P 2717 psi. 31 Choke_manifgld comp_Iies w1APl RP-53 (May 84)_ _ _ _ Yes 32 ~ Work will occur without operation shutdown_ Yes I33 Is presence_ of H2S gas probable No_ _ _ _ Not an H2$ pad X134 Mechanical condition of wells within AOR verified (For_se[vice well only) Yes All_AOR wells reviewed. X35 Permit can be issued w/o hydrogen sulfide measures No -- - -_ Geology 36 Data presented on potential overpressure zones NA_ '37 Seismic analysis_ of shallow gas zones_ _ _ _ NA _ _ _ _ _ _ _ _ Appr Date ;38 Seabed condition suryey_(ifgff-shore) NA_ RPC 10112!2006 !39 Contact name/phone for weekly_progress reports[explo_ratorygnly] NA . Geologic Engineering Public Commissioner: Date: C issioner: Date Commissioner Date ~~~ iv,~ • • • Well History File APPENDIX Information of detailed nature that is not ~~ particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ~ wgi-09.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 05 16:58:42 2008 Reel Header Service name .............LISTPE Date . ...................08/06/05 Ori9in ...................STS Reel Name. .. ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/06/05 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 w-0004725793 N. WHITE C. CLEMENS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD us..c aoc~- ~u~v scientific Technical Services wGI-09 500292332700 BP Exploration (Alaska) Inc. Sperry Drilling services 05-JUN-08 MWD RUN 2 MWD RUN 3 w-0004725793 W-0004725793 N. WHITE J. PANTER C. CLEMENS B. DECKER 11 11N 14E 5051 1215 50.59 17.69 Page 1 ~fo~l~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 16.000 12.250 8.500 wgi-09.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 20.000 80.0 13.375 4637.0 9.625 8381.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 1 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUNS 2,3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 5 JUNE 2008, QUOTING AUTHORIZATION FROM DOUG STONER (BP). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL WGI-09 WITH API# 50-029-23327-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8891'MD/8582'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER Page 2 ~ ~ FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPX RPS RPM FET GR ROP wgi-09.tapx 1 clipped curves; all bit runs merged. .5000 START DEPTH 261.5 261.5 261.5 261.5 261.5 271.0 313.0 STOP DEPTH 4602.5 4602.5 4602.5 4602.5 4602.5 8855.5 8891.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 261.5 4653.0 4653.5 8385.5 8385.5 8891.0 Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 261.5 8891 4576.25 17260 261,5 8891 RPD MWD OHMM 0.51 716.38 20.222 8683 261.5 4602.5 RPM MWD OHMM 0.47 286.53 15.2497 8683 261.5 4602.5 RPS MWD OHMM 0.53 80.23 9.92355 8683 261,5 4602.5 RPX MWD OHMM 0.59 44.41 6.74552 8683 261.5 4602.5 Page 3 ~ r wgi-09.tapx FET MWD HOUR 0.13 16.94 1.00664 8683 261.5 4602.5 GR MwD API 7.94 419.78 72.3238 17170 271 8855.5 RoP MwD FT/H 5.06 1328.13 148.036 17157 313 8891 First Reading For Entire File..........261.5 Last Reading For Entire File...........8891 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1,0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 261.5 4602.5 FET 261.5 4602.5 RPS 261.5 4602.5 RPM 261.5 4602.5 RPD 261.5 4602.5 GR 271.0 4653.0 ROP 313.0 4653.0 LOG HEADER DATA DATE LOGGED: 19-Nov-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4653.0 TOP LOG INTERVAL (FT): 312.0 BOTTOM LOG INTERVAL (FT): 4653.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 21.7 Page 4 i TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 wgi-09.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order DEPT RPD MWDO10 RPM MWDO10 RPS MWDO10 RPX MWDO10 FET MWDO10 GR MWDO10 ROP MWDO10 units FT OHMM OHMM OHMM OHMM HOUR API FT/H size 4 4 4 4 4 TOOL NUMBER 149206 81797 16.000 80.0 Native/spud Mud 8.90 258.0 8.7 500 7.8 2.000 68.0 1.370 102.2 6.000 68.0 2.600 68.0 Nsam Rep code offset channel 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 261.5 4653 2457.25 8784 RPD MWDO10 OHMM 0.51 716.38 20.222 8683 Page 5 First Reading 261.5 261.5 Last Reading 4653 4602.5 ~ ~ wgi-09.tapx RPM MWDO10 OHMM 0.47 286.53 15.2497 8683. 261.5 4602.5 RPS MWDO10 OHMM 0.53 80.23 9.92355 8683 261.5 4602.5 RPX MWDO10 OHMM 0.59 44.41 6.74552 8683 261.5 4602.5 FET MWDO10 HOUR 0.13 16.94 1.00664 8683 261.5 4602.5 GR MWDO10 API 16.36 101.55 52.1386 8765 271 4653 RoP MWD010 FT/H 5.06 1328.13 180.675 8681 313 4653 First Reading For Entire File..........261.5 Last Reading For Entire File...........4653 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/06/05 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type. .. .........Lo Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4653.5 8385.5 GR 4653.5 8339.5 LOG HEADER DATA DATE LOGGED: 26-Nov-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8385.0 TOP LOG INTERVAL (FT): 4653.0 BOTTOM LOG INTERVAL (FT): 8385.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 23.4 TOOL STRING (TOP TO BOTTOM) Page 6 wgi-09.tapx VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 4637.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 53.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 500 FLUID Loss (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY; HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4653.5 8385.5 6519.5 7465 4653.5 8385.5 GR MWD020 API 7.94 324.82 98.4172 7373 4653.5 8339.5 ROP MWD020 FT/H 5.57 539.18 119.65 7465 4653.5 8385.5 First Reading For Entire File..........4653.5 Last Reading For Entire File...........8385.5 File Trailer Page 7 wgi-09.tapx Service name... .......STSLIB.003 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File TyE~e. .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. .........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8340.0 RoP 8386.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 8855.5 8891.0 Page 8 O1-DEC-06 Insite 72.13 Memory 8891.0 8385.0 8891.0 .1 .3 TOOL NUMBER 59583 8.500 8381.0 Polymer 8.80 60.0 9.3 w9~-09.tapx MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): 7.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8340 8891 8615.5 1103 8340 8891 GR MWD030 API 12.81 419.78 57.3409 1032 8340 8855.5 ROP MWD030 FT/H 11.17 470.41 77.3696 1011 8386 8891 First Reading For Entire File..........8340 Last Reading For Entire File...........8891 File Trailer Service name... .......STSL2B.004 service sub Level~Name... version Number.. ........1.0.0 Date of Generation.......08/06/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Page 9 wgi-09.tapx Service name .............LISTPE Date . ...................08/06/05 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/05 Origin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ~~ scientific Technical Services scientific Technical services Page 10
