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Home My WebLink About206-0527. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU AGI-07A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-052 50-029-22343-01-00 10525 Conductor Surface Intermediate Production Liner 8493 76 3901 9928 676 10523 20" 13-3/8" 9-5/8" 7" 8491 34 - 110 33 - 3934 30 - 9958 9849 - 10525 34 - 110 33 - 3500 30 - 8038 7954 - 8493 none 470 2260 4760 5410 none 1490 5020 6870 7240 9957 - 10523 7-5/8" x 7" L-80 26 - 9857 8037 - 8491 Structural 7" Baker S-3 , 9812 , 7926 7" A-1 , 2132 , 2102 9812 7926 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (9070 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034628 , 0028301 26 - 7722 0 0 171479 283582 0 0 25 25 3380 3407 324-066 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.06.17 15:25:50 -08'00' David Bjork (3888) By Grace Christianson at 4:22 pm, Jun 17, 2024 WCB 9-9-2024 RBDMS JSB 062024 DSR-6/17/24 ACTIVITYDATE SUMMARY 5/19/2024 T/I/O= 2696/8/164 (TUBING WASH/PICKLE) 10 bbls 60/40. 100 bbls 180' Diesel. 405 bbls F-103 into TBG let soak 2 hours. Pump 168 bbls F-103 followed by 15 bbls 60/40. DSO Notified of well status upon departure. SV/SSV/WV = Closed, MV = Open, IA/OA = OTG FWHPs = 397/9/276 Daily Report of Well Operations PBU AGI-07A 10 bbls 60/40. 100 bbls 180' Diesel.() 405 bbls F-103 into TBG let soak 2 hours. Pump 168 bbls F-103 followed by 15 bbls 60/40. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU AGI-07A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-052 50-029-22343-01-00 ADL 0034628 , 0028301 10525 Conductor Surface Intermediate Production Liner 8493 76 3901 9928 676 10523 20" 13-3/8" 9-5/8" 7" 8491 34 - 110 33 - 3934 30 - 9958 9849 - 10525 34 - 110 33 - 3500 30 - 8038 7954 - 8493 none 470 2260 4760 5410 none 1490 5020 6870 7240 9957 - 10523 7-5/8" x 7" L-80 26 - 98578037 - 8491 Structural 7" Baker S-3 7" A-1 9812 / 7926 2132 / 2102 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:47 pm, Feb 08, 2024 324-066 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 13:26:22 - 09'00' Eric Dickerman (4002) MGR13FEB24 DSR-2/13/24 10-404 SFD 2/9/2024*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.28 13:52:55 -09'00'02/28/24 RBDMS JSB 022924 Well Work Prognosis Well Name:AGI-07A API Number:50-029-22343-01 Current Status:Gas Injector Leg: Estimated Start Date:March 1, 2024 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:2060520 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~320,000 Mscf/Day Injection Pressure: 3,450 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): AGI-07 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2018. 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 H2S Value N/A H2S Date N/A Work Desc AFE Date Engineer Phone Job Objective Pump Schedule Stage Fluid Type Pump Into Vol (bbls) Rate (bpm)Max Pres (psi) 1 Spear Methanol / Water TBG 10 1-3 2500 2 Solvent Diesel TBG 100 1-3 2500 3 Over-Flush Fresh Water TBG 600 see below 1800 4 Spear Methanol / Water TBG 15 1-3 1800 5 6 7 Detailed Procedure David Bjork (907) 564-4672 Well AGI-07A GI Water Wash 01/28/24 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 100 bbls of diesel from COTU. -Heat diesel to ~120*F -Order FreshWater to be at ~160*F -Freeze Protect contingent on WSL and ambient temp/seasonal pumping 1.) 10 bbl 60/40 MeOH/water spear 2.) 50 bbls COTU diesel (heated to ~120 deg F)at ~1 to 3 bpm. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 405 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 405 bbls has been pumped, shut-down pumps and let diesel soak across perfs for 2 hours -this should allow ~ 50 bbls of diesel to be pumped into perfs and a remaining 50 bbls to soak outside the perfs. b.) After 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 195 bbls of fresh water with 0.02% F-103 surfactant. 4.) 15 bbls of 60/40 MeOH/water freeze protect. 5.) RDMO. Return well to gas injection. if well isnt going to be POI then FP See ~ pumping time schedule and notesbelow COTU diesel has xylene impurities left, treat with proper safety precautions Clear Well Work Prognosis Pump Time Fluid type vol (bbls)rate (bpm)Time (min) time (hours) methanol 10 1 10 0.17 diesel 100 1.5 67 1.11 FW flush 405 5 81 1.35 Soak 2.00 FW flush 195 5 39 0.65 methanol cap 15 1.5 10 0.17 5.44 Soak Time of Diesel/Xylene 1 2 Diesel/Xylene Notes Note 1 Note 2 Note 3 Hot fluids recommended: Note 1 Fresh Water and Surfactant Notes Note 1 Tubing has gas in it prior to pumping, any fluids pumped first will free fall. Soak time - keep at a minimum of ~2 hours; xylene works best with longer soak times (at least on asphaltenes) SBG treatments have a 3 hour soak time as well (just an FYI) Soak time is really a time for diesel/xylene to seep through the perfs vs pushing/rushing through Max pump rates creates turbulence and has contact with the tubing walls. Also cuts down on time Use COTU "diesel" only in these treatments if available. See Craig Graff explanation below. COTU technically can’t make diesel. On good days it can make Jet A or Heating Oil. Neither meet the specs for diesel. The reason they are different is that they have a lot more aromatics and sulfur in them than diesel. Road diesel and ULSD have most of those bad components taken out, which means that they can only dissolve straight chain hydrocarbons (paraffins), and not aromatics. These will make asphaltenes precipitate instead of cleaning them up.COTU “diesel” has enough things like xylene and toluene left in it to make it a pretty good solvent even for asphaltenes. A real refinery would take all of those out to be sold for higher margins in other products. If COTU "diesel"is not available, use other available diesel and xylene at a 50/50 mixture. As you read diesel in instructions below, can substitue with diesel/xylene If xylene is used for a 50/50 diesel/xylene mixture, heated xylene to 80 deg F or higher, use pump rates of 1 to 1.5 bpm. Injectivity results have improved when all fluids pumped are at warmer temps MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-07A PRUDHOE BAY UNIT AGI-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 AGI-07A 50-029-22343-01-00 206-052-0 G SPT 7926 2060520 1982 3380 3380 3366 3372 228 465 326 255 4YRTST P Adam Earl 6/19/2022 MIT-IA 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 AGI-07A Inspection Date: Tubing OA Packer Depth 77 2249 2201 2198IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622085103 BBL Pumped:2.8 BBL Returned:2.7 Wednesday, July 20, 2022 Page 1 of 1          Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-052 6.50-029-22343-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10525 10523 8491 9812 7926 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 34 - 110 34 - 110 1490 470 Surface 3901 13-3/8" 33 - 3934 33 - 3500 5020 / 5380 2260 / 2670 Intermediate 9928 9-5/8" 30 - 9958 30 - 8038 6870 4760 Production Perforation Depth: Measured depth: 9957 - 10523 feet True vertical depth:8037 - 8491 feet Tubing (size, grade, measured and true vertical depth)7-5/8" x 7" L-80 26 - 9857 9812 7926Packers and SSSV (type, measured and true vertical depth) 7" Baker S-3 Packer Liner 676 7" 9849 - 10525 7954 - 8493 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 33624300 0276094 33 238876 0 3338 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. Sr. Area 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 measured8493 Sundry Number or N/A if C.O. Exempt: 321-270 7" A-1 Injection SSSV 2132 2102 Junk Packer Printed and Electronic Fracture Stimulation Data 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 0034628 & 0028301 PBU AGI-07A 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 11:50:07 -08'00' Bo York RBDMS HEW 6/14/2021 SFD 6/18/2021DSR-6/14/21MGR29JUL2021 ACTIVITYDATE SUMMARY 6/4/2021 T/I/O = 2647/45/199. Temp - 99*. Conduct TBG Water Wash. Pumped 10 bbls 60/40 for Spear. Pumped 50 bbls 120* Diesel into TBG followed with 458 bbls Water w/ F- 103. Allowed well to soak for 2 hours. Pumped 442 bbls water / F-103 followed by 15 bbls 60/40 for FP. Daily Report of Well Operations PBU AGI-07A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:206-052 6.API Number:50-029-22343-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0034628 Property Designation (Lease Number):10. 8. PBU AGI-07A 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 GSTORWAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10525 Effective Depth MD: L-80 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" A-1 Injection SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8493 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9812 , 7926 2132 , 2102 Date: Liner 676 7"9849 - 10525 7954 - 8493 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 33 - 3934 33 - 3500 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 110 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker S-3 Packer 9957 - 10523 8037 - 8491 7-5/8" 29.7# x 7" 26#26 - 9857 Production 10523 8491 none none 34 - 110 470 13-3/8" 9-5/8" Contact Phone:(907)564-4672 Date: 6/1/21 4760 76 149020"Conductor 2260 / 2670 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 3901 5020 / 5380 Intermediate 9928 30 - 9958 30 - 8038 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 3358 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. & 0028301 By Samantha Carlisle at 3:47 pm, Jun 01, 2021 321-270 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.01 15:20:21 -08'00' Stan Golis (880) DLB 06/01/2021MGR02JUN2021 X DSR-6/2/21 10-404 dts 6/3 2021 JLC 6/3/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.03 11:41:41 -08'00' RBDMS HEW 6/4/2021 Well Work Prognosis Well Name:AGI-07A API Number:50-029-22343-01 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:2060520 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: ~240,000 Mscf/Day Injection Pressure: 3,358 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): AGI-07A is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2018. 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. DLB -00 Well Work Prognosis Well Work Prognosis • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg I S1 I P.I.Supervisor t SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. AGI-07A FROM: Adam Earl PRUDHOE BAY UNIT AGI-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J312— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-07A API Well Number 50-029-22343-01-00 Inspector Name: Adam Earl Permit Number: 206-052-0 Inspection Date: 6/5/2018 - Insp Num: mitAGE180605131404 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-07A Type Inj G' TVD 7926 ' Tubing 3380 3373 ' 3381 ' 3382 PTD 2060520 Type Test SPT Test psi 1982 IA 22 2500 2470 2466 BBL Pumped: 3 1BBL Returned: 3.3 OA 208 404 282 ' 231 - Interval 4YRTST P/F P Notes: MIT_ J1JN 22L'It Tuesday,June 12,2018 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o`~~fp- ~~~ Well History File Identifier Organizing (aone> ,,,wo,~d iuummiuiuu o Re,~~~eed~ iuiuui~iuiim RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGITAL DATA ~skettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: /s/ Scanning Preparation .~ x 30 = ~ + ~~- =TOTAL PAGES ~ 1 (Count does not include cover sheet) BY: Maria Date: !s/ Production Scanning III IIIIII IIIII II III Stage 7 Page Count from Scanned File: ~~ (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: ~ ES NO BY: Maria Date: V V /s/ 7.~ Stage ~ If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II') II I II II I (III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc s,):,-7-1----, -2',--,-;---;,-,7,;.:, -f /. 1 / (-\,`I / / r ,, "— .,r „..: at K i — 333 WLst Seven�S Avenue : F GoV'0RNoR SL \ i�ARYI-I L Anchorage Alaska 99 01 3572 -;,----%,,,.:3/ o n 907.779 '433 \0 w, SCANNED JUL 2 2 2014 Javier Farinez Petroleum Engineer ' o `� BP Exploration (Alaska), Inc. (:),., (C/� ✓ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-07A Sundry Number: 314-170 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, til/ Daniel T. Seamount, Jr. Commissioner DATED this 20"day of March, 2014. Encl. V , 3 *' STATE OF ALASKA 1 t { ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS N ,.. , 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Weil❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate 0 \(�V"7U..��//ter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 1+11\v1,01041 i 1,4 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development LTJ, 206-052-0 • 3.Address: Stratigraphic El Service ❑✓ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22343-01-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? • PBU AGI-07A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034628 ' PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10525 - 8493 • 10523 8491 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 76 20"91.5#H-40 36-112 36-112 Surface 3903 13-3/8"68#L-80 32-3935 32-3500.25 5020 2260 Intermediate None None None None None None Production 3924 - 9-5/8"47#NT8OS 33-3957 33-3515.99 6870 4760 Liner 676 7"26#L-80 9849-10525 7953.94-8493.12 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): 9957-10523 8037.42-8491.48 See Attachment See Attachment See Attachment I Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(1t): See Attachment for Packer Depths 7"A-1 Injection SSSV 2132',2102.36' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Ell 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 ,e and corr-ct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name Jay- arinez Title Petroleum Engineer Signature '1� Phone 564-5043 Date 3--1`l—t* Prepared by Gerry Catron 564-4424 � COMMISSION USE ONLY �_�`(% Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .1‘ -\-to Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ I Other: RBDMeSay MAY 10 2014 Spacing Exception Required? Yes ❑ No u Subsequent Form Required: Glc D zj, , APPROVED BY I �2 • q Approved by: ‘ COMMISSIONER THE COMMISSION Date: ` '° .D 3.,' /Z Form 10-403 Revised 10/2012 0 Rife+NtAitlid for 12 months from the date of approval. Submit Form and Attachments in Duplicate 1/19=-1/19=- 3/11 / 14 S-C,� ' GF-3 dao,► -t /,lam-3/x/7 7, O O o 0 0 0 0 0 0 0 0 0 Cp 1 aD CO CO CO Cao CO CO CO CO a0 a0 = J Z J J J J J J J J J Q O 0 0 0 0 0 0 0 0 0 0 0 0 CO CO — - 0) 0) r V- V- V- r•-• C r- r- nr p 0 nt N 0 CO nr [t up up CD t[) U ; 0 0 0 0 0 0 0 0 0 0 0 0 I- CD cr N- N v v CD 0) v v v v 7 nr N Co O N N CO CO N N N N m CO 0 ti N- CO CD N- N- t• Ns CI) Cn m " O• O)) - O COO COO O ON) COO COD - to 0 CA O) 0 0 m U C10 Ch (h t` ti ti N t` t` N CL O _ _ ~ CD 141 Cr) N O O — N 0 O ON) 00 Q CO O) Ch 07 CD CD M O CD O N N- N- N- N N- N- N CO XI N N U) N- N- O) T- N- N M 0 CC) Ch C[) U) N- N CC) U) N 3 CO O C D 0 00 OD t• T- CD 00 T- opQ M co co O) O) N 0) 0) p 2 C a W 0 T- (13 F- CO v CY) N N- N v N Ns N- N CO 0 Q M 00) ch ch Off) Off) N M Off) Off) N N 2 O O o 000 000 0 iCD CDCD C) CD CD = CO F J CO CO 00 00 00 00 QJ 4tJ Z c J J J J J J 1. 4t 0 *k lt rn rn # 4# # *k � N 00 CO CO N N CO CO N N C me Cs1 Ns Ns LUD_ Cr) CO CO N O CO CO CC) 000 CO CO 01 N- ' O) O) Ns N- CD O Ns t` N J CO op Cr) N- N • Z O O rn F- F- W mD 0 0 0 0 0 0 0 0 0 U Q ccQ W Z Z Z Z Z Z Z Z Z W O Ce CO CO m m CO m CO CO 0 acnF- F-- F- F- F- F- Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top Description TVD Top AGI-07A SSSV 2132 7"A-1 Injection SSSV 2102 AGI-07A PACKER 9812 7" Baker S-3 Packer 7926 9861 7" Baker C-2 AGI-07A PACKER Ba e ZAP LTP 7963 TREE 6-3/8"CW WELLHEAD= FMC' y ACTUATOR= BAKER G '-O SAr_.I NOTES:WELL REQUIRES A SSSV. KB.ELEV= 49' BF.ELEV= I I KOP= 3935' 32' —17"X 7-5/8"XO,ID=6.276" Max Angle= 46 @ 3233' Datum MD= 10959' Datum TV D= 8800'SS 2121' H7-5/8"X 7"XO,ID=6.276" I 20"CONDUCTOR,91.5#,H-40 76' 2132' H 7"CAMCO DB-6 SSSV NIP,ID=6.000" 7-5/8"TBG,26#,L-80, IPC VAM TOP 2121' .0459 bpf,ID=6.875" 2144' 1 7"X 7-5/8"XO,ID= 6.276" 13-3/8"CSG,68#,L-80/K-55, ID=12.415" — 3936' (TOP TWO JOINTS=K-55) MILLOUT WINDOW(AGI-07A) 3957'-4020' ESTIMATED TOP OF CEMENT —I 3938' PERFORATION SUMMARY EZSV(05/04/06) 4200' I ��1�•�� REF LOG: ��•••� ANGLE AT TOP PERF: @' ii,it x x•44.41, Note: Refer to Production DB for historical perf data i. 4•••:•4 SIZE I SPF INTERVAL Opn/Sqz DATE �WMIA �••j•1 '�:�.� , �••��• SLOTTED 9957-10523 0 05/26/06 Minimum ID = 5.770" @ 9836' 7" OTIS RN NIPPLE • 7844' H 9-5/8"HES ES CEMENTER • 9779' _—17-5/8"X 7"XO,ID=6.276" 7-5/8"TBG,26#,L-80,IPC VA M TOP, 9779' 9791' —17"OTIS R NIP, ID=5.963" I .0459 bpf,ID=6.875" 111 9812' —9-5/8"X 7"BKR S-3 PKR,ID=6.000" egi III 9836' —17"OTIS RN NIP, ID=5.770" 9-5/8"CSG,47#,L-80,BTC,XO TC-II —1 9833' I-- 9849' — 9-5/8"X 7"BKR C-2 ZXP LTP,ID=6.27" 7"TBG,26#,L-80,TC-II,.0383 bpf, ID=6.276" —1 9857' r : 9857' H MULESHOE,ID=6.184" . 9867' 9-5/8"X 7"BKR HMC II I LNR HGR, ID=6.29" 7"SOLID LNR,26#,L-80,BTC-M,.0383 bpf,ID=6.276" — 9957' I 9-5/8"CSG,47#,L-80, BTC,ID=8.681" 9958' I 1 I 1 I 1 I 1 I 1 PBTD —1 10523' 7"SLTD LNR,26#,L-80, BTC-M, .0383 bpf,ID=6.276" 10523' r••.•1P•V TD H 10525' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/03/93 ORIGINAL COMPLETION WELL: AGI-07A 06/02/06 N27E SIDETRACK"A" PERMIT No:'2060520 06/05/07 JGM/PJC DRLG DRAFT CORRECTIONS API No: 50-029-22343-01 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 36,T12N,R14E, 1271.69'FEL&1056.95'FNL BP Exploration (Alaska) Fullbore Pumping Program for Field Well Name AGI-07 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 3/11/2014 IOR 30 Engineer Bob Chivvis Phone 564-5412 H2S Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume(bbls) Rate (bpm) Max Pressure 1 Pre-Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 200 5 2500 3 Load Select Fluid Type Tbg 600 5 2500 4 Freeze Protect Methanol (60/40) Tbg 10 5 2500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel/xylene 3 800 bbls of fresh water with 0.02% F-103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level(ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level(ft) No Input Depth If Applicable Recent OA Fluid Level(ft) STATE OF ALASKA . ALillk OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L f Water Wash Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: BP Exploration (Alaska), Inc Na me: Development ❑ Exploratory ❑ — 206 -052 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22343 -01 -00 7. Property Designation (Lease Number): 6 8. Well Name and Number: ADL0034628 PBU AGI -07A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10525 feet Plugs measured None feet true vertical 8493.12 feet Junk measured None feet Effective Depth measured 10523 feet Packer measured See Attachment feet true vertical 8491.48 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H-40 30 - 106 30 - 106 - 1490 470 Surface 3907 13 -3/8" 68# L- 80/K -55 29 - 3936 29 - 3500.96 0 0 Intermediate None None None None None None Production 9930 9 -5/8" 47# L -80 28 - 9958 28 - 8038.2 6870 4760 Liner 676 7" 26# L -80 9849 - 10525 7953.94 - 8493.12 7240 5410 Perforation depth Measured depth 9957 - 10523 feet Cfy JpN 2 8 2413 SCANN True Vertical depth 7990.42 - 8444.48 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachmenf — See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: 0 Intervals treated (measured): RECEIVED C Treatment descriptions including volumes used and final pressure: S EP 2 4 2012 13. Representative Daily Average Production or Injection Data AOGCC Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to welt operation: ' 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service IS Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas Q WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ 151 SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -198 Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita ummerhays , Title Petrotechnical Data Technician � Signatur- � � g / A�� _ Phone 564 -4035 Date 9/24/2012 � Form Revised 11!201 { J cEP ! ��` �� 'l V1 - - / fL Submit Original Only �/ • • Daily Report of Well Operations ADL0034628 ACTIVITYDATE SUMMARY o• con lnue• rom - - umpe• • • • s me spear o owe. .y • S • • s S 11 diesel /xylene, 825 bbls FW with surfactant, 10 bbls meth cap, for TBG wash on gas injector. DSO notified Valve positions =SV closed Lateral valve closed WV SSV MV open CVs OTG per DSO 7/13/2012 FWHP = 0/0/260 FLUIDS PUMPED BBLS 100 50/50 DIESEL /XYLENE 20 METH 825 FRESH WATER W/ F -103 SURFACTANT 945 TOTAL . e • Perforation Attachment ADL0034628 Perf Operation Operation Meas Depth Meas Depth TVD Depth TVD Depth SW Name Date Code Top Base Top Base AGI -07A 5/31/06 SL 9957 10523 8037.42 8491.48 0 0 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • • Packers and SSV's Attachment ADL0034628 SW Name Type MD TVD Depscription AGI -07A PACKER 9812 7878.78 7" Baker S -3 Packer AGI -07A PACKER 9849 7906.94 7" Baker C -2 ZXP LTP Casing / Tubing Attachment ADL0034628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 30 - 106 30 - 106 1490 470 LINER 676 7" 26# L -80 9849 - 10525 7953.94 - 8493.12 7240 5410 PRODUCTION 9930 9 -5/8" 47# L -80 28 - 9958 28 - 8038.2 6870 4760 TUBING 9752 7 -5/8" 29.7# L -80 27 - 9779 27 - 7900.63 6890 4790 TUBING 78 7" 26# L -80 9779 - 9857 7900.63 - 7960.04 7240 5410 SURFACE 3907 13 -3/8" 68# L- 80/K -55 29 - 3936 29 - 3500.96 • • 1 TREE = 6 -3/8" CM/ • WELLHEAD = FMC IlkTY NOTES: WELL REQUIRES A SSSV. f ACTUATOR = BAKER AG1-0 7A KB. ELEV = 49' BF.ELEV= I KOP = 3935' I 32' I-I 7" X 7 -5/8" XO, ID = 6.276" 1 Max Angle = 46 @ 3233' Datum MD = 10959' Datum ND = 8800' SS 2121 I- I7 -5/8" X 7 XO, ID = 6.276" I 120" CONDUCTOR, 91.5 #, I-1-40 I 76' I 2132' H7" CAMCO DB -6 SSSV NIP, ID = 6.000 I 7 -5/8" TBG, 26 #, L -80, PC VAM TOP 2121' .0459 bpf, ID = 6.875" 2144' 17" X 7 -5/8" XO, ID = 6.276" 13 -3/8" CSG, 68 #, L -801 K -55, ID = 12.415" -I 3936' I (TOP TWO JOINTS = K -55) / MILLOUT WINDOW (AGI -07A) 3957' - 4020' I ESTIMATED TOP OF CEMENT H 3938' PERFORATION SUMMARY EZSV (05/04/06) -I 4200' I . .Z ■ REF LOG: .:* *: ANGLE ATTOPPERF: @' : 4 :4 • Note: Refer to Production DB for historical pert data \i "Pi i � �� h SIZE I SPF INTERVAL Opn /Sqz DATE O % /M /w 41 1 ��1 ::'� \ �'. is SLOTTED 9957 - 10523 0 05/26/06 Minimum ID = 5.770" @ 9836' 7" OTIS RN NIPPLE • I 7844' H9 -5/8" HES ES CEMENTER I • 9779' H7-5/8" X 7" XO, ID = 6.276" I 7 -5/8" TBG, 26 #, L -80, IPC VAM TOP, 9779' 9791' Hr OTIS R NIP, D = 5.963" 1 .0459 bpf, ID = 6.875" III 9812' _I-I 9-5/8" X 7" BKR S-3 PKR, ID = 6.000" I O 9836' —17" OTIS RN NIP, ID = 5.770" I 19 -5/8" CSG, 47 #, L -80, BTC, XO TC-II H 9833' I- 984g' I- 9 -5/8" X 7" BKR C-2 ZXP LTP, ID = 6.27" 17" TBG, 26 #, L -80, TC-II, .0383 bpf, ID = 6.276" hl 9857' : 9857' Hr MULESHOE, ID = 6.184" I . 9867' I- 9 -5/8" X 7" BKR HMC II LNR HGR, ID = 6.29" 17" SOLID LNR, 26 #, L -80, BTGM, .0383 bpf, ID = 6.276'1-1 9957' ' 1 19 -5/8" CSG, 47 #, L -80, BTC, ID = 8.681" I 9958' 1 1 1 1 1 1 It 1 1 1 PBTD --I 10523' I 17" SLTD LNR, 26#, L -80, BTC-M, .0383 bpf, ID = 6.276" I 10523' ■••••■ 1 TD H 10525' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/03/93 ORIGINAL COMPLETION WELL: AGI-07A 06/02/06 N27E SIDETRACK "A" PERMIT No: 2060520 06/05/07 JGM/PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 22343 -01 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 36, T12N, R14E, 1271.69' FEL & 1056.95' FNL BP Exploration (Alaska) • 3 [F [ r SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bob Chivvis Petroleum Engineer 0 5 BP Exploration (Alaska), Inc. �p P.O. Box 196612 � Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -07A Sundry Number: 312 -198 Dear Mr. Chivvis: Enclosed is the approved Applica4tAt 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. Si r cer - • r n K. Norman Co 'ssioner DATED this day of June, 2012. Encl. STATE OF ALASKA RECEIVED ALA. OIL AND GAS CONSERVATION COMMIAN APPLICATION FOR SUNDRY APPROVALS MAY 3 0 2012 20 AAC 25.280 //►� 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Cllfa4 g •; .0. ("gram ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ x a , Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: WATER WASH 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -0520 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 . 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22343 -01 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No PBU AGI -07A . 0 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 034628 • PRUDHOE BAY Field / PRUDHOE Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10525 . 8493 • 10523 8491 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H-40 30' 106' 30' 106' 1490 470 Surface 3908' 13 -3/8" 68# K- 55/L -80 29' 3937' 29' 3502' 3450 1950 Production 9930' 9 -5/8" 47# L -80 28' 9958' 28' 8038' 6870 4760 Liner 676' 7" 26# L -80 9849' 10525' 7954' 8493' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7 -5/8" 29.7# L -80 27' 9779' - - 7" 26# L -80 9779' 9857' Packers and SSSV Type: 7" BKR S -3 PKR Packers and SSSV MD and TVD (ft): 9812' 7926' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service eg 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/13/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ 0 . WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Chivvis Printed Name Bob Chivvis Title PE Signature Phone Date go/i -T- 564 -5412 5/30/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓I 2 -to Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: i Subsequent Form Required: /e - 4 0 a ) APPROVED BY S"-,� Approved by: COMMISSIONER THE COMMISSION Date: HAAS JUN 06 0R1GINAL ` c1v ,, r4 � T , Form 10-403 Revised 1/2010 f n1 '�. Submit in Duplicate AGI-07A 206 -052 PERF ATTACHMENT . Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base AGI -07A 5/31/06 SL 9,957. 10,523. 8,037.42 8,491.48 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED • MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • TREE = 6 -3/8" CIW WELLHEAD = FMC SAFONOTES: WELL REQUIRES A SSW ACTUATOR = BAKER AGI -07A KB. ELEv = ' .49' BF. ELEV = KOP = 3935' 1 1 1 32' I X 7 - 5/8" XO, ID = 6.276" Max Angle = 46 @ 3233' Datum MD = 10959' - Datum TV D = 8800' SS 2121' 1 - 17 - 5/8" X 7" XO, ID = 6.276" 120" CONDUCTOR, 91.5 #, H-40 I 76' 1 2132' 1-1 7" CAMCO DB -6 SSSV NIP, ID = 6.000" I 7 -5/8" TBG, 26#, L -80, IPC VAM TOP 2121' .0459 bpf, ID = 6.875" 2144' I 7" X 7 -5/8" XO, ID = 6.276" 13 -3/8" CSG, 68 #, L -80/ K -55, ID = 12.415" —I 3936' I J (TOP TWO JOINTS = K -55) MILLOUT WINDOW (AGI -07A) 3957' - 4020' (ESTIMATED TOP OF CEMENT H 3938' PERFORATION SUMMARY 1 EZSV (05/04/06) -1 4200' 1 4** 4 . -4 14 REF LOG: �� /i* A NGLE AT TOP PERF: @ ' •� air \i'llor.,* �r, * Note: Refer to Production DB for historical perf data �\��1�� SIZE 1 SPF INTERVAL Opn /Sqz DATE �°�wc°�,�� 1 SLOTTED 9957 - 10523 0 05/26/06 Minimum ID = 5.770" @ 9836' 7" OTIS RN NIPPLE • 1 7844' I-1 -5/8" HES ES CEMENTER 1 • 9779' H 7 -5 /8" X 7" XO, ID = 6.276" 1 7 -5/8" TBG, 26 #, L -80, IPC VAM TOP, 9779' 9791' H 7" OTIS R NIP, ID = 5.963" 1 .0459 bpf, ID = 6.875" . 9812' — - 5/8" X 7" BKR S -3 PKR, ID = 6.000" 1 /, ,' II 9836' 1—17" OTIS RN NIP, ID = 5.770" 1 19 -5/8" CSG, 47 #, L -80, BTC, X0 TC-II H 9833' 9849' ( — 9-5/8" X 7" BKR C-2 ZXP LTP, ID = 6.27" 1 7" TBG, 26 #, L -80, TC-II, .0383 bpf, ID = 6.276" I 9857' ■ 9857' 1-I 7" MULESHOE, ID = 6.184" 1 ' 1 9867' 1 — 9 -5/8" X 7" BKR HMC i LNR HGR, ID = 6.29" 7" SOLID LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276 "H 9957' 1 k 1 9 -5/8" CSG, 47 #, L -80, BTC, ID = 8.681" i-1 9958' 1 1 1 7" SLID LNR, 26#, L -80, BTC-M, .0383 bpf, ID = 6.276" 1 10523' ∎ PBTD I--1 10523' I ► ∎ i • i • i • i 1 TD H 10525' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/03/93 ORIGINAL COM PLETION WELL: AGI -07A 06/02/06 N27E SIDETRACK "A" PERMIT No: 2060 06/05/07 JGM/PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 22343 -01 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 36, T12N, R14E, 1271.69' FEL & 1056.95' FNL BP Exploration (Alaska) • • 0 0 0 0 a 0 0 O 0 d X = N N N N .c co > to to CU c O . L In _ O u n a a m M 4 0 E — — a. co c N .+ w ° .c c L to o. CD N C1) v 0 s- C N Q) a) 0 O O 0 R a) o c� a) ' - 'a E to 0 c `- 5 > t o 0 7 • , u) to -C o 0 C o W x C m Q to V > _ L to a. in. Q Q . _ ..r c to Q o. > C.) a v n 3 E E ° a a c c U- � . c C 0 r I I a (1) .Q N c . a . � c o a) 0 > X t �. 0 S. O. 0 . a L c ID = .r+ • N N .N O o a) ++ 0 v 1- c F t6 3 to 1- _ E 'a 'E ) _ m o 0 C7 N 0 "a N 0 � c LL u. c - LI to w a _ N C Q. '� 7 _c v v t v o d 3 0 u) 0 c m - u °' a) d ° ' :a C W .c_ �0 4.- m cu o *C./ o o o 0 0 ++ s- m (4- >, CU ca to m CO Z to _.1 ~ tv O 0 d= ++ m o N m 0000 0 CO c U U ti a) d �� COe- � ra .' U a� CD 0 W to .E LL N r N M to t0 a) a N O a. N cc c o >, U CO E N .4.+ L 0 c w 03 u, �• a ) O E d O. r m C Lc J Y N E o v o .1-2. y y _ E ° 0 n. �• _ 4 - N m I 1 1 Q 0 V, t6 a) of r, d O t6 C E 0 . ` u) .T) E, 0 N Q _� a a sZ E a co N CO m = o y c ° a iii - E O O O d d Cl. n n n a c ° U a Cn d .Q 0 N > O O O 0 O - «. d c a) y c m t0 a) ^ a E > m > a> > a S c o N p o p O '3 Y _° Y N N N m o J> d a E U° w w? 5 Y CO d 9- O a 0.) d > O O J = - o O N a Q Q t2 . Q N Y a C C F- > FL u < a o m N a) a) - d = a3 R N o Q a a a a o o ¢ H O a cO CO 0 . ca c 2 w F O CO = E a E 3 .E a. a F_ a O m m 0 m is U ,, O y u a u u m m c c c U v v o a a, N a (1) a a a a C C _ y y a) a1 a) m a) , U c N ` N N N W Z Z C d a 0 a E N F iii lC U U U a s a d (n N N to N Q 1 2 2 2 t i ti m tY tY w w w ¢ N ° a = CL — — o a Q t2 Q . c,. o V a) a) a) a) (1) (1) 0 y a) a) CU p U 03 03 CO 03 03 C13 U U U U U O to to N p N a) O Q a a n Q Q O a) O ..> Z a) a) N a¢aQQ a c � cc� cn z cc V- - a < a a a) 'N as m c Al c 0 ° H- El U w c z a co 1- U . • Fullbore Pumping Program for Field Well Name AGI -07 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 5/29/2012 IOR 30 Engineer Bob Chivvis Phone 564 -5412 H2S 2E, Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. V Diesel / Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush Methanol (60/40) Tbg 10 5 2500 2 Solvent Select Fluid Type Tbg 100 5 I 2500 3 Load Select Fluid Type Tbg 800 5 2500 4 Freeze Protect I Methanol (60/40) Tbg 10 5 2500 5 Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 800 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) _ dimensions mechanical inner capacity outer capacity size lb/ft od id drift id collapse burst bbls /ft ft/bbls bblslft ft/bbls 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 _ 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6.40 3.19 2.81 2.68 11111.00 11111.00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4.500 12.60 4.50 3.96 3.83 7500.00 _ 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 _ 4.89 4.77 6280.00 7740.00 _ 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 26.9 0.04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9.63 8.68 8.53 4760.00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 a Brine Design Notes Revised: 5/1/00 NaCI KC! CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through 8.7 26 8.7 27 9.5 10 9.5 20 permafrost (approx. 2500'). 8.8 24 8.9 23 10.0 -9 10.0 14 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and 8.9 22 9.1 19 10.5 -36 10.5 6 dilute. 9.0 19 9.3 15 10.7 51 11.0 _2 Don't use Ca based fluids that may come in contact with the formation. 9.1 17 9.5 15 10.8 -57 11.5 -11 Be careful using CaCI in IA - may dump on formation. Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine. 9.2 14 9.6 33 10.9 -35 11.7 -16 Note: Inhibitor has a 1 day half -life. 9.3 11 11.0 -19 11.8 -19 Be careful allowing very cold diesel to contact KCI - could form a slush. 9.4 9 11.5 36 11.9 -10 • 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 1 1 1 ao 1 KCI / CaCI zo ! NaCI / ♦'� ♦`' •:�, a / e' NaBr i ° r ' o / • 1 / 0 0 -20 ` it 0 fl o ♦ - NaCI -40 � f -A- CaCI -60 �� --. KCI o NaBr 8.5 9.5 Density, PPG 10.5 11.5 12.5' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue SL ,UUE AUG 0 7 2012 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB AGI ! O Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI 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) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI -03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI-04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 AGI -05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 AGI-06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 -- )PAGI-07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 AGI -08 1930330 50029223480000 1.8 NA 1.8 NA 15.3 7/24/2011 AGI -09 1930350 50029223500000 Spit conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA MEMORANDUM To: Jim Regg ~~ ~ 7~Z~~p P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-07A PRUDHOE BAY UNIT AGI-07A Src: Inspector NnN-CnNFiDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT AGI-07A API Well Number: 50-029-22343-01-00 Insp Num: mitCS100714070650 Permit Number: 206-052-0 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 7/13/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI-07A' Type Inj. G TVD 7926 ~ IA 770 2200 - 2190 2190 P.T.Di 2060520' TypeTest SPT Test psi 1981 QA 260 390 320 280 I11terVal4YRTST p~ P ~Tnbirig 3400 3400 3400 3400 Notes: pre-test pressures were observed for 30+ minutes and found stable. ~l.~lr. ~ ~~ (c9 ~esr 1`~~l ~~ ` Wednesday, July 14, 2010 Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.txooks@a~ska.gov; tom.rnaurtder~a~_gov; doa.aogcc.prudhoe.tyay~alaska.gov OPERATOR: BP Exploration (Alaska}, Inc_ FIELD /UNIT /PAD: Prudhoe Bay /PBU /AGI Pad DATE: 07!13110 OPERATOR REP: Tiffany Quy AOGCC REP: Chuck Scheve Packer Pretest Init~l 75 Min. 30 Min. Well AGI-07 T In". G TVD 7,926' T 3,400 3,400 3,400 3,400 Interval 4 P.T.D. 2060520 T test P Test 1981.5 770 2,200 2,190 2,190 PIF P Notes: AOGCC MIT-IA to 2200 psr f~ 4 y~r t1fC OA 26(T 390 32Q 28(1 Well T In . TVD Tut>! Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test PtF Notes: OA Well T In'_ TVD T Interval P.T.D. T test Test Casi P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water MIT Report Form BFL 11127/07 TYPE TEST Codes M = Annuhis 9 P =Standard Pressure Test R = Irdemal Radioactive Tracer Survey A =Temperature Anortraly Survey D = DAferentiaf Temperature Test MIT PBU AGI-07 07-13-10.x1s ~~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) '~ ° ~-: ~~ ~,,. -~~ ~;~ a ~. ~ ,~~; ,,~ , ,r, ~ ~ r ~x ,~`_ ~ . ~ .. i ,~. ,~ qtr `' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 3 ~ ~.~... DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060520 Well Name/No. PRUDHOE BAY UNIT AGI-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22343-01-00 MD 10525 TVD 8493 Completion Date 5/31/2006 Completion Status 1GINJ Current Status 1GINJ /GIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey es 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 meairrmi rvumper Name scale meaia No Start Stop CH Received Comments D Asc Directional Survey 9368 10525 Open 6/27/2006 ED D Asc Directional Survey 3921 9730 Open 6/27/2006 PB 1 D C Pds 13963 Cement Evaluation 1 50 9800 Case 6/23/2006 USIT/GR/CCL 28-May- 2006 // ~.ED C Lis 13963 vCement Evaluation 1 50 9800 Case 6/23/2006 USIT/GR/CCL 28-May- 2006 Plus Graphics !~°~ C Pds 13963 Cement Evaluation 5 Col 1 50 9800 Case 6/23/2006 USIT/GR/CCL 28-May- i 2006 ~IE~D C Pdf 13982 Gamma Ray 1-4 3931 10525 Open 7/19/2006 DGR, BAT 12-May-2006 w/EMF Graphics **On CD the TVD Version is actually a MD version" D C Pdf 13982 Neutron 1-4 3931 10525 Open 7/19/2006 DGR, CTN, ALD 12-May- 2006 w/EMF Graphics / ~ ED C Pdf eutron 13982 1-4 3497 8494 Open 7/19/2006 DGR, CTN, ALD 12-May- 2006 w/EMF Graphics ED C Pdf 13983 Gamma Ray 1-2 3931 9730 Open 7/19/2006 DGR w/ EMF Graphics 12- May-2006 PB1 D C Pdf 13983 Gamma Ray 1-2 3498 7839 Open 7/19/2006 DGR w/ EMF Graphics 12- May-2006 PB1 C Lis 13983 Induction/Resistivity 0 0 Open 7/12/2006 P61 w/ Graphics ~D C Lis 13982 Induction/Resistivity 0 0 Open 7/19/2006 LIS I tXED C Lis 13984a/I~nduction/Resistivity 0 0 Open 7/19/2006 LIS PB1 w/Graphics Rpt 13984 Induction/Resistivity 0 0 Open 7/19/2006 LIS P61 w/Graphics ~D C Lis 13986~nduction/Resistivity 0 0 Open 7/19/2006 LIS ~ED C Asc 13986 Induction/Resistivity 0 0 Open 7/19/2006 Text ~J DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060520 Well Name/No. PRUDHOE BAY UNIT AGI-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22343-01-00 MD 10525 TVD 8493 Completion Date 5/31/2006 Completion Status 1GINJ Current Status 1GINJ UIC Y Rpt 13986 Induction/Resistivity _ 0 0 Open 7/19/2006 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMA N Well Cored? Y Daily History Received? N Chips Received? ~fi'hr~ Formation Tops ~/ N Analysis "f9'I~- Received? Comments: Compliance Reviewed By: _ __ Date: __ d' ~ MEMORANDUM To: Jim Regg --} _ P.I. Supervisor %C-:'~'L: ~'~ ~~ 1~~1, ~.~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 12, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-07A PRUDHOE BAY UNIT AGI-07.4 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.~ Comm Well Name: PRUDHOE BAY UNIT AGI-07A Insp Num: mitJJ060711203553 Rel Insp Num API Well Number 50-029-22343-01-00 Permit Number: 206-052-0 Inspector Name• Jeff Jones Inspection Date: 7/6/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI-07A Type IRS. '~ G ~ 'I'~7D ' 7925 ~ IA ~ 0 ~ 2100 ~ 2070 ~ 2065 ~ P ~ ~ 2060520 ~!TypeTCSt ~ SPT ~ Test psl ~ 1981.25 ~ OA ~ 200 ~ 380 260 ~ 220 Interval ~T~- P/F P Tubing! 3490 ~ 3490 ~ 3475 3490 Notes 3.5 bbls methanol pumped. 1 well house inspected; no exceptions noted. Wednesday, July 12, 2006 Page 1 of 1 -TREE W~ HEAU= FMC ACTUATOR= BAKERC KB. ELEV = 33.60' BF. E1EV = 30.30' KOP = Y 3938' Max Angle = Datum MD = 46 @ 3235' 10525' Datum TV D = 8494' • AG I-0 ~/"~ 13-318" CSG, 68#, L-80, ID = 12.415" ( 3936' 13-3/8" CSG, 68#, K-55, ~~~ (TOP TWO JOINTS) Minimum tD = 5.770" @ 9836' 7" OTIS RN NIPPLE TOP OF 9 5/8" 4020' s 5r8" ¢sv 4200' Top of 7" 9590' TOP OF 7" LNR t~ 10129' 9-518" CSG, 47#, NT-80-S, !D = 8.681" 10306' ,: 7 5/8" TBG, 29.7#, L-80-IPC, VAM TOP HC, ID = 6.875", 0.0459 BBLlFT 9 5(8" HES CEMENTER W/ x- 7844' over TGII TO BTC it I 9779, 7 5/8" x 7" 26#TC-!! TO VAM TOP HC XO - 9782' 7" OTIS R Nipple, ID = 5.963" 9812' 9 5!8" x 7° Baker S-3 Pkr, 7" ~, 26# TGII, ID = 6.059" 9836' 7" OTIS RN Nipple, ID = 5.770" 7" HMC Liner hanger/ ZXP 9850' Packer w / 11.6' TBS (7.5" fD) 26# BTC 9856' T' 26# TGII Mule Shoe 9 5/8" CSG, 47#, L-80, 9958' TGII, ID = 8.681", 0.07321 BBL/FT 995T T' 26# L-80 F~rforated ~- iQ523' 7" 2G# L-80 10525' 7" 26# TD 7" LNR, 29#, NT-80-S 11013' DATE REV BY COMMENTS DATE REV BY COMMENTS 05103/93 ORIGINAL COMPLETION 11/01!05 PGS Proposed Sidetrack 06/01/06 CPC Actual Cpmpletion PRUDHOE BAY UNIT WELL: AGI-07A PERMIT No: 206-252 API No: 50-029-22343-01 SEC 36, T12N, R14E, UM 2292' FSL, 2516' FEL BP Exploration {Alaska) AFEfY NOTES: 7-5/8" Vam Top HC is IPC. ' Perforated Liner. RHC-M plug is set in 7" Otis RN Nipple @ 9836' 2121' 7 5/8" x 7" XO (ID 6.250"} w / 7" 26# TGIF Pup _ 2132' 7" OTIS DB-6 SSSV NIP, ID = 6.0" TC-11 2144' 7" x 7 5!8" XO (ID 6.184"} w / 7" 26# TGII Pup WELL LOG TRANSMITTAL • To: State of Alaska July 12, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : AGI-07A &AGI-07A PB1, AK-MW-4315456 AGI-07A: Digital Log Images(CGM, EMF, PDF &LIS DATA): 1 CD Rom 50-029-22343-01 AGI-07A PB1: Digital Log Images(CGM, EMF, PDF &LIS DATA): 1 CD Rom 50-029-22343-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signed: ~,. ~~ ~0(o-oSa ~ 139~a ~ i39~s3 ~ • WELL LOG TRANSMITTAL To: State of Alaska July 12, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: AGI-07A PB 1, AK-MW-4315450 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-223 43 -70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~- Signed: ®`~ 2v~ _~ ~ t39~s~f • • WELL LOG TRANSMITTAL To: State of Alaska July 7, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: AGI-07A, AK-MW-431545 1 LDWG formatted CD Rom with verification listing. API#: 50-029-22343-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signed: C_ d 2o~O -05 a ~ ~ 3 ~ ~~ • r~ LJ 14-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well AGI-07A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,368.43' MD Window /Kickoff Survey: 10,469.73' MD (if applicable) Projected Survey: 10,525.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 _ ~ Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich ~~~~ Survey Manager '~ Attachment(s) JUN ~ ~ 'r?Of " ~ ~t X03 COt15. Ci0~1i 3 ~,,:~ i~,' Anchorage a,D(. - 0 S ~ • • 14-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well AGI-07A PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and "`.PDF files. Tie-on Survey Window /Kickoff Survey: 9,649.74' MD (if applicable) Projected Survey: 9,730.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 _ Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 3,921.25' MD JUN 2 '7 2006 ~~ ~ mmission o~oC~ - oS~. STATE OF ALASKA - ALAS~OIL AND GAS CONSERVATION CO ISSION JUN 2 2 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Gormnission Anchorage. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoaACZS.,os zoAnczs.,,o ®GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory O Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5/31/2006 12. Permit to Drill Number 206-052 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/13/2006 13. API Number 50-029-22343-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/26/2006 14. Well Name and Number: PBU AGI-07A 2292 FSL, 2516 FEL, SEC. 36, T12N, R14E, UM Top of Productive Horizon: 1395' FNL, 2242' FEL, SEC. 31, T12N, R15E, UM g, KB Elevation (ft): 47' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1318' FNL, 1968' FEL, SEC. 31, T12N, R15E, UM 9. Plug Back Depth (MD+TVD} 10525 + 8493 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688758 y- 5979929 Zone- ASP4 10. Total Depth (MD+TVD) 10525 + 8493 Ft 16. Property Designation: ADL 034628 TPI: x- 693856 y- 5981653 Zone- ASP4 Total Depth: x- 694129 Y- 5981737 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: 1 W h if ff h 20 Thi k f P f t 18. Directional Survey ®Yes ^ No ater dept , ore 9. o s N/A MSL ros . c ness o erma 1900' (Approx.) 21. Logs Run: MWD DIR / GR /PWD, MWD DIR / GR /PWD, USIT 2 ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT SIZE WT, PER FT. GRADE OP TTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 30' 106' 30' 106' 30" 11 ds Arcticset 13-3/8" 68# K-55 / L-80 34' 3937' 34' 3502' 16" 2604 cu ft PF'E', 460 cu ft Class'G' 9-5/8" 47# L-80 30' 9958' 30' 8038' 12-1/2" 489 sx Litecrete, 2188 sx Class 'G' 7" 26# L-80 9849' 10525' 7954' 8493' 8-1/2" Uncemented Slotted Liner 23. Perforations open.to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD} 7" Slotted Section 7", 26# x 7-5/8" 29.7#, L-80 9857' 9812' MD TVD MD TVD 995T - 10523' 8037 -8491' 2rj, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED Freeze Protected with 100 Bbls Diesel 26• PRODUCTION TEST Date First Production: June 10, 2006 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 Flow 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". /°' $ 9q None T CO~iPL~`r10At ~ o r t.(~Nt/~'~ `l ~~~~~.~ y/ ! ~~ ~ ft~ BFL Sulu 2 Zoos Form 10-407 Revised 12/2003 ~ ~ ~ (-•~ ~ f~T IUED ON REVERSE SIDE 28. GEOLOGIC MARK 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". Ugnu 4 5820' 4915' None Ugnu 4A 5859' 4944' Ugnue 3 6431' 5379' Ugnu 1 7027' 5840' West Sak 2 7724' 6338' West Sak 1 7890' 6462' Colville Mudstone 3 8045' 6582' Colville Mudstone 2 8874' 7218' Colville Mudstone 1 9214' 7480' H RZ 9712' 7850' LCU 9965' 8044' 42S6 /Zone 4A 10023' 8089' Top CGL /Zone 3 10045' 8107' Base CGL 10135' 8178' 23SB /Zone 2B 10210' 8238' 22TS 10240' 8262' 21TS /Zone 2A 10278' 8293' Zone 1 B 10392' 8385' TDF /Zone 1A 10426' 8412' Base Sadlerochit 10452' 8434' 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. h / d~ Signed 0 ~ Title Technical Assistant Date ~7 Terrie Hubble PBU AGI-07A 206-052 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling engrneer: Shane Gagliardi, 564-5251 INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 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 Operations Summary Report Page 1 of 18 Legal Well Name: AGI-07 ' Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours Task ~ Code NPT Phase ~ Description of Operations 4/26/2006 15:00 - 00:00 9.00 RIGU P DECOMP Accepted Rif at 1500 hrs, 4/26/06. Clean and Organize Rig and Conduct House Keeping Prior to Commencing Operations 4/27/2006 00:00 - 03:00 3.00 RIGU P DECOMP Clean and Organize Rig, Perform House Keeping Prior to Commencing Rig Operations 03:00 - 05:00 2.00 WHSUR P DECOMP PJSM; 7" x 9-5/8" Annulus Pressure 400 psi, Tubing Pressure 400 psi. R/U DSM Lubricator and Pull BPV. R/D Lubricator. 05:00 - 09:00 4.00 WHSUR P DECOMP R/U High Pressure Lines to Circulating Manifold and Tree. 09:00 - 09:30 0.50 WHSUR P DECOMP Bled Down Annulus to 0 psi. Volume Back 1.6 bbl. 09:30 - 13:30 4.00 WHSUR P DECOMP Circulate Seawater Through Manifold to Gas Buster. Leak in Gas Buster Line-Repaired. Pressure Test Lines to 3,500 psi. Union Leaking on Mudline Jumper Hose Union. Attempt to tighten -retest, no success. Break out and inspect need to replace. 13:30 - 14:00 0.50 W HSUR P DECOMP Held Discussion with Anchorage Team on Annulus Pressure. Removed Mudline Hose. Decision was Made to Change Out Seawater for 9.3 ppg KCL Brine 14:00 - 18:00 4.00 WHSUR N WAIT DECOMP Wait on 9.3 ppg KCL Brine 18:00 - 20:00 2.00 WHSUR P DECOMP R/U Injection Line for Well Kill Operations 20:00 - 21:00 1.00 W HSUR P DECOMP Pump 20 bbls Seawater to Fill Lines and Gas Buster. Test Lines to 250 psi low / 3,500 psi high. 21:00 - 22:00 1.00 WHSUR P DECOMP Pump 100 bbls Down Annulus at 3 bpm Holding 400 psi Back Pressure on Choke. Taking Diesel Returns from Tubing to Cuttings Tank 22:00 - 00:00 2.00 WHSUR P DECOMP Circulate 9.3 ppg KCL Brine Down Tubing at 5 bpm Holding Constant Bottom Hole Pressure of 400 psi. 4/28/2006 00:00 - 01:30 1.50 WHSUR P DECOMP Circulated Surface to Surface 9.3 ppg KCL Brine Down Tubing at 5 bpm Holding Constant Bottom Hole Pressure of 400 psi. to Kill Well. At Completion of Kill Operations Well Bore Pressure 0 psi. 01:30 - 02:00 0.50 WHSUR P DECOMP Monitor Well-Static 02:00 - 03:00 1.00 WHSUR P DECOMP Blow Down Circulating Lines. R/D Lines from Tree 03:00 - 05:00 2.00 WHSUR P DECOMP Remove Tree Cap and Install TWC. Install Tree Cap and Pressure Test TWC from Below to 250 psi. Bled Down Pressure. Blow Down All Lines 05:00 - 09:00 4.00 WHSUR P DECOMP Held PJSM; N/D Tree and Adapter Flange. Inspec Hanger Threads. Threads in Bad Shape, Will Use Spear to Pull Tubing. Take Well Head Measurements, RT-TS = 28.00', RT-CS = 30.30', RT-GL = 33.50' 09:00 - 12:00 3.00 BOPSU P DECOMP Held PJSM; Inspect Bridge Crane. P/U BOPE Stack from Cellar Pedestal and Position On Tubing Head. Install Flange Bolts and BOPE Securing Cables 12:00 - 16:30 4.50 BOPSU P DECOMP Open Lower Ram and Blind Ram Cavities. Inspect 3-1/2" x 6" Variable and Blind Shear Rams. Both Sets in Good Condition. C/O Upper Rams to 4-1/2" x 7" Variables 16:30 - 21:30 5.00 BOPSU P DECOMP Held PJSM; Remove Top of GL Hydril Annular, C/O Element, Replace Top of Annular. Tighten All Ram Doors 21:30 - 23:00 1.50 BOPSU P DECOMP Held PJSM; Remove BOPE Securing Cables, Attach Bridge Crane to BOPE's, Remove Lower Flange Bolts, Set BOPE's Back on Cellar Pedestal. 23:00 - 00:00 1.00 BOPSU P DECOMP Install 13-5/8" Drilling Spacer Spool on Tubing Head 4/29/2006 00:00 - 06:00 6.00 BOPSU P DECOMP Held PJSM; Pick BOPE Stack from Cellar Pedestal and Set on Drilling Spool. Install Flange Bolts. Torque Bolts on Upper and Lower Drilling Spool Flanges. Connect Kill and Choke Lines Printed: 6/5/2006 11:44:05 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 4/29/2006 06:00 - 10:00 10:00 - 14:00 AGI-07 AGI-07 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 27E Hours Task Code 4.00 BOPSU P 4.00 BOPSU N 14:00 - 00:00 10.00 BOPSU N 4/30/2006 00:00 - 03:30 3.50 BOPSU N 03:30 - 04:30 I 1.00 I BOPSUR P 04:30 - 05:00 0.50 BOPSU~ P 05:00 - 05:30 0.50 BOPSU P 05:30 - 07:00 1.50 BOPSU~ N 07:00 - 07:30 0.50 BOPSU P 07:30 - 09:30 2.00 BOPSU~ P 09:30 - 12:00 2.50 BOPSU P 12:00 - 13:30 1.50 BOPSU~ N 13:30 - 00:00 10.50 BOPSU P Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Page 2 of 18 Spud Date: 5/13/2006 End: 5/31 /2006 NPT Phase I. Description of Operations DECOMP Charge Accumulator System, Close Blind Rams, Installed Drilling Riser and Flowline. Air Boot Leaked Between Annular and Riser. SFAL DECOMP N/D Flowline and Drilling Riser, C/O Air Boot, N/U Riser and Flowline RREP DECOMP Rebuild High Pressure Mudline Between Substructure and Pit Complex RREP DECOMP Rebuild High Pressure Mudline Between Substructure and Pit Complex. Test to 4,500 psi DECOMP Open Lower Ram Door and Check Ram Activation for Interference with DP Test Joint Tool Joint. No Interference. Close Ram Door and Secure DECOMP R/U BOPE Test Equipment DECOMP Perform Full Body Test on Stack and Choke Manifold, 250 psi low / 4,000 psi high. Door Seal on Blind Rams Failed. Bled Down All Pressure to Opsi. SFAL DECOMP Replaced Driller Side Blind Ram Door Seal DECOMP Perform Full Body Test on Stack and Choke Manifold to 250 psi / 4,000 psi. DECOMP R/U Test Joint, Connect Testing Manifold and Equipment DECOMP Test 13-5/8" 5,000 psi BOPE, Choke Manifold, Floor Safety Valves and TOP Drive IBOP's to 250 psi low / 4,000 psi high. Annular Tested to 250 psi low / 3,500 psi high. All Tests Held 5 min Each. Test W itnessed by Lou Gramaldi - AOGCC Rep. Bill Decker, Rodney - WSL. and Allen Lunda, Charles Richards Nabors Toolpusher. Test #1. Upper Pipe Rams, Kill HCR, Choke Vlaves #1 & #2 Test #2. Manual Kill, Choke Valves #4, #5 & #6 Test #3. Choke Valves # 8 & #9 Test #4. Choke Vlave #3-Failed Test #5. Choke Valve #7-Failed Test #6. Choke Valves #11 & #12- Off Drillers Side Top Pipe Rams Door Seal Failed SFAL DECOMP Replaced Off Drillers Side Top Pipe Ram Door Seal DECOMP Continue with BOPE Test Test #6. Choke Valves #11 & #12 Test #7. Choke Valves #13, #14 & #15 Test #8. Manual Choke Test #9. Annular Test #10 P/U 7" Test Joint, Upper Pipe Rams. Test #11 7" Test Joint, Annular Test #12 Blind Rams, Retest Choke Valve #3 Test #13 Restest Choke Valve #7 Test #14 Floor Dart Valve Test #15 Floor Safety Valve Test #16 Lower IBOP-Failed-Replaced-Retested Test #17 Upper IBOP Accumulator Test Initial Pressure 3,200 psi After Closure 1,900 psi 200 psi Recovery 27 sec. Full recovery 1 min 45 sec. Nitrogen Btls 8 at 2,425 psi Avg Printed: 6/5/2006 11:44:05 AM • BP EXPLORATION Legal,IVell Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/1/2006 00:00 - 01:00 01:00 - 01:30 01:30 - 02:30 02:30 - 03:00 03:00 - 04:30 Operations Summary Report AG I-07 AG I-07 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 27E Hours 1.00 0.50 1.00 0.50 1.50 Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Task Code NPT Phase N N N N P 04:30 - 06:00 1.50 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 08:00 1.50 PULL P 08:00 - 08:30 0.50 PULL P 08:30 - 09:00 0.50 PULL P 09:00 - 11:00 2.00 PULL P 11:00 - 12:30 1.50 PULL P 12:30 - 17:30 5.00 PULL N 17:30 - 22:30 5.00 PULL P 22:30 - 23:00 0.50 PULL P 23:00 - 00:00 1.00 PULL P 5/2/2006 00:00 - 00:30 0.50 PULL P 00:30 - 15:00 14.50 PULL N 15:00 - 17:30 2.50 PULL P 17:30 - 18:30 1.00 PULL P 18:30 - 20:30 2.00 PULL N 20:30 - 00:00 3.50 PULL P 5/3/2006 00:00 - 01:30 1.50 PULL P 01:30 - 03:30 2.00 PULL N 03:30 - 07:30 I 4.001 PULL I P 07:30 - 08:30 1.00 PULL P 08:30 - 09:30 1.00 WHSUR P 09:30 - 11:00 1.50 CLEAN P 11:00 - 13:00 2.00 CLEAN P Page 3 of 18 Spud Date: 5/13/2006 End: 5/31 /2006 Description of Operations SFAL DECOMP Replace Lower Top Drive IBOP SFAL DECOMP Test Lower Top Drive IBOP to 250 psi low / 4,000 psi high HMAN DECOMP M/U Choke Line Directioanl Flow Block HMAN DECOMP Test Choke Line to 250 psi low / 4,000 psi high DECOMP Install Lubricator Extension. P/U and M/U DSM Lubricator. Check 7" x 9-5/8" Annulus Pressure, 0 psi. Pull TWC. R/D Lubricator. DECOMP P/U and M/U Baker7", 26# Spear dressed with DBL 6.220" Grapples & Circ. Cups. DECOMP RIH with Baker Spear Assy. and Engage 7" Tubing below Hanger. P/U to 100,00 Up Wt. to Check Grapple Integrity. BOLDS. P/U to 260,000# Up Wt., Hanger Unseated, at 292,000# String Pulled Free. Continous Pull of 240,000# to Pull hanger to Rig Floor. DECOMP Circulate Surface to Surfagce with 9.3 ppg Brine at 7-1/2 bpm at 1,030 psi. Loss 30 bph While Circulating. R/U Control Line Spooler While Circulating DECOMP Monitor Well-6 bbl Loss per/hr DECOMP B/O Spear Assy. UD Spear Assy and 1 Joint DP DECOMP PJSM; R/U Casing Tongs, Single Line Compensator, C/O Bails and Install 7" Elevators DECOMP PJSM; Held Training Session on Pulling Tubing and Working with Single Joint Compensator. Pull 7 Jts 7" 26# NT-80-S-IPS NSCC Tubing RREP DECOMP Pipe Skate Hyd. Pipe Ejector Cylinder Failed. Replace Cylinder DECOMP POH with 7" 26# NT-80-S-IPC NSCC Tubing. B/O and UD SSSV. 54 Full Joints UD. Recovered 29 SS Control Line Bands. R/D and UD Camco Spooling Unit. DECOMP Conducted BOP Drill While Pulling Casing. Held Post-Op Review of Drill with All Personnel Involved. DECOMP POH with 7" 26# NT-80-S-IPC NSCC Tubing DECOMP Pull 7" 26# NT-80-S-IPC NSCC Tubing, UD 66 Joints Total RREP DECOMP Pipe Skate Broke, Love Joy Coupling between Electrical Drive Motor and Hyd. Drive Pump. Replaced. Functioned Tested Skate before Continuing Operations DECOMP Pull 7" Tubing, UD 105 Joints Total DECOMP Service Top Drive, Blocks, Crown, Ironroughneck. RREP DECOMP Troubleshoot Stabbing Board Winch. Winch Drive Motor Failed. Safe Out Stabbing Board Man Basket in Stationary Postion. DECOMP Pult 7" Tubing, UD 155 Joints Total DECOMP Pull 7" 26# NT-80-S-IPC NSCC Tubing, UD 172 Joints Total RREP DECOMP Repaired Coupler on Pipe Skate. Coupler Shifted on Drive Shaft, Removed Coupler, Redressed and Reinstalled DECOMP Pull 7" Tubing, Recovered 239 Joints Total, 1 ea. 15' Cut Off Joint and SSSV Assy. DECOMP R/D Casing Tongs and Single Joint Compensator, Remove Casing Equipment from Rig Floor DECOMP Install 5" Elevators, P/U Test Joint, M/U Wear Ring Running Tool. Installed Wear Ring, RILDS. B/O Running Tool and UD Test Joint DECOMP R/U Schlumberger Unit. Hang Sheaves and String E-Line. DECOMP M/U 8.5 Gauge Ring /Junk Basket, RIH on E-Line to 4,400'. Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Page 4 of 18 Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABORS 27E Rig Number: 27E Date From - To Hours Task Code NPT Phase Description of Operations 5/3/2006 11:00 - 13:00 2.00 CLEAN P DECOMP POH and Recovered 1 SS SSSV Contol Line Band 13:00 - 14:30 1.50 DHB P DECOMP M/U Halliburton 9-5/8" EZSV Bridge Plug and Set at 4,200'. POH with E-line. 14:30 - 15:30 1.00 CASE P DECOMP R/U Test Chart and Test 9-5/8" Casing and Bridge Plug to 3,500 psi. Held 30 min. 15:30 - 16:30 1.00 DHB P DECOMP R/D Schlumberger E-Line Tools and Equipment 16:30 - 17:30 1.00 PULL P DECOMP Remove Elevators, C/O Bails, Install Elevators 17:30 - 18:30 1.00 DEMOB P DECOMP Service Top Drive, Blocks and Crown 18:30 - 19:00 0.50 STCTPL P WEXIT Held PJSM; M/U Baker 9-5/8" Casing Cutter. M/U Top Drive and Circulated at 2 bpm to Function Test Cutter Blades. 19:00 - 00:00 5.00 STCTPL P WEXIT RIH with 9-5/8" Casing Cutter on 5" DP to 2,340'. P/U DP 1 x 1 from Pipeshed 5/4/2006 00:00 - 03:00 3.00 STCTPL P WEXIT RIH with 9-5/8" Casing Cutter on 5" DP and Tag EZSV at 4,200'. P/U DP 1 x 1 from Pipeshed 03:00 - 04:00 1.00 STCTPL P WEXIT Established Parameters; UP WT 122,000#, DN WT 120,000#, RT WT 120,000#, Pump 1,340 psi at 6 bpm. P/U to 4,010'. Engage Pumps at 47 spm, 813 psi. S/O to 4,035', Did Not Find Collar, P/U to 4,005', Increase Pump to 900 psi, 50 spm, S/O and Found Collar at 4,020'. Shut Down Pumps, S/O to 4,040'. Engage Rotary, Slowly Increasing RPM to 60, Bring Pumps up to 60 spm at 1,450 psi. Torque 6,000 / 7,000 fUlbs. When Cutters Penetrated 9-5/8" Casing Torque Dropped Down to 4,000 fUlbs. RPM's Increased to 65. Shut Down Pumps and Rotary. 04:00 - 05:00 1.00 STCTPL P WEXIT Monitored 9-5/8" x 13-3/8" Annulus for Pressure, 0 psi. Closed Annular and Try to Establish Circulation. Slowly Pressure Up to 750 psi. No Returns. Bled Down Pressure to 0 psi. Open Annular. 05:00 - 05:30 0.50 STCTPL P WEXIT POH to 3,880'. Repeat Casing Cutting Process. 05:30 - 07:30 2.00 STCTPL P WEXIT Montiored OA for Pressure, 0 psi. Close Annular and Try to Establish Circulation W/O Success. R/U to Reverse Circulate Down OA Taking Returns Up IA. Pressure Up to 650 psi on OA. Held 5 min. No Bleed Down. Pressure Up to 1,500 psi. Held 5 min. No Bleed Down. Bled Down All Pressures to 0 psi. Monitor Well 16 bph Losses. Blow Dn All Lines. 07:30 - 10:00 2.50 STCTPL P WEXIT POH with 5" DP 10:00 - 10:30 0.50 STCTPL P WEXIT Monitor Well, Fill Trip Tank, Function Tested BOPE's 10:30 - 11:00 0.50 STCTPL P WEXIT B/O and L/D 9-5/8" Casing Cutter 11:00 - 13:00 2.00 STCTPL P WEXIT Change Out Top Pipe Rams to 9-5/8". Monitoring Losses with Blind Rams Closed Circulating Across the Top of the Hole with Rig Pump 13:00 - 13:30 0.50 STCTPL P WEXIT P/U 5" Test Joint and Pull Wear Ring. L/D Test Joint 13:30 - 14:30 1.00 STCTPL P WEXIT P/U 9-5l8" Test Joint and Test Plug. Install Plug and Joint 14:30 - 15:30 1.00 STCTPL P WEXIT R/U BOPE Testing Equipment. Tested 9-5/8" Rams to 250 psi low / 3,500 psi high. Held Tests for 5 min Each. R/D Test Equipment, Test Witnessed by WSL Chris Clemens. 15:30 - 16:00 0.50 STCTPL P WEXIT L/D Test Joint and Test plug 16:00 - 18:00 2.00 STCTPL P WEXIT P/U 2 Joints 5" DP and M/U Baker Spear Assy Addressed with a Single Grapple for 9-5/8" 47# Casing. Torqued All Connections on Assy as per Baker Rep. 12.74' BHA Length 18:00 - 20:00 2.00 STCTPL P WEXIT Spear 9-5/8" Casing, BOLDS. P/U.to 140,000# to Ensure Spear Engaged. S/O to 40,000#, P/U to 250,000#, Functioned Lock-Down Screws, All Moved Freely. S/O to 40,000#, P/U to Printed: 6/5/2006 11:44:05 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 5 of 18 AGI-07 AGI-07 Spud Date: 5/13/2006 REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 NABOBS 27E Rig Number: 27E Date I From - To I Hours I Task Code 5/4/2006 18:00 - 20:00 20:00 - 21:00 21:00 - 22:30 22:30 - 00:00 5/5/2006 5/6/2006 00:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 08:00 08:00 - 10:00 10:00 - 11:00 11:00 - 13:30 13:30 - 14:00 14:00 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 21:30 21:30 - 22:00 22:00 - 00:00 00:00 - 05:00 05:00 - 05:30 2.00 STCTPL P 1.00 STCTPL P 1.50 STCTPL P 1.50 STCTPL P 4.50 STCTPL P 1.00 STCTPL P 0.50 STCTPL P 0.50 STCTPL P 1.00 STCTPL P 0.50 STCTPL P 2.00 STCTPL P 1.00 STCTPL P 2.50 STCTPL P 0.50 STCTPL P 2.50 STCTPL P 0.50 STCTPL P 1.00 STCTPL P 1.001 STCTPL I P 0.50 STCTPL P 2.00 STCTPL P 0.50 STCTPL P 2.00 STCTPL P 5.00 STCTPL P 0.50 STCTPL P NPT ~ Phase L j Description of Operations 1 __ - - _ WEXIT - _ _ __- - --- 300,000#, No Pipe Movement, Increased Up Wt to 350,000#. Pipe Moved 6". S/O to 40,000#. Work Pipe from 40,000# to 400,000#. With 400,000# Up Wt Measured 19" Pipe Stretch. Baker Calculations Susgests Pipe Stuck Around 3,500'. Work Pipe from 40,000# to 450,000# While Waiting on Schlumberger E-Line Unit. WEXIT Set 9-5/8" Pack-Off Back into Wellhead and RILDS. Released Spear, POH and UD Spear Assy and DP WEXIT Held PJSM with Schlumberger E-Line Crew. Load Rig Floor with E-Line Equipment and Tools. R/U and Hang Sheaves. String E-Line and Raise Blocks. WEXIT M/U E-Line CCUGR/USIT Logging Tools and RIH, Monitoring Well with Trip Tank WEXIT Run Schlumberger CCUGR/USIT Log WEXIT Send Logs to Town. Discuss Options with Anchorage Team WEXIT R/D E-Line. UD Sheaves and Tools WEXIT P/U 1 Joint 5" DP . M/U Wear Ring Running Tool. Install Wear Ring. RILDS, Remove Running Tool and UD DP WEXIT Held PJSM; P/U 1 Stand 5" DP and M/U 9-5/8" Casing Cutter. Replaced Cutter Blades. Pump at 2 bpm to Confirm Blades Extended. Shut Down Pumps. Retract Blades and Secure with Duct Tape. WEXIT Blow Down Top Drive and Lines WEXIT RIH with 5" DP to 3,880' WEXIT Break Circulation at 2 bpm and Locate Old Cut at 3,900'. Shut Down Pumps and Reposition Cutter at 3,910'. Proceed to Cut 9-5/8" Casing with 50 Rotary rpm, 4 bpm Pump at 1,000 psi. Torque While Cutting 5,000 / 8,000 ft lbs. Torqued Dropped to 2,000 fUlbs and Pressure Dropped to 200 psi When Blades Penetrated Casing. Slowly Reduce Pump and Rotary to 0. WEXIT Close Annular and Circulate 9.3 ppg Brine Down DP at 5-1/2 bpm at 300 psi. Taking Retruns Off OA to Cuttings Tank Until Clean Returns at Surface. Total Displaced Volume 288 bbls WEXIT Monitor Well, 7 bph Fluid Loss WEXIT POH with 5" DP WEXIT B/O and UD Casing Cutter WEXIT P/U 2 Joints DP, M/U Baker Spear Dressed with 9-5/8" 47# Casing Grapple. RIH and Engaged Spear. BOLDS, Pull on Spear and Casing, String Free at 195,000# Up Wt. Pull 9-5/8" Hanger and Packoff to Rig Floor WEXIT Circulate 233 bbls Annulus Volume to Surface. Final Circulating Rate 10 bpm at 200 psi. Installed False Bowl on Rotary Table for 9-5/8" Casing WEXIT Held PJSM; Breaking and UD Down 9-5/8" Spear. Pulling 9-5/8" Casing WEXIT B/O Spear, Make All Service Breaks and UD Same. UD 2 Joints DP WEXIT R/U Casing Tongs, C/O Elevators to 9-5/8" Side Doors WEXIT POH with 9-5/8" 47# NT-80-S Casing. UD 9-5/8" Hgr and Joints #1 - #12 WEXIT POH with 9-5/8" 47# NT-80-S Casing. Joints #13 - #98. Cut Off Joint 10.31' WEXIT R/D Casing Tools and Equipment Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Page 6 of 18 Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date ;From - To 'Hours Task Code NPT Phase Description of Operations 5/6/2006 05:30 - 06:00 0.50 STCTPL P WEXIT Clear and Clean Rig Floor 06:00 - 08:30 2.50 STCTPL P WEXIT PJSM; C/O Top Rams to 2-7/8" to 5" Variables 08:30 - 10:00 1.50 STCTPL P WEXIT P/U Test Joint and Install Test Plug. R/U Testing Equipment 10:00 - 12:30 2.50 STCTPL P WEXIT Tested 2-7/8" x 5" Variables Rams to 250 psi low / 4,000 psi high, Rams Leaked By, Bled Down Pressure, Functioned Rams, Retested-Failed Again 12:30 - 14:30 2.00 STCTPL N SFAL WEXIT Replaced 2-7/8" x 5" Rams with 4-1/2" x 7" Rams 14:30 - 15:00 0.50 STCTPL N SFAL WEXIT Tested 4-1/2" Variables to 250 psi low / 4,000 psi high. Both Tests Held 5 min Each. Test Witnessed by WSL, Chris Clemens 15:00 - 15:30 0.50 STCTPL P WEXIT Pull Test Plug and Install Wear Ring 15:30 - 19:00 3.50 STCTPL P WEXIT Held PJSM; P/U and M/U 9-5/8" Casing Milling BHA; Lockomatic Mill w/ 8.565" Nose -Jet Sub -Bumper Sub -Oil Ja - XO - 9 x 6-3/8" DC's - XO. 307.25' Total Length 19:00 - 20:00 1.00 STCTPL P WEXIT Service Top Drive, Ironroughneck, Blocks and Crown 20:00 - 22:00 2.00 STCTPL P WEXIT RIH with 5" Dp to 3,900' 22:00 - 00:00 2.00 STCTPL P WEXIT Held PJSM; Pump 65 bbls 9.4 ppg Brine. Chased by 585 bbls 9.0 ppg Milling Fluid at 9 bpm, 675 psi. 5/7/2006 00:00 - 06:30 6.50 STCTPL P WEXIT Established Parameters; Up Wt 130,000#, Dn Wt 124,000#, Rt Wt 125,000#, WOM 4,000#, Pump 105 spm at 850 psi, Rotary 85/100 rpm, On Btm Torque 5,500 fUlbs, Off Btm. Torque 3,000 ft/Ibs. Pumping Sweeps Every 5' to 7'. Mill from 3,910' to 3,927'. Sweep Formula 25 bbls 9 ppg Fluid, .2 ppb Soda Ash, 3-4 ppb Duo-Vis, .05 ppb Caustic Soda, 10 ppb Gel, .1 gpb Greenside 25 G, 3.75 Ibs Super Sweep. 06:30 - 09:00 2.50 STCTPL P WEXIT Circulated and Reciprocated Pipe. Pump 150 spm at 1250 psi, Rotary 100 rpm. Pump Weighted 11.0 ppg Super Sweep (recovered 400 Ibs metal), Pump Hi-Vis Super Sweep (recovered 200 Ibs metal), Pump Weighted Super Sweep (recovered 50 Ibs metal) 09:00 - 00:00 15.00 STCTPL P WEXIT Mill from 3,927 to 3,971'. WOM 10-15K. RPM 75/100, Pump 150 spm at 1525 psi. Torque Off Btm 3,000 fUlbs, Torque On Btm 6,500 - 10,000 fUlbs. Alternating 1 Weighted Sweep to 2 Non-Weighted Sweeps. 5/8/2006 00:00 - 04:30 4.50 STCTPL P WEXIT Mill from 3,970' to 3,990'. WOM 10-15K. Alternating 1 Weighted Sweep to 2Non-Weighted Sweeps. 04:30 - 06:00 1.50 STCTPL P WEXIT P/U to Circulate and Clear Cutter Blades of Shavings. Work Pipe Back Down to 3,990'. WOM 10-20K, Roatary 50-100 rpm, Pump 10-15 bpm. Pump Weighted Sweep and Super sweep to Clean Well Bore 06:00 - 11:00 5.00 STCTPL P WEXIT Mill from 3,990' to 4,020'. Pump Sweep Every Hour. Alternating 1 Weighted Sweep to 1Non-Weighted Sweep 11:00 - 13:30 2.50 STCTPL P WEXIT P/U to Circulate and Clear Cutter Blades. Pumped Weighted Sweep Followed by Super Sweep. Reciprocated and Rotated Pipe While Circulating, 130 rpm, 180 spm at 1,850 psi / 2,00 psi. Unable to Work Past 3.993' 13:30 - 17:30 4.00 STCTPL P WEXIT POH, Back Ream from 3,993' to 2,137'. Rotary 60 rpm, Pump 180 spm at 2,000 psi. Tight at 2,894' 17:30 - 18:00 0.50 STCTPL P WEXIT Pump Dry Job 18:00 - 19:30 1.50 STCTPL P WEXIT POH with 5" DP 19:30 - 21:30 2.00 STCTPL P WEXIT POH with Milling BHA; UD DC', Jars, Bumper Sub, Jet Sub, Casing Mill. Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ! Name: ell Name: A e: Name: From - To AGI-07 GI-07 REENTE NABOBS NABOBS Hours R+COM ALASK 27E Task PLET A DRI Code E LLING NPT j Start I Rig Rig Phase '. Spud Date: 5/13/2006 : 4/26/2006 End: 5/31/2006 Release: 5/16/2006 Number: 27E Description of Operations 5/8/2006 21:30 - 22:00 0.50 STCTPL P WEXIT Clear and Clean Rig Floor 22:00 - 23:30 1.50 STCTPL P WEXIT P/U and M/U BOPE Flushing Tool, Flush BOPE's, Choke Line and Kill Line, Function All Rams and Annular, Reflush BOPE's. and Flowline. UD Flushing Tool 23:30 - 00:00 0.50 STCTPL P WEXIT P/U Test Joint and Remove Wear Ring 5/9/2006 00:00 - 00:30 0.50 STCTPL P WEXIT P/U Flushing Tool, Flush Wellhead/Test Plug Setting Area. UD Flushing Tool 00:30 - 01:30 1.00 STCTPL P WEXIT P/U Test Joint, M/U Test Plug and Install, R/U Testing Equippment 01:30 - 03:30 2.00 STCTPL N SFAL WEXIT BOP test witness waived by Jeff Jones(AOGCC) Witnessed by wellsite leader Rod Klepzig and Nabors tour pusher Rick Brumley. Fill BOPE Stack with Water, Leaking By Test Plug, Pull Test Plug and Inspect Seal, Seal in Good Condition, Reinstall Test Plug, Fill with Water, Still Leaking, RILDS, Still Leaking, Removed Test Plug. Installed Upper Test Plug, Filled BOPE's with Water, Full Body Pressure Test to 250 psi / 4,000 psi. 03:30 - 09:00 5.50 STCTPL P WEXIT Test BOPE as per BP and AOGCC regulations, to 250 psi low and 4000 psi high -Test Hydril to 250 psi low and 3500 psi high. Pulled upper test plug, installed a new lower test plug and tested bottom flange ok. Test witnessed by BP wellsite leader Chris Clemens and Nabors tool pusher AI Lunda. 09:00 - 10:00 1.00 STCTPL P WEXIT Clear floor, install wear bushing. 10:00 - 12:30 2.50 STCTPL P WEXIT Pick up 3-1/2" mule shoe and 20 jts 3-1/2" tubing, totaling 628.80' and xo back to 5" dp. 12:30 - 14:30 2.00 STCTPL P WEXIT RIH with 3-1/2" tbg on 5" drill pipe to 13-3/8" shoe at 3936'. 14:30 - 15:30 1.00 STCTPL P WEXIT RIH while pumping 2.5 bbls/min at 200 psi. Held up at 3992'. Attempt to wash and work past with no success. 15:30 - 17:30 2.00 STCTPL P WEXIT Circulate b/u at at 700 gpm - 650 psi. Rig up cement equipment, hold safety meeting. Up wt=115k - Dn wt =110k 17:30 - 18:30 1.00 STCTPL P WEXIT Pump 5 bbl water spacer, pressure test surface lines to 3500 psi, pump 5 bbls water spacer, pump 59 bbls of 17 ppg cement at 4.5 bbls per minute, pump 1 bbl water spacer, displace cement with rig pump, 56 bbls at 6 bbls/minute 18:30 - 19:30 1.00 STCTPL P WEXIT Lay down pup jt and 1 jt of 5" drill pipe. Pull out of cement 8 stands slowly to 3190' 19:30 - 21:00 1.50 STCTPL P WEXIT Circulate 510 bbls to clear annulus of contaminated cement. Approximately 150 bbls came back with a ph of 11.2, dropping to a ph of 10.0 in the next 50 bbls of mud pumped. Dropped wiper plug, pumped 51 bbls at 336 gpm at 350 psi. 21:00 - 23:30 2.50 STCTPL P WEXIT Trip out of the hole to the 3-1/2" tubing. Mud wt in and out 9.1 PPg• 23:30 - 00:00 0.50 STCTPL P WEXIT Rig up casing tongs to lay down 3-1/2" tubing 5/10/2006 00:00 - 01:00 1.00 STCTPL P WEXIT POH LD XO, 20 Jts 3 1/2" NSCT & Mule shoe 01:00 - 02:00 1.00 STCTPL P WEXIT RD 3 1/2" handling equipment. Clean and clear rig floor 02:00 - 04:30 2.50 BOPSU P WEXIT MU Flushing tool and flush BOP stack. Function test rams. Pull wear bushing. Repeat Flushing procedure. Service wear bushing and install same. 04:30 - 09:00 4.50 STCTPL P WEXIT RU 5" handling equipment and RIH PU 5" DP 1x1 bulding stands to TD intermediate hole section. 09:00 - 10:30 1.50 STCTPL P WEXIT Trip out 33 stands and rack back in derrick to TD intermediate hole section. Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date From - To Hours i Task Code !. NPT 5/10/2006 10:30 - 14:30 4.00 STCTPL P Start: 4/26/2006 Rig Release: 5/16/2006 Rig Number: 27E Phase WEXIT 14:30 - 17:00 I 2.50 I STCTPL I P I I W EXIT 17:00 - 19:30 ~ 2.50 STCTPL ~ P ~ W EXIT 19:30 - 20:00 0.50 STCTPL P WEXIT 20:00 - 22:00 2.00 STCTPL P WEXIT 22:00 - 23:30 1.50 STCTPL P WEXIT 23:30 - 00:00 I 0.50 I STCTPL I P I I W EXIT 5/11/2006 100:00 - 01:00 I 1.001 STCTPL I P I I W EXIT 01:00 - 03:30 I 2.50 I STCTPL I P i I W EXIT 03:30 - 04:00 0.50 STCTPL P WEXIT 04:00 - 05:00 1.00 STCTPL P WEXIT 05:00 - 05:30 I 0.501 STCTPL I N I HMAN I W EXIT 05:30 - 08:00 I 2.50 I STCTPL I P I I W EXIT 08:00 - 10:30 I 2.50 I STCTPL I N I HMAN I W EXIT 10:30 - 12:00 1.50 STCTPL N HMAN WEXIT 12:00 - 13:30 1.50 STCTPL N HMAN WEXIT 13:30 - 14:30 1.00 STCTPL P WEXIT 14:30 - 17:00 ~ 2.50 ~ STCTPL ~ P ~ ~ W EXIT 17:00 - 18:00 1.00 STCTPL P WEXIT 18:00 - 19:30 1.50 STCTPL P WEXIT 19:30 - 20:30 1.00 STCTPL P WEXIT 20:30 - 21:30 1.00 .STCTPL P WEXIT 21:30 - 22:30 I 1.00 I STCTPL I N I WAIT I W EXIT 22:30 - 23:00 I 0.50 I STCTPL I P I I W EXIT 23:00 - 00:00 I 1.00 I STCTPL I P I I W EXIT Page 8 of 18 Spud Date: 5/13/2006 End: 5/31 /2006 Description of Operations RIH PU 5" DP 1x1 bulding stands to TD intermediate hole section. Trip out 31 stands and rack back in derrick to TD intermediate hole section. Make up 12-1/4" bha. P/U milltooth bit, mud motor set at 1.83 degrees, stab, and mwd tools. Load mwd tools. Pick up 3 - 8" flex dc'c, xo, 12 jts 5" hwt, 6.25" jar, 5 jts 5" hwt RIH w/5" dp to 3200', strap in hole. Cement compression at 2300 hrs is 1800 psi. Circulate and condition mud. 420 gpm - 875 psi. Up wt=125k - Dn wt=115k, 9.2 ppg in and out Circulate and condition mud. 420 gpm - 875 psi. Up wt=125k - Dn wt=115k, 9.2 ppg in and out. Test 13-3/8" casing to 2750 psi for 30 minutes, record on chart. 60 strokes total at 1 bbl/min. Lost 125 psi in 30 minutes. Blow down choke line with air. RIH, tag top set 4-1/2" x 7 "variable rams that were left closed after testing casing. Mix and pump dry job to POOH. Mobilize 13 3/8" storm packer from Halliburton. At 0530 the compression on the kick off plug is 4000 psi. Wash down from 3180' to 3554' looking for cement while mobilizing Halliburton. PU storm packer, set at 45', pull wear ring,set test plug, visually inspect top set of 4-1/2" x 7" variable rams, test same to 4000 psi. Rig down test equipment. Release storm packer and lay down same. M/U top drive, establish slow pump rate, perform D2 and D5 wel kill) drill. Simulate well kill through choke manifold, alternate crew members operating super choke testing well control equipment for operational performance. Wash and ream from 3554' to 3655', tag cement at 3655'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Calibrate depth tracking for Epoch and Sperry Sun. Drill cement from 3655' to 3830'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Run water 30 bbls/hr. Change shaker screens to 180's, 140's,110's,84's Drill cement from 3830' to 3927'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.2 ppg in & out, torq=6500. Circulate while waiitng on supersuckers. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.1 ppg in & out, torq=6500. Drill cement from 3830' to 3927'. Up wt=125k - Dn wt =120k, 500 gpm at 1300 psi, 30 rpm rotary, 9.0 ppg in & out, torq=6500. Circulate and condition mud, turn up pumps to 600 gppm, hole unloaded. Up wt=150k - Dn wt =123k, 600 gpm at 1750 psi, 30 rpm rotary, 9.0 ppg in & out, torq=6500. Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Page 9 of 18 Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date I From - To I Hours I Task ! Code I NPT 5/12/2006 00:00 - 00:30 ~ 0.50 ~ STCTPL ~ P 00:30 - 03:00 2.50 STCTPL N DFAL 03:00 - 06:00 3.00 STCTPL N DFAL 06:00 - 07:30 1.50 STCTPL N DFAL 07:30 - 08:30 1.00 STCTPL N DFAL 08:30 - 09:30 1.00 STCTPL N DFAL 09:30 - 10:30 1.00 STCTPL N DFAL 10:30 - 11:30 11:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 19:00 19:00 - 19:30 19:30 - 20:30 5/13/2006 20:30 - 00:00 00:00 - 01:30 01:30 - 02:00 02:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 00:00 5/14/2006 100:00 - 00:30 Phase ~ Description of Operations WEXIT Circulate hole clean at 700 gpm at 2100 psi. Up wt=150k, do wt= 123k, 30 rpm's, 6.5k torq, 8.9 ppg in and out. WEXIT Trouble shoot Spery Sun MW D. Tool would not tum on. WEXIT Trip out of hole for MW D tool. WEXIT Stand back bha -drain mud motor WEXIT Download mwd data WEXIT Lay down mwd tool, pick up new mwd tools. WEXIT Change out bits to a Hycalog PDC 12-1/4" DSX 103H, change motor bend to 1.50. 1.00 STCTPL N DFAL WEXIT Orient mwd to motor, initialize mwd tool. 1.50 STCTPL N DFAL WEXIT Trip in hole to 1800'. 0.50 STCTPL N DFAL WEXIT Make up ghost reamer into drill string 1800' behind the bit. 0.50 STCTPL N DFAL WEXIT Shallow pulse test mwd tool. 1.00 STCTPL N DFAL WEXIT RIH to 3720'. 4.00 STCTPL N RREP WEXIT Repair hydraulic leak on top drive. 0.50 STCTPL N DFAL WEXIT RIH to 3935'. 1.00 STCTPL P ~ W EXIT Circulate hole clean. 270 gpm at 500 psi. 8.9 ppg in and out, up wt= 150k, do wt=123k. 3.50 STCTPL N RREP WEXIT Hydraulic brake on top drive failed, repair same. 1.50 STCTPL N RREP WEXIT Hydraulic brake on top drive failed, replace selinoid. 0.50 STCTPL P WEXIT Make connection, orient pipe to a 150R TF. 4.50 DRILL P INT1 Time drill 5'/hr to kick off cement plug. 700 gpm ~ 1300 psi, uw=150k,dw=123k, 8.9 ppg in/out, 2k wt on bit. Drilled from 3935' to 3957'. AST=4hrs. 1.50 DRILL P INT1 Circulate 10594 stks C~ 700 gpm, 1300 psi, uw=150k, dw=123k, 9 ppg in/out. 1.00 DRILL P INT1 Perform L.O.T., broke down at 673 psi, 12.7 ppg. 1.50 DRILL P INT1 Slide F/3957'-T/3990', 700 gpm @ 1300 psi, uw=150k, dw=123k, 9 ppg in/out. AST=1.5hrs. 1.50 DRILL P INT1 Rot F/3990'-T/4027', 60 rpms, rw=130k, uw=150k, dw=123k, tq=7k, 9 ppg in/out. 1.00 DRILL P INT1 Circulate hole clean, 9.Oppg in/out 0.50 DRILL P INT1 Trip out 3 stands to the shoe. 1.00 DRILL P INT1 Establish baseline for clean hole ECD of 9.1 ppg. 0.50 DRILL P 9.00 DRILL P 0.50 DRILL P 00:30 - 12:00 I 11.501 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 5/15/2006 100:00 - 02:30 I 2.501 DRILL I P INT1 Trip back to 4027'. INT1 Drill F/4027'-T/5066', AST=.5hrs, ART=4.15hrs, TDT=10.15hrs, 85 rpm, 5k-12k wt on bit, uw=160k, dw=130k, rw=150k, tq on=8k, tq off=7k, mw=9.2ppg in/out, 700 gpm @ 1830 psi. INT1 Slide F/5066'-T/5096', 750 GPM ~ 1900 psi, 5k-12k wt on bit, uw=160k, dw=130k, rw=150k, tq on=8k, tq off=7k, mw=9.2ppg in/out. INT1 Drill F/5096'-T/5664', 850 GPM ~ 2300 psi, 5k-12k wt on bit, uw=191 k, dw=135k, rw=160k, tq on=9k, tq off=7k, mw=9.2ppg in/out. INT1 Drill F/5096'-T/'6095', 850 GPM, 2300 psi off, 2400 psi on, 80 rpm, 5k-20k wt on bit, uw=200k, dw=140k, rw=160k, tq on=10k, tq off=8k, mw=9.2ppg in/out. AST=.5, ART=15.25, TDT=26. INT1 Drill F/6095'-T/'6204', 850 GPM, 2300 psi off, 2400 psi on, 80 rpm, 5k-20k wt on bit, uw=200k, dw=140k, rw=160k, tq on=10k, tq off=8k, mw=9.2ppg in/out. Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 27E Date From - To Hours I Task Code ~ NPT ~ I Page 10 of 18 Spud Date: 5/13/2006 Start: 4/26/2006 End: 5/31 /2006 Rig Release: 5/16/2006 Rig Number: 27E Phase Description of Operations 5/15/2006 00:00 - 02:30 2.50 DRILL P INT1 02:30 - 04:30 2.00 DRILL N SFAL INT1 04:30 - 05:00 0.50 DRILL N SFAL INT1 05:30 - 12:00 6.50 DRILL P INT1 12:00 - 15:30 I 3.501 DRILL I P I I INT1 15:30 - 16:30 1.00 DRILL N SFAL INT1 16:30 - 00:00 7.50 DRILL P INT1 5/16/2006 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P 12:00 - 12:30 I 0.501 DRILL I P 12:30 - 20:30 8.00 DRILL P 20:30 - 21:00 0.50 DRILL N 21:00 - 00:00 3.00 DRILL P 5/17/2006 100:00 - 09:00 I 9.001 DRILL I P 09:00 - 10:00 I 1.001 DRILL I N 10:00 - 12:00 I 2.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 5/18/2006 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:30 I 1.001 DRILL I N 03:30 - 13:00 I 9.501 DRILL I P INT1 INT1 INT1 SFAL INT1 INT1 INT1 INT1 INT1 Change out swab on # 2 mud pump. Clean screen in #1 suction line. Drill F/6204'-T/'6772', 850 GPM, 2300 psi off, 2400 psi on, 80 rpm, 5k-12k wt on bit, uw=221 k, dw=144k, rw=173k, tq on=14k, tq off=14k, mw=9.2ppg in/out. AST=O, ART=6.5, ADT=6.5 Drill F/6772'-T/'6961', 850 GPM, 2300 psi off, 2400 psi on, 80 rpm, 5k-10k wt on bit, uw=230k, dw=146k, rw=177k, tq on=14k, tq off=14k, mw=9.2ppg in/out. Replace gasket in suction line. Drill F/6991'-T/7410', 850 GPM, 2300 psi off, 2400 psi on, 80 rpm, 5k-10k wt on bit, uw=250k, dw=146k, rw=182k, tq on=16k, tq off=14k, mw=9.2ppg in/out. AST=3.2, ART=3.85, ADT=7.05 Drill 12.25" hole F/7410'-T/7910', 850 GPM, 2600 psi off, 2800 psi on, 85 rpm, 5k-10k wt on bit, uw=259k, dw=146k, rw=196k, tq on=18k, tq off=17k, CECD=9.4 ppg, AECD=9.65 ppg. Circulate 11.7 ppg weighted sweep around. Reciprocated Drill String Off Bottom at 200 spm, 2,500 psi, 100 rpm. Approximately 10% Increased Cuttings Return Drill 12.25" hole F/7910'-T/8270', 850 GPM, 2600 psi off, 2800 psi on, 85 rpm, 5k-10k wt on bit, uw=265k, dw=160k, rw=200k, tq on=18k, tq off=17k, CECD=9.5 ppg, AECD=9.63 ppg. Sperry Sun MW D repair stroke counter on mud pump. Drill 12.25" hole F/8270'-T/8439', 850 GPM, 2600 psi off, 2800 psi on, 85 rpm, 5k-10k wt on bit, uw=265k, dw=160k, rw=200k, tq on=18k, tq off=17k, CECD=9.52 ppg, AECD=9.75 ppg. Drill 12.25" hole F/8,439'-T/8,782', 850 GPM, 2600 psi off, 2800 psi on, 85 rpm, 5k-10k wt on bit, uw=265k, dw=160k, rw=200k, tq on=18k, tq off=17k, CECD=10 ppg, AECD=10.2 ppg. Trickling 13.5 ppg spike mud into the system to achieve a 10.4 ppg all around. All spiked mud added by 0730 hrs. Change Out Swab and Liner in #2 Mud Pump, #1 Cylinder. While Changing Out Swab and Liner Reciprocated and Circulated Off Bottom with #1 Mud Pump at 95 spm, 800 psi, 50 rpm Drilled 12-1/4" Hole f/8,762'- U8,820', 15k WOB, 850 GPM, 2600 psi off, 2800 psi on, 85 rpm, uw=260k, dw=160k, rw=201 k, tq on=18k, tq off=17k, CECD=10.6 ppg, AECD=10.8 PPg• INT1 Drilled 12-1/4" Hole f/8,820'- U9,251', 15k WOB, 850 GPM, 2800 psi off, 3200 psi on, 85 rpm, uw=265k, dw=165k, rw=206k, tq on=19k, tq off=17k, CECD=10.6 ppg, AECD=10.8 ppg. AST=3.4, ART=10.65, TDT=69.3 hrs INT1 Drilled 12-1/4" Hole f/9,251'- U9,362', 15k WOB, 850 GPM, 3000 psi off, 3400 psi on, 85 rpm, uw=265k, dw=165k, rw=206k, tq on=19k, tq off=17k, CECD=10.6 ppg, AECD=10.8 PPg• INT1 Change Out Swab #2 Mud Pump, #3 Cylinder. While Changing Out Swab and Liner Reciprocated and Circulated Off Bottom with #1 Mud Pump at 100 spm, 900 psi, 50 rpm's. INT1 Drilled 12-1/4" Hole f/9,362'- U9,730', 15k WOB, 850 GPM, Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Event Name: REENTER+COMPLETE Start: 4/26/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date I From - To I Hours I Task . Code i NPT 5/18/2006 ~ 03:30 - 13:00 9.50 ~ DRILL ~ P 13:00 - 15:00 I 2.001 DRILL I P 15:00 - 22:00 I 7.001 DRILL I P 22:00 - 00:00 2.00 DRILL N 5/19/2006 00:00- 00:30 0.50 DRILL N 00:30 - 03:00 2.50 DRILL N 03:00 - 06:00 3.00 DRILL N 06:00 - 09:00 3.00 DRILL N 09:00 - 10:00 1.00 DRILL N 10:00 - 10:30 0.50 DRILL N 10:30 - 12:30 2.00 DRILL N 12:30 - 14:00 1.50 DRILL P 14:00 - 15:30 1.50 DRILL P 15:30 - 16:00 0.50 DRILL N 16:00 - 20:30 4.50 DRILL P 20:30 - 22:30 2.00 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL N DPRB 5/20/2006 100:00 - 08:00 I 8.001 STKOH I N I DPRB 08:00 - 09:00 1.00 STKOH N DPRB 09:00 - 14:00 5.00 STKOH N DPRB Page 11 of 18 Spud Date: 5/13/2006 End: 5/31 /2006 Phase ! Description of Operations INT1 3000 psi off, 3400 psi on, 85 rpm, uw=275k, dw=165k, rw=208k, tq on=19.5k, tq off=18.5k, CECD=10.65 ppg, AECD=10.84 ppg. INT1 Reciprocated and Circulated 13.0 ppg Sweep at 200 spm, 3,000 psi, 100 rpm. While Taking Check Survey Lost 250 psi. Checked Surface Mud System for Leaks, None. Continued to Circulate Sweep Around. Total Pressure Loss 500 psi. Pressure Held Steady at 2,500 psi During Final Circulation. Cuttings Reutrns Increased by +/- 25%-35% When Sweep at Surface. Unable to Get Final Clean Hole ECD Because MWD Failed to Turn On Becuase of No Differential Pressure Spike INT1 POH (/9,730'. Backreamed U9,100'. POH Wet Looking for Washout INT1 Stand Back 6 Stands Hwt DP, Jar, and 1 stand 8" DC's. INT1 Pull MWD, Float Sub, and 21' of mud motor out of the hole. We left 7.4' of the mud motor, rotor, and the Hycalog DSX 103H bit in the hole. It looks like the motor unscrewed right above the adjustment nut. That explains the surveys going the oppisite direction of the slides made. INT1 Download MWD, lay down MWD tools and mud motor. INT1 Clean rig floor and drip pans below rotary table. INT1 P/U and M/U 12-1/4" BHA; Hughes MXL1 Bit-8" Motor w/ 1.5 deg Bend -Stab -MWD -Float Sub - 3 x 8" Flex DC's - XO - 12 x 5" DWDP -Jars - 5 x 5" HWDP. 12-1/4" Ghost Reamer at 1,800'. BHA Length 715.59' INTi RIH w/ 5" DP to 1,850'. P/U Ghost Reamer INT1 Fill DP, Pulse Check MWD, Good Pulse INT1 RIH f/1,850' - U3,837' INT1 Cut Drilling Line. INT1 Service Top Drive, Crown and Blocks. INT1 Fill DP. INT1 RIH w/ 5" DP F/3,387' - T/ 9,427'. Rotated Ghost Reamer Through 13-3/8" Shoe. First Time Through, String Stalled. Second Time Through, Maximum Torque 22,500 ft/Ibs, String Did Not Stall, Third Time Through, Maximum Torque 18,000 ft/Ibs. Fourth Time Through, 15,000 ft/Ibs. Good to Go INT1 Pump 13.0 ppg, 65 Vis, 35YP, weighted sweep full circulation. Circulate and reciprocate at 800 gpm at 3,700 psi, 80 rpm's, 65 visc, 35 yp. Did not notice increase in cuttings when sweep came back. INT1 Establish baseline clean hole ECD. CECD=10.7, AECD=10.7. INT1 Trough F/9,417'-T/9,427' at 180 deg Tool Face. 850 gpm, 3,700 psi. INT1 Time drill open hole sidetrack F/9,417'-T/9,465' at 5' / hr. 850 GPM at 3,700 psi. AECD=10.7, CECD=10.7. INT1 Rotary Drill F/ 9,465' - T/ 9,500'. Backreamed T/ 9,417'. Oriented Toolface 180 deg, Slide F/ 9,417 - T/ 9,500'. Backream T/ 9,417'. Rotated Down F/ 9,4127' - T/ 9,550'. Surveyed at 9,500' Bit Depth, Old Hole, INC 45.29, AZ 77.81. New Hole, INC 43.47, AZ 75.77 INTi Directional Drill F/ 9,500' - T/ 9,670'. Up Wt 276K, Dn Wt 170K, Rt Wt 207K, 45K-50K WOB, 80 rpm, Tq On 15-17K, Tq Off 15K, 850 gpm, 4,000 psi. DPRB DFAL DFAL DPRB DPRB DPRB DPRB DPRB DPRB Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 12 of 18 Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date From - To ! Hours ~ Task ~ Code ~ NPT Phase Description of Operations 5/20/2006 14:00 - 15:00 1.00 STKOH N DPRB INTi Pump Swab Failed #1 Pump #3 Cylinder. Decission was Made to Change Out All Swabs on # 1 Pump 15:00 - 16:30 1.50 STKOH N DPRB INT1 Directional Drill F/ 9,670' - T/ 9,730' 16:30 - 21:00 4.50 STKOH P INT1 Directional Drill F/ 9,730' - T/ 9,960'. Estamated Top of Ivishak at 9,975' MD. Up Wt 266K, Dn Wt 176, Rt Wt 212K, 45K-50K WOB, 80 rpm, Tq On 18K, Tq Off 17K, 850 gpm, 4,000 psi. 21:00 - 23:00 2.00 STKOH P INT1 Circulate 1.5 times bottoms up. Pumped weighted sweep, 13 ppg, 65 vise, 35YP) 850 gpm at 4000 psi, 100 rpm's, CECD=10.8 ppg, AECD=10.95 ppg. 23:00 - 00:00 1.00 STKOH P INT1 Pump out f/9,960'-U9,804', no rotating, 800 gpm at 3400 psi. 5/21/2006 00:00 - 01:00 1.00 STKOH P INT1 POH f/9,804' - U9,427', Pumping Out, no rotating, 800 gpm at 3400 psi. Pull 2 stands with no pump to 9416', 300k-340k up wt. 01:00 - 01:30 0.50 STKOH P INT1 RIH T/ 9,960', Work though the sidetrack at 9,417' with 180 deg Toolface, While Rotating and with Unknown Toolface 01:30 - 04:30 3.00 STKOH P INTi Estabish circulation, pump weighted sweep(13 ppg, 65 visc, 35 YP), circulate 3 times bottoms up. 850 gpm at 3,950 psi, 100 rpm's. CECD=10.81 ppg, AECD=10.86 , 10.6+ ppg in / 10.6+ out. 04:30 - 06:00 1.50 STKOH P INT1 POH F/ 9,960' - T/ 9,485' with Pumps On at 700 gpm, no rotating, pull 2 stands without pumps T/ 9,285' to check for swabbing, OK. 06:00 - 06:30 0.50 STKOH P INT1 Pump Dry Job, Blow Down Top Drive 06:30 - 11:00 4.50 STKOH P INT1 POH F/ 9,485' - T/ 707' 11:00 - 15:30 4.50 STKOH P INT1 POH w/ BHA; Stand Back 5" HWDP and Jars. B/O and UD Flex DC's, XO's, Download MWD. Continue to UD MWD, Stab's, Motor and Bit 15:30 - 16:00 0.50 CASE P INT1 P/U Test Jt, M/U Wear Ring Retrieving Tool, Pull Wear Ring, UD Test Jt. 16:00 - 19:00 3.00 CASE P INTi Closed Blind Rams and Monitored Well Bore at Wellhead Annulus. Held PJSM, C/O Top Set Rams to 9-5/8". Dress 1 ram door bolt starting thread to screw bolt back in. 19:00 - 21:30 2.50 CASE P INT1 Test top 9-5/8" rams with 9-5/8" test joint. 250 psi low - 4,000 psi high, 5 minutes each, recorded on chart, OK. Witnessed by WSL Charlie Noakes. UD Test Jt and Test Plug 21:30 - 00:00 2.50 CASE P INT1 Hold PJSM with casing hands and crew. Pick up landing jt and performed Dummy Run, 30.85'. Rig up to run 9-5/8" casing. 5/22/2006 00:00 - 02:00 2.00 CASE P INT1 Rig 9-5/8" Casing Equipment, C/O Bails, R/U Torque Turn Equipment 02:00 - 03:30 1.50 CASE P INT1 Held PJSM; Pick up 1st joint of 9-5/8" 47# L-80 TClI casing with the Float Shoe on bottom, Float Collar on top. Install Baffle Adapter on top of Float Collar, Bakerlock pin on second jt, make up to Float Collar. Pick up jt #3 with the Baffle Adapter on bottom, Bakerlok Baffle Adapter and screw into top of jt #2. Make up Franks Fillup tool to TD and torque to 20k, break circulation, p/u 30', come back down, check floats. OK. 03:30 - 04:30 1.00 CASE N RREP INT1 Work on casing stabbing board. It will go up but will not come down. 04:30 - 07:00 2.50 CASE. P INT1 RIH w/ 9-5/8" casing filling every jt. 80 fUmin Running Speed, Jt's #4 - #31 07:00 - 07:30 0.50 CASE P INT1 Break Circulation at 1,750'. 50 spm, 250 psi 07:30 - 13:30 6.00 CASE P INT1 RIH T13,920' w/ 9-5/8" 47# L-80 TCII Casing. Jt's #32- #95. P/U and M/U Baffle Adapter between Jts # 51 & #52 Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABORS 27E Rig Number: 27E Date ;From - To ~ Hours Task Code j NPT j Phase Description of Operations 5/22/2006 13:30 - 15:00 1.50 CASE P INT1 Break Circuilation at 3,920'. Stage Pumps Up Starting with 2 bpm. Final Circulation Rate 7 bpm, 500 psi. Take SPR's at 40 spm 250 psi, 45 spm 285 psi 15:00 - 00:00 9.00 CASE P INTi RIH w/ 9-5/8" 476# L-80 TCII Casing. Jts. #95 - #200 to 8,169'. Filling Every Joint and Circulating Down Every 15th Joint at 4-6 bpm for 40 bbls. Full displacement returns. (AT 7,560' we started to only get 75% of our calcutaed displacement. Pumped down 2 jts back to back at 10 minutes a jt to move more mud and slowed down our running speed. Ran another 15 jts and only gained 50% of our displacement, pumping 4-6 BPM. UW=370k. DW=230k. 5/23/2006 00:00 - 07:00 7.00 CASE P INT1 At 200 jts in at a depth of 8,169' we are getting back 60% of our calculated displacement.. Started pumping 5 BPM every 5 jts for 15 minutes trying to gain full returns. Worked pipe while circulating. Full returns while circulating at 5 BPM, only losing while running in pumping at 3 min/jt. At 8,700' we started pumping down every jt at 5 BPM, getting back 50% of our calculated displacemnt At 9,140' we didn't getting any displacement back. Slowed the pump to 4 BPM while running in the hole. RIH to 9,960', getting 50% displacement back. UW=460k, DW=250k, 4 BPM=425 psi. (No problems at sidetrack depth of 9,417'.) Landed Out Casing at 9,958' 07:00 - 09:00 2.00 CASE P INT1 Circulate at 7 bpm, 735 psi. No Reciprocation Because of Interferance between BOPE Ram Cavities and Fluted Hanger. 09:00 - 10:00 1.00 CASE P INT1 R/D Franks Fill Up Tool, Load Head w/Wiper Plug, Install Cement Head 10:00 - 10:30 0.50 CASE P INT1 Circulate Through Cement Hose and Head at 7 bpm, 775 psi. Held PJSM w/ Rig Crew, Cementing Crew, Truck Drivers. Mudman and Rig Supervisors 10:30 - 14:00 3.50 CEMT P INT1 Kick Out Wiper Plug w/ 5 bbls Water. Test Lines to 4,000 psi. Bled Down All Pressure. Load Cement Head w/ Open ES Cementer Opening Plug. Pump 20 bbls 8.32 ppg CW-100, 100 bbls 11.5 ppg Mud Push, 90 bbls 12.5 ppg Lite- Crete Class G Cement and 85 bbls 15.8 ppg Class G Tail Cement. Kick Out Opening Plug w/ 5 bbls Water. Switched to Rig pumps and Displaced Cement at 10 bpm Until Mud Caught Cement. Continued to Displace at 7 bpm. Slowed Pumps to 6 bpm at 650 bbls Away, 4 bpm at 710 bbls Away, Pumped Plug at 2 bpm at Calculated Strokes. CIP at 1345 hrs. Pressured Up to 1,600 psi. Held 5 min. Bled Down Pressure to 0 psi. Checked for Flowback, No Flowback. Observed Full Returns Through Out Cement Job. 14:00 - 18:00 4.00 CEMT P INTi Loaded Cement Head w/ ES Cementer Closing Plug. Pressure Up to 2,950 psi to Open ES Cementer. Circulated at 6 bpm, 650 psi. At Bottoms Up Observed Ph Level fo 11.3. Continued to Circulate and Condition Mud. Held PJSM w/ Rig Crew, Cementing Crew, Truck Drivers. Mudman and Rig Supervisors 18:00 - 22:30 4.50 CEMT P INTi Pump 20 bbls 8.32 ppg CW-100, 150 bbls 11.0 ppg Mud Push, 110 bbls 11.0 ppg Class G Lead Cement, 195 bbls 15.8 ppg Class G Tail Cement. Kick Out ES Cementer Closing Plug w/ 5 bbls Water. Switch to Rig pumps and Displaced Cement at 9 bpm Until Mud Caught Cement. Continued to Displace at 7 bpm. Slowed Pumps to 6 bpm at 500 bbls Away, 4 bpm at 550 Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31!2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Task ~ Code { NPT I Phase ~'~~ Description of Operations Date i From - To Hours - _--- __ - - _. - 5/23/2006 18:00 - 22:30 4.50 CEMT P INT1 bbis Away, 2 bpm at 560 bbls Away at 975 psi, Bumped Plug at 2 bpm at Calculated Strokes. CIP at 2205 hrs. Pressure Up to 1,950 psi to Shut ES Cementer, Held Pressure 5 min. Bled Down all Pressure and Checked for Flowback, No Flowback. Observed Full Returns through Out Cement Job. 22:30 - 00:00 1.50 CEMT P INTi R/U to Flush 9-5/8' x 13-3/8" Annulus. Initial Breakdown at 1/2 bpm, 340 psi. Established Injection Rate of 2 bpm, 700 psi. Displaced 125 bbls 10.4 ppg LSND Mud 5/24/2006 00:00 - 01:00 1.00 CASE P INT1 UD Cement Head, B/O and UD Landing Jt., UD Casing Elevators. 01:00 - 02:00 1.00 BOPSU P INT1 P/U Test Jt and M/U Packoff Running Tool. Install 9-5/8" Packoff and Test to 5,000 psi. 02:00 - 04:00 2.00 BOPSU P PROD1 Remove 9-5/8" Rams, Installed 4-1/2" x 7" Rams. Inject 150 bbis Crude Down 9-5l8" x i3-3/8" Annulus w/ Hot Oil at 2 bpm, 1,250 psi. Final Injection Pressure 1,400 psi. 04:00 - 08:00 4.00 BOPSU P PROD1 P/U and M/U Test Joint and Test Plug. Installed Test Plug, M/U Floor Safety Valve and Top Drive to Test Joint. 08:00 - 13:00 5.00 BOPSU P PROD1 Tested 3-1/2" x 6" Variable Rams, 4-1/2" x 7" Variable Rams, Blind/Shear Rams, Manual and Hydraulic Kill and Choke Line Valves, Choke Manifold, Floor Safety Valves, Upper and Lower Top Drive IBOP Valves, to 250 psi Low / 4,000 psi High. Annular to 250 psi Low / 3,500 psi High. All Tests Held 5 min Each. Accumulator Test; Starting Pressure 3,200 psi, Pressure After Closure 1,700 psi, First 200 psi Attained 29 sec, Full Pressure Attained 1 min 49 sec. 8 Nitgn Bottles at 2,400 psi avg. State Witness of Test Waived by AGOCC Rep. John Crisp. Test Witnessed by WSL Chris Clemens and Nabors Toolpusher Dave Hansen. 13:00 - 14:00 1.00 BOPSU P PROD1 R!D Testing Equipment, Remove Test Joint and Plug, Blow Down Choke Manifold, Drain Stack 14:00 - 14:30 0.50 BOPSU P PROD1 P/U Test Joint and Installed Wear Ring. RILDS 14:30 - 15:00 0.50 DRILL P PROD1 R/D Stabbing Board 15:00 - 16:30 1.50 DRILL P PROD1 P/U and M/U 8-1/2" Directional BHA; Hughes 8-1/2" MXL-18DX Bit, 7" Motor, Stab, Float Sub, MWD 16:30 - 17:30 1.00 DRILL P PROD1 Load MWD 17:30 - 19:30 2.00 DRILL P PROD1 Continue to RIH with BHA, Pump Out Sub, 2 x NM Flex DC's, 12 x HWDP, Jars, 5 x HWDP. BHA Length 746.59'. Pulse Test MWD, Good Pulse 19:30 - 22:00 2.50 DRILL P PROD1 RIH w/ 5" DP 22:00 - 00:00 2.00 DRILL P PROD1 Perform Well Control Drill While Tripping, Held PJSM On Stripping Drill, Perform Stripping Drill 5/25/2006 00:00 - 02:30 2.50 DRILL P PROD1 Perform Weil Control Drill While Tripping, Held PJSM On Stripping Drill, Perform Stripping Drill at 5,800' 02:30 - 04:00 1.50 DRILL P PROD1 RIH to ES Cementer at 7,844' 04:00 - 04:30 0.50 DRILL P PROD1 Tag ES Cementer at 7,844', Break Circulation at 120 spm, 2,650 psi. Circulate DP Volume 140 bbis. Close Pipe Rams and Test 9-5/8" Casing to 4,000 psi, for 10 min. 04:30 - 05:30 1.00 DRILL P PROD1 Drilled ES Cementer at 7,844' WOB 3-5K, Rotary 15-30K, Bit Rev's 160 05:30 - 06:00 0.50 DRILL P PROD1 Circulate Bottoms Up at 120 spm, 2,115 psi 06:00 - 07:00 1.00 DRILL P PROD1 RIH Ti 9,825' 07:00 - 08:00 1.00 DRILL P PROD1 Circulated Bottoms Up at 120 spm, 2,250 psi 08:00 - 09:00 i.00 CASE P PROD1 Held PJSM; Tested Casing to 4,000 psi. Charted and Held for Printed: 6/5/2006 11:44:05 AM vNc~ awl la r71d111111C1f ~/ rS~F7oft Legal Well Name: AGI-07 Common WeII Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+CO MPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5!16/2006 Rig Name: NABOBS 27E Rig Number: 27E t D F T H T k ~ ~ NPT P f a e i rom - o ~ ours as Code ~ hase Description o Operations 5/25/2006 08:00 - 09:00 1.00 CASE P PROD1 30 min. 09:00 - 10:00 1.00 DRILL P PROD1 Service Top Drive, Removed Stabbing Board Winch 10:00 - 12:00 2.00 DRILL P PROD1 RIH and Tag Baffle Adaptrer at 9,873', Clean Out 9-5/8" Shoe Track to 9,956'. WOB 2-7K, Pump 450 gpm, 2,350 psi, 60 rpm, 2-7K Torque, Up Wt 285K, Dn Wt 160K, Rt Wt 198K. 12:00 - 12:30 0.50 DRILL P PROD1 Circulate Bottoms Up at 450 gpm, 2,250 psi 12:30 - 14:30 2.00 DRILL P PROD1 Displaced 10.4 ppg LSND Mud with 8.5 ppg Flo-Pro Mud, Pumped 100 bbis Water, 22 bbis 8.5 ppg 150 Vis Sweep at 5 bpm. Followed by 8.5 ppg Flo-Pro Mud at 9 bpm 14:30 - 15:30 1.00 DRILL P PROD1 Circulated and Conditoned Mud. Take SPR's on Both Pumps. Established ECD Basline at 9.11 ppg. Added 200 bbls 8,5 ppg Pro-Flo to Surface System 15:30 - 16:00 0.50 DRILL P PROD1 Drilled F/ 9,956' - T/ 9,980'. 16:00 - 16:30 0.50 DRILL P PROD1 Circulated 150 bbls at 450 gpm, 1,340 psi. 60 rpm, 13K Torque 16:30 - 17:00 0.50 DRILL P PROD1 Pulled Bit back into 9-5/8" Shoe at 9,958'. Closed Rams and Pressured up to 585 psi. EMW 10.0 ppg. Bled Down Pressure, Oped Rams. Monitored Well, Static 17:00 - 17:30 0.50 DRILL P PROD1 Drilled F/ 9,980 -T/ 10,009', 6K WOB, 550 gpm, 2,025 psi, 60 rpm, 15K Torque. Observed Increse in Flow at Flowline 17:30 - 18:30 1.00 DRILL P PROD1 P/U off Bottom, Shut Down Pumps and Checked for Flow. Observed Gas Breaking Out in Drilling Riser but NO Flow. Circulated Until Gas Cleared Up 18:30 - 00:00 5.50 DRILL P PROD1 Drilled F/ 10,009' -T/ 10,210'. Up Wt 285K, Dn Wt 160K, Rt Wt 198K, 10K WOB, 450 gpm, 1,960 psi On, 1,830 psi Off, 100 rpm, TO On 18K, TO Off 15K. Encountering Sporadic Gas Cut Mud. Continue to Check for Flow Whenever Obvserved Gas Cut Mud. Increased MW to 8.7 ppg. Baseline ECD Increased to 9.3ippg. After MW {ncrease Gas Concentration Decreased Dramatically 5/26/2006 00:00 - 09:30 9.50 DRILL P PRODt Drilled F/ 10,210' - T/ 10,525'. Up Wt 295K, Dn Wt 190K, Rt Wt 215K, 8-25 WOB, 550 gpm, 2,180 psi 100 rpm, TO On 19K, TO Off 15K 09:30 - 10:30 1.00 DRILL P PROD1 Circulated and Conditioned Mud, Pump 25 bbl 11.0 ppg 80 Vis Weighted Sweep at 650 gpm, 100 rpm. Slight Increase in Cuttings Volume at Bottoms Up. Monitor Well 10:30 - 12:00 1.50 DRILL P PROD1 Short Trip to 9-5/8" Shoe at 9,958', No Overpulls 12:00 - 13:00 1.00 DRILL P PROD1 Monitor Well, Service Top Drive, Crown and Blocks 13:00 - 14:00 1.00 DRILL P PROD1 RIH, at 10,460' Hole Started Taking Fluid, M/U Top Drive and Circulated Down to 10,525 at 4 bpm, 60 rpm 14:00 - 19:00 5.00 DRILL P PROD1 Circulated and Reciprocated at 100 rpm, 560 gpm, 2,160 psi, ECD 9.62. Observed Gas Cut Mud at Bottoms Up. Gas Cut MW 8.1 ppg. Bring MW Up to 9.0+ppg. Gas Cleaned Up After Circulating 9.0+ Surface to Surface. 19:00 - 20:00 1.00 DRILL P PROD1 POH to 9-5/8" Shoe at 9,958'. Pumped Out at 8 bpm W/O Rotating. 20:00 - 20:30 0.50 DRILL P PROD1 Monitor Well With Trip Tank. Static Losses of 2 bbis/hr. Pump Dry Job. MW in 9.0+, MW out 9.0+ 20:30 -_00:00 3.50 DRILL P PROD1 POH with 5" DP. Fluid Looses +/- 5 bph 5/27/2006 00:00 - 02:00 2.00 DRILL P PROD1 POH with 5" DP. Fluid Losses to Hole +/-5 bph While Tripping 02:00 - 03:30 1.50 DRILL P PROD1 Monitor Well, Hole Taking +/- 15 bph Static 03:30 - 04:30 1.00 DRILL P PROD1 POH with 8-1/2" BHA. UD 17 x 5" HWDP, Jars, 2 x NM Flex DC's. 04:30 - 05:30 1.00 DRILL P PROD1 Remove Radioactive Sources and Down Load MWD Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: AG I-07 AGI-07 Spud Date: 5/13/2006 REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 NABOBS ALASKA DRILLING I Rig Release: 5/16/2006 NABOBS 27E Rig Number: 27E Date From - To Hours Task Code; NPT 5/27/2006 05:30 - 07:30 2.00 DRILL P 07:30 - 08:30 1.00 CASE P 08:30 - 10:00 1.50 CASE P 10:00 - 10:30 0.50 CASE P 10:30 - 18:30 8.00 CASE P 18:30 - 19:00 I 0.501 CASE I P 19:00 - 19:30 I 0.501 CASE I P 19:30 - 20:00 I 0.501 CASE I P 20:00 - 21:00 I 1.001 CASE I P 21:00 - 22:30 I 1.501 CASE I P 22:30 - 00:00 1.50 CASE P 5/28/2006 00:00 - 10:30 10.50 CASE P 10:30 - 11:00 0.50 CASE P 11:00 - 12:00 1.00 EVAL P 12:00 - 12:30 0.50 EVAL P 12:30 - 14:30 2.00 EVAL P 14:30 - 15:30 1.00 EVAL P 15:30 - 16:00 I 0.501 EVAL I P 16:00 - 16:30 0.50 EVAL P 16:30 - 19:30 3.00 EVAL P 19:30 - 21:00 I 1.501 EVAL I P 21:00 - 00:00 3.00 EVAL P 5/29/2006 00:00 - 02:00 2.00 EVAL P 02:00 - 03:00 I 1.00 I EVAL I P 03:00 - 04:00 I 1.00 I EVAL I P Phase ' Description of Operations PROD1 POH and UD MWD, Stab, Motor and Bit RUNPRD PJSM; R/U Casing Tools and Handling Equipment RUNPRD RIH w/ 7" 26# L-80 BTC-M Perforated /Solid Liner and Baker 7" x 9-5/8" C-2 Packer. RUNPRD R/D Casing Equipment and Handling Tools RUNPRD RIH w/ 7" Liner on 5" DP. Filling DP Every 20 Stands. Tag Bottom at 10,525'. Mud Loss Rate 8-10 bph RUNPRD Drop 29/32" Ball and Pump on Seat With Rig Pumps at 10 bpm. Find Neutral Weight of 175K RUNPRD Pressured Up to 2,000 psi to Set Hanger. S/O to 100K and Up to 250K Ensure Hanger Set. S/O to 150K. Pressured Up to 3,500 psi to Set Packer. Held 5 min. Bled Down Pressure. Close Pipe Rams and Pressured Up Annulus to 1,000 psi to Test Packer, No Pressure Loss. Bled Down Pressure. Open Pipe Rams. Pressured Upon DP to 4,250 psi and Sheared Out Setting Ball. Rotated String 20 Turns to Right, Got 1Turn Back. P/U 30' and Clear Circulating Sub from Liner Tie-Back Sleeve. RUNPRD Displaced Well with 25 bbl Hi-Vis Sweep Followed By 25 bbls 9.0 Brine at 10 bpm. Pumps Starving, Shut Down Displacement RUNPRD Check Mud Pump Suction Screens. Pluged with Flo-Vis Plus. Cleaned Screens RUNPRD Continued to Displce the Well with 9.0 ppg Brine at 18 bpm, 1,100 psi. Taking All Returns to Slop Tank. Shut Down Pumps When Clean Brine at Surface, Pumped 75 bbls Extra. RUNPRD Clean Under Shakers, Possum Belly and Flush Flowline RUNPRD POH UD 5" DP. Fluid Losses +/- 15- 20 bph. RUNPRD UD Baker Liner Setting /Running Tool RUNPRD P/U Test Joint, Removed Wear Ring, UD Test Joint RUNPRD R/U Injection Line to Upper Side Outlet Annulus Valve, R/U Return Line from Opposite Side Outlet Annulus Valve to Flowline. Close Blind Rams. Circulate Across the Top of the Hole, Under the Blind Rams, to Monitor Fluid Losses OTHCMP PJSM Removed 4-1/2" x 7" Rams, Installed 9-5/8" Rams OTHCMP P/U 9-5/8" Test Joint, M/U Test Plug and Install, M/U Test Manifold OTHCMP Test 9-5/8" Rams, 250 psi low / 4,000 psi high, Test Held for 5 min. Witness of Test Waived by AOGCC Rep. Jeff Jones. Test Witnessed by WSL Chris Clemens OTHCMP Removed Test Plug, Installed Wear Ring, UD Test Joint OTHCMP PJSM with Rig Crew, Schlumberger E-Line Crew, Rig Supervisors. P/U E-Line BOPEs and Lubricator Extension. Installed Extension in Rig BOPE's and Close 9-5/8" Rams. R/U E-Line BOPE's and Lubricator. Hang Sheaves and String E-Line OTHCMP M/U E-Line BHA; USIT / CL / GR and Installed in Lubricator. Tested Lubricator to 500 psi. OTHCMP RIH with USIT / CL / GR. Started Logging Up From 9,800' OTHCMP Logging Up From 9,800' Inside 9-5/8" Casing with USIT / CL / GR Log OTHCMP PJSM; Remove Logging Tools from Lubricator. B/O and UD Logging BHA. OTHCMP Break Down lubricator, BOPE's and UD Same Printed: 6/5/2006 11:44:05 AM BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date 'From - To Hours Task ;Code NPT 5/29/2006 04:00 - 06:00 2.00 BOPSU P 06:00 - 06:30 0.50 BOPSU P 06:30 - 07:00 0.50 BOPSU P 07:00 - 07:30 0.50 BOPSU P 07:30 - 08:00 0.50 BOPSU P 08:00 - 10:00 2.00 BUNCO 10:00 - 11:00 I 1.00 11:00 - 12:00 1.00 RU 12:00 - 00:00 12.00 RU 5/30/2006 100:00 - 12:00 I 12.001 RUN 12:00 - 15:00 I 3.001 RUN 15:00 - 17:00 1 2.00 17:00 - 18:00 I 1.00 I RU 18:00 - 19:00 ~ 1.00 ~ RU 19:00 - 21:00 I 2.001 RU 21:00 - 21:30 I 0.501 RU 21:30 - 23:00 I 1.501 RUN 23:00 - 00:00 I 1.001 RUN 5/31/2006 00:00 - 01:30 1.50 BOPSUF~ P 01:30 - 03:00 1.50 BOPSU~} P Spud Date: 5/13/2006 Start: 4/26/2006 End: 5/31/2006 I Rig Release: 5/16/2006 Rig Number: 27E Phase Description of Operations __ ~___ RUNCMP PJSM; Removed 9-5/8" Rams and Installed 7-5/8" Rams RUNCMP P/U Test Joint and Pull Wear Ring RUNCMP M/U Test Plug and Set Same. R/U Test Manifold RUNCMP Test 7-5/8" Rams to 250 psi low / 4,000 psi high. Test Held for 5 min. Witness of Test Waived by AOGCC Rep. Jeff Jones. Test Witnessed by WSL Chris Clemens and Nabors Toolpusher Allen Lunda RUNCMP R/D Test Manifold, Pull Test Plug, UD Test Joint RUNCMP R/U Casing Equipment and Handling Tools, R/U Gator Hawk Connection Testing Equipment RUNCMP P/U 7-5/8" Landing Joint and Perform Dummy Run with 7-5/8" Tubing Hanger. UD Joint and Hanger. RUNCMP PJSM, P/U Mule Shoe / RN Nipple Assy, 7" x 9-5/8" Packer Assy. and R Nipple Assy. with 7" x 7-5/8" XO RUNCMP RIH w/ 7-5/8" 29.7# L-80 Vam Top Tubing. Torque Turn Each Connection to Optimum 14,450 fUlbs. Gater Hawk Each Connection to 3,800 psi RUNCMP RIH w/ 7-5/8" 29.7# L-80 Vam Top Tubing. Torque Turn Each Connection to Optimum 14,450 ft/Ibs. Gater Hawk Each Connection to 3,800 psi. P/U Joints #238 & #239. RUNCMP M/U Top Drive and Circulated Down at 3 bpm, 170 psi. Tag Bottom at 9,862', Did Not Observe Pump Pressure Increase When Entering the 7" Liner Tie Back Sleeve. Circulated Bottoms Up at 3 bpm, 170 psi. R/U Hot Oil While Circulating. RUNCMP B/O and L/D Joints # 239, #238 and #237. P/U 7-5/8" Pup Joints 19.54', 9.91' and 5.90'. P/U Joint # 237. RUNCMP L/D Casing Equipment and Handling Tools. R/D and UD Gater Hawk Equipment. RUNCMP M/U Tubing Hanger and Landing Joint. Landed Hanger in Tubing Head at 28.0'. RILDS. Bottom of Tubing Tail Pipe Set at 9,856'. Approximately 6' into 7" Tie Back Sleeve RUNCMP Reverse Circulated 134 bbls 9.0 Brine with Corrosion Inhibitor Down 7-5/8" x 9-5/8" Annulus at 3 bpm, 400 psi. Switch to Hot Oil and Followed with 40 bbls Diesel. Shut Down Pumps and Shut In Annulus. RUNCMP B/O Top Drive, Dropped 1-7/8" Ball and Rod, Removed Landing Joint and UD Same. RUNCMP Closed Blind Rams. Pressured Up on 7-5/8" Tubing with Rig pumps to 4,000 psi to Set Packer. Closed Kill Line Valve. Monitored Annulus for Fluid Flowback, No Flowback. Charted Test and Held Pressure for 30 min. Bled Tubing Pressure Down to 2,000 psi. Pressured up 7-5/8" x 9-5/8" Annulus with Hot Oil to 4,000 psi. to Test Packer. Tubing Pressure Increased to 2,900 psi. Charted and Held Annulus Pressure for 30 Min. Bled Down Annulus Pressure, Bled Down Tubing Pressure. AOGCC Rep. Jeff Jones Wavied Witnessing of Test. All Tested Witnessed by WSL Rodney Klepzig RUNCMP Blew Down all Lines. R/D Hot Oil. R/D Reverse Circulating Lines. RUNCMP R/U Diaphram Pump and Suck Out Excess Fluid from BOPE's RUNCMP M/U TWC to Running Tool, Make Repeated Attempts to Set TWC. Flush Tubing Hanger with Fresh Water. Remove Excess Water from BOPE's. Installed TWC. L/D T-Bar Running Tool Printed: 6/5/2006 71:44:05 AM BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: AGI-07 Common Well Name: AGI-07 Spud Date: 5/13/2006 Event Name: REENTER+COMPLETE Start: 4/26/2006 End: 5/31/2006 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 5/16/2006 Rig Name: NABOBS 27E Rig Number: 27E Date ;From - To Hours ' Task ~ Code ; NPT 5/31/2006 03:00-03:30 0.50 BOPSU P 03:30 - 05:00 1.50 BOPSU ~ P 05:00 - 10:30 5.50 BOPSU P 10:30 - 14:30 4.00 WHSUR P 14:30 - 15:00 0.50 WHSUR P 15:00- 17:00 2.00 WHSUR P 17:00 - 18:30 1.50 DHEOP P 18:30-19:30 1.00 WHSUR P 19:30 -22:00 2.50 WHSUR P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 WHSUR P Phase Description of Operations RUNCMP Test TWC to 1,000 psi. Remove Excess Water from BOPE's RUNCMP Remove 7-5/8" Rams and Installed 4-1/2" x 7" Variable Rams RUNCMP PJSM; Remove BOPE Securing Turnbuckles, UD Flowline and Pull Drilling Riser to Rig Floor, N/D BOPE's and Stand Back on Cellar Pedistal RUNCMP N/U Adapter Flange and Test Void to 5,000 psi. N/U Tree and Test to 5,000 psi RUNCMP R/U DSM Lubricator and Pull TWC, R/D Lubricator RUNCMP PJSM; R/U Schlumberger Lubricator Risers, BOPE's, Wiper Head and Hung Sheeves, Tested Lubricator to 3,000 psi. RUNCMP RIH with Rod Catcher on SLickline, Latch Rod and Pull Loose, Filled Hole with Rig, Hole Took 40 bbls, POH with Rod and Ball RUNCMP R/D Schlumberger Tools, Slickline, BOPE's and Lubricator Risers RUNCMP R/U Hot Oil and Bullheaded 100 bbls Diesel Down Tubing at 4 bpm, 1,100 psi. R/D Hot Oil RUNCMP R/U DSM Lubricator and Installed BPV, 0 psi on Well, R/D Lubricator RUNCMP Secure Well, Clean Cellar Area, RIG RELEASED AT 2400 HRS 5/31/06 Printed: 6/5/2006 11:44:05 AM - ~ Halliburton Company ~' Survey Report _ _ -_ -_ I)atc h 8%2006 Timc __ __ : 93-13.25 Pakc: 1 Company: Fi ld BP Amoco Prudhoe Bay (various) C'o-o~dm itcI~E112cferuui Well: AGI-07, Tn1P North e : i A(I A~cnc~al (l AU) Ketcrcncct 33.5 + 13-5 47.0 S t c: Sectmn 1~ti1 KcC~rence: Well (0.ODN,O.OOE,7313P,zi) Nell: AGI-07 tiur~c. C~Iculauun ~lcthud: Minimum Curvature Db: Oracle ~Fclipath: AGI-07AP81 ___ ~ Field: Prudhoe Bay (various) Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Well: AGI-07 AGI-07 We1lPosition: +N/-S 6546.81 ft Northing: 5979929.37 ft +E/-W 3913.91 ft Easting : 688757.89 ft Position Uncertainty: 0.00 ft Wellpath: AGI-07APB1 500292234370 Current Datum: 33.5 + 13.5 Height 47.00 ft Magnetic Data: 5/5/2006 Field Strength: 57617 nT Vertical Section: Depth From (TVD) +N/-S ft ft 33.50 0.00 Survey Program for Definitive Wellpath Date: 6!8/2006 Validated: Yes Actual From To Survey ft ft 39.40 3921.25 1 : Schlumberger GCT multishot 3941.00 9649.74 AGI-07APB1 IIFR (3941.00-9649. Survey _ _ ____ ___ MD Inch ~zim h~'p Sys TVD ft deg deg ft ft 33.50 0.00 0.00 33.50 13.50 39.40 0.04 207.99 39.40 -7.60 52.80 0.11 181.35 52.80 5.80 66.20 0.11 182.21 66.20 19.20 79.60 0.11 183.81 79.60 32.60 89.30 0.11 181.52 89.30 42.30 98.40 0.10 176.58 98.40 51.40 107.60 0.11 175.21 107.60 60.60 116.75 0.13 177.79 116.75 69.75 126.00 0.14 183.23 126.00 79.00 135.25 0.16 190.41 135.25 88.25 144.60 0.15 189.15 144.60 97.60 153.85 0.14 182.49 153.85 106.85 163.15 0.13 183.85 163.15 116.15 172.45 0.13 182.78 172.45 125.45 181.75 0.12 175.78 181.75 134.75 191.10 0.11 174.19 191.10 144.10 200.45 0.11 176.83 200.45 153.45 209.75 0.11 176.54 209.75 162.75 219.15 0.10 176.43 219.15 172.15 228.45 0.11 181.83 228.45 181.45 238.25 0.12 186.17 238.25 191.25 252.55 0.12 184.47 252.55 205.55 266.85 0.13 181.41 266.85 219.85 280.95 0.14 179.61 280.95 233.95 295.05 0.13 177.73 295.05 248.05 309.25 0.13 178.30 309.25 262.25 323.50 0.12 178.03 323.50 276.50 332.20 0.12 179.83 332.20 285.20 Map Zone: Coordinate System: Geomagnefic Model: Slot Name: Latitude: Longitude: Alaska, Zone 4 Well Centre bggm2005 70 20 59.646 N 148 28 2.673 W Drilled From: AGI-07 Tie-on Depth: 3921.25 ft Above System Datum: Mean Sea Level Declination: 24.65 deg Mag Dip Angle: 80.94 deg +E/-W Direction ft deg 0.00 73.13 Version: 2 Toolcode Tool Name GCT-MS Schlumberger GCT multishot MWD+IFR+MS MWD +IFR + Multi Station N/S E/W MapN MapE Tool ft ft ft ft ---- 00 0 0.00 _ 5979929.37 _ 688757.89 TIE LINE . 00 0 0.00 5979929.37 688757.89 GCT-MS . 02 -0 0.00 5979929.35 688757.89 GCT-MS . 04 -0 0.00 5979929.33 688757.89 GCT-MS . -0.07 -0.01 5979929.30 688757.89 GCT-MS 09 -0 -0.01 5979929.28 688757.89 GCT-MS . 11 -0 -0.01 5979929.26 688757.89 GCT-MS . 12 -0 -0.01 5979929.25 688757.89 GCT-MS . 14 -0 0.00 5979929.23 688757.89 GCT-MS . -0.16 0.00 5979929.21 688757.89 GCT-MS 19 -0 -0.01 5979929.18 688757.89 GCT-MS . 21 -0 -0.01 5979929.16 688757.88 GCT-MS . -0.24 -0.01 5979929.13 688757.88 GCT-MS 26 -0 -0.02 5979929.11 688757.88 GCT-MS . -0.28 -0.02 5979929.09 688757.88 GCT-MS 30 -0 -0.02 5979929.07 688757.88 GCT-MS . 32 -0 -0.01 5979929.05 688757.88 GCT-MS . 34 -0 -0.01 5979929.03 688757.89 GCT-M5 . 35 -0 -0.01 5979929.02 688757.89 GCT-MS . -0.37 -0.01 5979929.00 688757.89 GCT-MS -0.39 -0.01 5979928.98 688757.89 GCT-MS 41 -0 -0.01 5979928.96 688757.89 GCT-MS . 44 -0 -0.01 5979928.93 688757.89 GCT-MS . 47 -0 -0.02 5979928.90 688757.89 GCT-MS . -0.50 -0.02 5979928.87 688757.89 GCT-MS 53 -0 -0.02 5979928.84 688757.89 GCT-MS . 57 -0 -0.01 5979928.80 688757.89 GCT-MS . 60 -0 -0.01 5979928.77 688757.89 GCT-MS . -0.62 -0.01 5979928.75 688757.89 GCT-MS 0 - • Halliburton Company Survey Report I Comp:~m~: BP Ar~~oco Field: Prudhoe bay {various) tine: AGI Wdl: AGI-07 Wcllpatfl: AGI-07APB1 Ua~c: 6i8i2006 Timc: 08-1325 1':~gc Co-urdinate(~H~) Reference: Well: AGI-07, True tdorth ~erlic:~l (TVD) Reference: 33.5 + 13.5 47.0 Section (Vti) Reference Well (0-OON,O.OOE,73.13Azi) Survey Culcnlatim~ }lerhod: Minimum Curvature un: 3 racle Su r~ ev X11) Ind Azim TVD S~sTVD N/S E/W' tap` MapE Tool ft deg deg ft ft ft ft ft ft i -- 1226.75 7.84 73.67 1223.79 1176.79 -- __ 19.25 55.18 - 5979950.01 688812.57 GCT-MS - 1243.85 7.96 73.72 1240.73 1193.73 19.91 57.44 5979950.72 688814.80 GCT-MS 1260.95 8.07 73.70 1257.66 1210.66 20.58 59.73 5979951.45 688817.08 GCT-MS 1278.05 8.16 73.48 1274.59 1227.59 21.26 62.04 5979952.19 688819.37 GCT-MS 1295.05 8.25 73.05 1291.41 1244.41 21.96 64.37 5979952.95 688821.68 GCT-MS 1312.15 8.35 72.59 1308.34 1261.34 22.69 66.72 5979953.73 688824.02 GCT-MS 1329.25 8.46 72.13 1325.25 1278.25 23.45 69.11 5979954.55 688826.38 GCT-MS 1346.25 8.58 71.69 1342.06 1295.06 24.23 71.50 5979955.39 688828.75 GCT-MS 1363.30 8.67 71.11 1358.92 1311.92 25.05 73.92 5979956.27 688831.15 GCT-MS 1380.30 8.76 70.58 1375.73 1328.73 25.89 76.36 5979957.18 688833.57 GCT-MS 1397.35 8.87 70.39 1392.57 1345.57 26.77 78.82 5979958.11 688836.01 GCT-MS 1414.40 9.00 70.34 1409.42 1362.42 27.66 81.31 5979959.06 688838.48 GCT-MS 1431.45 9.15 70.28 1426.25 1379.25 28.56 83.85 5979960.03 688840.98 GCT-MS 1448.70 9.26 70.22 1443.28 1396.28 29.49 86.44 5979961.03 688843.56 GCT-MS 1466.10 9.33 70.32 1460.45 1413.45 30.44 89.09 5979962.05 688846.18 GCT-MS 1483.10 9.41 70.57 1477.23 1430.23 31.37 91.70 5979963.04 688848.76 GCT-MS 1500.20 9.47 70.81 1494.09 1447.09 32.30 94.34 5979964.03 688851.38 GCT-MS 1517.10 9.55 71.08 1510.76 1463.76 33.21 96.98 5979965.01 688854.00 GCT-MS 1533.85 9.63 71.36 1527.28 1480.28 34.11 99.62 5979965.97 688856.62 GCT-MS 1550.55 9.68 71.63 1543.74 1496.74 35.00 102.28 5979966.93 688859.25 GCT-MS 1567.30 .9.77 71.98 1560.25 1513.25 35.88 104.97 5979967.88 688861.91 GCT-MS 1584.00 9.90 72.34 1576.71 1529.71 36.75 107.68 5979968.82 688864.61 GCT-MS 1601.25 10.03 72.49 1593.70 1546.70 37.65 110.53 5979969.79 688867.43 GCT-MS 1619.75 10.17 72.60 1611.91 1564.91 38.63 113.62 5979970.85 688870.50 GCT-MS 1645.65 10.38 72.84 1637.39 1590.39 40.00 118.03 5979972.33 688874.87 GCT-MS 1671.85 10.60 73.08 1663.16 1616.16 41.40 122.60 5979973.84 688879.40 GCT-MS 1697.85 10.78 73.11 1688.70 1641.70 42.80 127.21 5979975.36 688883.97 GCT-MS 1723.85 10.93 73.18 1714.24 1667.24 44.22 131.90 5979976.90 688888.62 GCT-MS 1750.20 11.14 73.45 1740.10 1693.10 45.67 136.73 5979978.46 688893.42 GCT-MS 1776.85 11.51 73.56 1766.23 1719.23 47.15 141.75 5979980.08 688898.39 GCT-MS 1803.55 12.12 73.70 1792.37 1745.37 48.69 146.99 5979981.75 688903.60 GCT-MS 1830.45 13.09 73.98 1818.62 1771.62 50.33 152.63 5979983.52 688909.19 GCT-MS 1857.30 14.53 73.95 1844.69 1797.69 52.10 158.79 5979985.45 688915.31 GCT-MS 1884.40 16.19 73.19 1870.82 1823.82 54.13 165.67 5979987.65 688922.14 GCT-MS 1911.30 17.74 72.07 1896.55 1849.55 56.48 173.16 5979990.19 688929.56 GCT-MS 1938.40 19.23 70.88 1922.25 1875.25 59.21 181.31 5979993.12 688937.64 GCT-MS 1965.50 20.52 70.18 1947.74 1900.74 62.28 189.99 5979996.41 688946.24 GCT-MS 1992.65 21.30 70.10 1973.10 1926.10 65.57 199.11 5979999.93 688955.27 GCT-MS 2019.85 21.65 70.21 1998.41 1951.41 68.95 208.47 5980003.55 688964.55 GCT-MS 2046.85 21.89 70.38 2023.49 1976.49 72.33 217.90 5980007.16 688973.89 GCT-MS 2073.85 22.06 70.51 2048.52 2001.52 75.71 227.42 5980010.78 688983.32 GCT-MS 2100.85 22.20 70.61 2073.53 2026.53 79.10 237.01 5980014.41 688992.82 GCT-MS 2127.85 22.36 70.71 2098.52 2051.52 82.49 246.67 5980018.04 689002.39 GCT-MS 2155.05 22.64 70.91 2123.65 2076.65 85.91 256.50 5980021.71 689012.13 GCT-MS 2182.40 23.11 71.15 2148.85 2101.85 89.36 266.56 5980025.42 689022.09 GCT-MS 2209.80 23.82 71.36 2173.98 2126.98 92.87 276.89 5980029.18 689032.33 GCT-MS 2237.20 24.57 71.28 2198.97 2151.97 96.47 287.53 5980033.04 689042.88 GCT-MS 2264.65 25.24 70.88 2223.87 2176.87 100.22 298.46 5980037.07 689053.71 GCT-MS 2292.10 25.87 70.49 2248.64 2201.64 104.13 309.64 5980041.26 689064.79 GCT-MS 2319.55 26.44 70.23 2273.28 2226.28 108.20 321.03 5980045.62 689076.07 GCT-MS 2347.00 27.15 70.00 2297.78 2250.78 112.41 332.67 5980050.12 689087.60 GCT-MS 2374.75 27.99 69.86 2322.38 2275.38 116.82 344.73 5980054.83 689099.55 GCT-MS 2402.55 28.75 69.92 2346.84 2299.&1 121.36 357.14 5980059.68 689111.83 GCT-MS i Halliburton Company Survey Report Compam~: BP Amoro Date: 6/8/2006 Time: 08.13-25 Page: 4~ Field: Pru dhoe B~iy (various) Cu-or dinaec(.A E) Reference: VJell: AGI-07. Tr ue Nr~rth Silt: AG I ~crtical (~1 ~'lli Rc fcrcncc 33.5 + 13.5 47.0 ~~cll: AG I-07 Sectiu u (~'tii Refer ence: Well (0-OON.O OO E,73.13Azi) ~~cllpath: AG I-07APB1 Surcc ~ Calculn~lu n 6terhod: Minirnwn Curvat ure Ub: Oracle Suncv hID Incl Azim "FVll Sys "1 t'D N/S E/W >1ap~ MapE Tool ft dey deg ft ft ft ft ft i•t 2430.15 29.30 70.09 2370.97 2323.97 125.94 369.72 5980064.57 689124.30 GCT-MS 2457.40 29.65 70.30 2394.69 2347.69 130.48 382.33 5980069.43 689136.79 GCT-MS 2484.50 29.96 70.50 2418.21 2371.21 135.00 395.02 5980074.27 689149.36 GCT-MS 2511.50 30.47 70.82 2441.54 2394.54 139.50 407.84 5980079.09 689162.07 GCT-MS 2538.00 31.30 71.16 2464.28 2417.28 143.93 420.71 5980083.84 689174.81 GCT-MS 2564.85 32.47 71.43 2487.08 2440.08 148.48 434.14 5980088.73 689188.13 GCT-MS 2591.70 33.73 71.53 2509.57 2462.57 153.13 448.04 5980093.73 689201.91 GCT-MS 2618.55 34.72 71.48 2531.77 2484.77 157.92 462.36 5980098.88 689216.10 GCT-MS 2645.45 35.41 71.42 2553.79 2506.79 162.84 477.02 5980104.16 689230.62 GCT-MS 2672.30 35.79 71.40 2575.62 2528.62 167.82 491.83 5980109.52 689245.31 GCT-MS 2699.15 35.95 71.44 2597.38 2550.38 172.84 506.74 5980114.91 689260.09 GCT-MS 2726.00 36.08 71.56 2619.10 2572.10 177.85 521.71 5980120.29 689274.93 GCT-MS 2752.75 36.24 71.66 2640.70 2593.70 182.83 536.69 5980125.64 689289.77 GCT-MS 2779.60 36.51 71.60 2662.31 2615.31 187.84 551.80 5980131.04 689304.75 GCT-MS 2806.10 36.96 71.41 2683.55 2636.55 192.87 566.84 5980136.45 689319.65 GCT-MS 2832.60 37,66 70.95 2704.63 2657.63 198.05 582.04 5980142.01 689334.72 GCT-MS 2859.10 38.27 70.57 2725.52 2678.52 203.43 597.43 5980147.77 689349.97 GCT-MS 2885.65 38,58 70.53 2746.32 2699.32 208.92 612.99 5980153.65 689365.39 GCT-MS 2912.45 38.78 70.65 2767.24 2720.24 214.49 628.79 5980159.61 689381.04 GCT-MS 2939.25 38.98 70.80 2788.11 2741.11 220.04 644.67 5980165.56 689396.77 GCT-MS 2966.05 39.34 70.89 2808.89 2761.89 225.59 660.65 5980171.52 689412.61 GCT-MS 2992.90 40.01 71.03 2829.55 2782.55 231.19 676.86 5980177.52 689428.67 GCT-MS 3019.65 40.88 71.18 2849.91 2802.91 236.80 693.27 5980183.55 689444.94 GCT-MS 3046.50 41.76 71.29 2870.07 2823.07 242.51 710.06 5980189.67 689461.57 GCT-MS 3073.25 42.67 71.45 2889.89 2842.89 248.25 727.09 5980195.84 689478.45 GCT-MS 3100.00 43.65 71.86 2909.40 2862.40 254.01 744.46 5980202.03 689495.67 GCT-MS 3126.80 44.56 72.52 2928.64 2881.64 259.71 762.22 5980208.18 689513.28 GCT-MS 3153.40 45.17 73.17 2947.50 2900.50 265.25 780.15 5980214.17 689531.06 GCT-MS 3179.90 45.49 73.87 2966.13 2919.13 270.59 798.22 5980219.96 689548.99 GCT-MS 3206.45 45.68 74.53 2984.71 2937.71 275.75 816.47 5980225.59 689567.10 GCT-MS 3233.00 45.83 74.90 3003.23 2956.23 280.77 834.81 5980231.06 689585.32 GCT-MS 3259.75 45.79 75.09 3021.88 2974.88 285.73 853.34 5980236.49 689603.71 GCT-MS 3286.35 45.54 75.26 3040.47 2993.47 290.60 871.73 5980241.82 689621.97 GCT-MS 3312.95 45.31 75.49 3059.14 3012.14 295.39 890.07 5980247.06 689640.18 GCT-MS 3339.65 45.23 75.56 3077.93 3030.93 300.13 908.43 5980252.27 689658.42 GCT-MS 3366.45 45.29 75.29 3096.79 3049.79 304.92 926.86 5980257.52 689676.72 GCT-MS 3393.30 45.41 74.81 3115.66 3068.66 309.85 945.31 5980262.91 689695.04 GCT-MS 3420.90 45.52 74.25 3135.02 3088.02 315.09 964.27 5980268.63 689713.86 GCT-MS 3447.90 45.52 73.54 3153.93 3106.93 320.44 982.78 5980274.44 689732.23 GCT-MS 3474.90 45.32 72.42 3172.89 3125.89 326.07 1001.17 5980280.53 689750.47 GCT-MS 3501.30 45.06 71.30 3191.49 3144.49 331.90 1018.97 5980286.81 689768.11 GCT-MS 3527.40 44.91 70.73 3209.95 3162.95 337.90 1036.41 5980293.25 689785.40 GCT-MS 3553.45 44.82 70.59 3228.42 3181.42 343.99 1053.75 5980299.77 689802.58 GCT-MS 3579.45 44.62 70.62 3246.89 3199.89 350.06 1071.01 5980306.28 689819.68 GCT-MS 3605.65 44.34 70.80 3265.58 3218.58 356.12 1088.34 5980312.77 689836.85 GCT-MS 3631.90 44.07 71.04 3284.40 3237.40 362.11 1105.63 5980319.19 689853.99 GCT-MS 3658.25 43.88 71.26 3303.36 3256.36 368.02 1122.95 5980325.54 689871.15 GCT-MS 3684.60 43.86 71.40 3322.36 3275.36 373.86 1140.25 5980331.81 689888.29 GCT-MS 3710.90 44.00 71.35 3341.30 3294.30 379.69 1157.54 5980338.08 689905.43 GCT-MS 3737.30 44.28 70.94 3360.25 3313.25 385.63 1174.94 5980344.45 689922.67 GCT-MS 3763.60 44.59 70.43 3379.03 3332.03 391.72 1192.31 5980350.98 689939.89 GCT-MS 3789.90 44.87 70.19 3397.71 3350.71 397.96 1209.74 5980357.65 689957.15 GCT-MS i' ' • Halliburton Company Survey Report ~ Company: BP AnlOCO --_ Date: 6!812006 Time: 08:1325 Pa~;r. 5 I ' Fieltl: Pru dhoe Bay (various) Co-o nlinutcl~t~:) F tcfcrrnce: Well. AGI-07 Tr ue Narth Site: AGI Verti cal (I'll) Ke fcrencc: 33.5 + 13.5 47.0 Nell: AGI -07 ticcti uu (~'SI Nefa ~aice: Well (O.OON,O.OO E;73 13Azi) N'dlpath: AGI -07APB1 4ur~e ~ Calculatio n ~~lclhud: Minimum Curvature Db: Orade Suncv -- h1D lncl Azim TVD Sys "i~'D -- N/S E1W A1ap1' Map E: - Tool ft deg _ deg - _ ft ft ft ft ft ft - __ 3816.30 44.99 70.15 3416.40 3369.40 404.29 _ 1227.28 5980364.42 _ 689974.52 GCT-MS 3842.50 45.03 70.17 3434.92 3387.92 410.57 1244.71 5980371.14 689991.79 GCT-MS 3868.55 45.12 70.21 3453.32 3406.32 416.82 1262.06 5980377.83 690008.98 GCT-MS 3894.55 45.23 70.23 3471.65 3424.65 423.07 1279.42 5980384.50 690026.17 GCT-MS 3921.25 44.97 70.27 3490.50 3443.50 429.46 1297.22 5980391.34 690043.80 GCT-MS 3941.00 44.55 70.33 3504.52 3457.52 434.14 1310.31 5980396.35 690056.77 MWD+IFR+MS 3964.24 43.49 72.24 3521.23 3474.23 439.33 1325.60 5980401.92 690071.93 MWD+IFR+MS 4060.80 39.46 81.00 3593.63 3546.63 454.28 1387.63 5980418.43 690133.55 MWD+IFR+MS 4154.58 38.50 75.77 3666.55 3619.55 466.12 1445.37 5980431.72 690190.98 MWD+IFR+MS 4251.88 40.17 74.90 3741.80 3694.80 481.74 1505.03 5980448.84 690250.22 MWD+IFR+MS 4345.43 40.27 75.12 3813.23 3766.23 497.37 1563.39 5980465.93 690308.16 MWD+IFR+MS 4440.85 41.26 69.80 3885.52 3838.52 516.16 1622.74 5980486.21 690367.02 MWD+IFR+MS 4531.55 41.19 72.25 3953.75 3906.75 535.59 1679.25 5980507.06 690423.02 MWD+IFR+MS 4626.96 41.37 72.39 4025.45 3978.45 554.71 1739.23 5980527.68 690482.49 MWD+IFR+MS 4709.09 41.94 73.33 4086.81 4039.81 570.79 1791.39 5980545.07 690534.23 MWD+IFR+MS 4819.17 42.40 73.55 4168.40 4121.40 591.85 1862.22 5980567.91 690604.50 MWD+IFR+MS 4912.41 42.99 73.51 4236.93 4189.93 609.78 1922.86 5980587.35 690664.66 MWD+IFR+MS 5006.74 43.56 73.04 4305.61 4258.61 628.39 1984.78 5980607.52 690726.10 MWD+IFR+MS 5092.10 41.48 74.22 4368.52 4321.52 644.66 2040.13 5980625.17 690781.01 MWD+IFR+MS 5199.65 40.99 73.54 4449.40 4402.40 664.34 2108.23 5980646.56 690848.59 MWD+IFR+MS 5294.05 41.53 72.83 4520.36 4473.36 682.35 2167.82 5980666.07 690907.71 MWD+IFR+MS 5387.41 41.64 72.46 4590.19 4543.19 700.83 2226.96 5980686.03 690966.36 MWD+IFR+MS 5483.37 41.57 71.50 4661.94 4614.94 720.54 2287.55 5980707.26 691026.43 MWD+IFR+MS 5578.89 41.72 72.05 4733.32 4686.32 740.40 2347.84 5980728.62 691086.20 MWD+IFR+MS 5676.64 41.51 71.56 4806.40 4759.40 760.67 2409.52 5980750.44 691147.34 MWD+IFR+MS 5770.18 40.67 72.25 4876.90 4829.90 779.76 2467.95 5980771.00 691205.27 MWD+IFR+MS 5862.09 41.01 71.84 4946.44 4899.44 798.29 2525.13 5980790.96 691261.96 MWD+IFR+MS 5955.95 41.22 72.08 5017.15 4970.15 817.41 2583.81 5980811.55 691320.14 MWD+IFR+MS 6049.56 39.93 71.88 5088.25 5041.25 836.24 2641.71 5980831.83 691377.55 MWD+IFR+MS 6145.15 40.12 72.81 5161.45 5114.45 854.88 2700.29 5980851.95 691435.63 MWD+IFR+MS 6241.46 40.45 73.82 5234.92 5187.92 872.76 2759.94 5980871.32 691494.81 MWD+IFR+MS 6335.25 40.50 73.75 5306.27 5259.27 889.76 2818.40 5980889.78 691552.82 MWD+IFR+MS 6429.50 39.77 74.34 5378.32 5331.32 906.46 2876.81 5980907.95 691610.79 MWD+IFR+MS 6524.69 39.73 74.93 5451.51 5404.51 922.59 2935.51 5980925.55 691669.05 MWD+IFR+MS 6619.73 39.68 75.02 5524.63 5477.63 938.33 2994.15 5980942.76 691727.27 MWD+IFR+MS 6713.64 38.74 76.34 5597.39 5550.39 953.02 3051.66 5980958.89 691784.40 MWD+IFR+MS 6805.45 38.89 76.72 5668.93 5621.93 966.42 3107.63 5980973.70 691840.00 MWD+IFR+MS 6896.91 38.97 76.98 5740.08 5693.08 979.50 3163.59 5980988.18 691895.62 MWD+IFR+MS 6993.87 40.53 74.09 5814.63 5767.63 995.01 3223.60 5981005.20 691955.22 MWD+IFR+MS 7092.99 44.75 70.01 5887.54 5840.54 1015.77 3287.40 5981027.57 692018.47 MWD+IFR+MS 7188.22 45.21 70.64 5954.90 5907.90 1038.44 3350.79 5981051.82 692081.26 MWD+IFR+MS 7284.12 45.80 70.87 6022.11 5975.11 1060.98 3415.37 5981075.98 692145.25 MWD+IFR+MS 7377.80 45.01 70.10 6087.88 6040.88 1083.26 3478.25 5981099.84 692207.54 MWD+IFR+MS 7472.36 45.23 71.11 6154.61 6107.61 1105.51 3541.45 5981123.67 692270.16 MWD+IFR+MS 7566.60 42.79 70.43 6222.38 6175.38 1127.07 3603.27 5981146.77 692331.41 MWD+IFR+MS 7661.65 42.91 70.96 6292.07 6245.07 1148.44 3664.28 5981169.67 692391.86 MWD+IFR+MS 7757.00 42.23 70.85 6362.29 6315.29 1169.54 3725.23 5981192.30 692452.26 MWD+IFR+MS 7851.47 40.72 70.80 6433.07 6386.07 1190.09 3784.32 5981214.33 692510.81 MWD+IFR+MS 7945.05 39.47 71.48 6504.65 6457.65 1209.58 3841.36 5981235.25 692567.33 MWD+IFR+MS 8040.41 39.93 71.42 6578.02 6531.02 1228.95 3899.10 5981256.07 692624.57 MWD+IFR+MS 8134.12 39.31 71.69 6650.21 6603.21 1247.86 3955.79 5981276.40 692680.76 MWD+IFR+MS 8229.02 39.61 71.32 6723.48 6676.48 1266.99 4012.99 5981296.97 692737.45 MWD+IFR+MS 8323.87 39.95 71.93 6796.37 6749.37 1286.12 4070.58 5981317.54 692794.54 MWD+IFR+MS Halliburton Company Survey Report Cumpa3i~~: BP Amoco llate: 613,'2006 Time: Od:13 25 Page: fi }field: Prudhoe Bay (vanousj Cu-o rdinah~tl'N:) Reference: Well- AGI-07. Tr ue North Site: AGI ~ crti cal ('lll)) kc (crencc: 33.5 + 13.5 47.0 I ~tcll: AGI -07 ticcti un (~~Sf Refe rence: Well (O OON.O OO E 73-13Azij ~te[Ipatfi: AGI-07APB1 tiur~ c~ Cnlcululiu u ylethoii: Minimum Curvat ure Ut,: Orade Survey Mb tod Azim I ~ D Scs "T~ D N/S E/~1` A1:ipN i1spE Tool ft deg deg ft ft ft ft rt ft 8419.12 40.09 71.55 6869.31 6822.31 1305.32 4128.75 5981338.19 692852.20 MWD+IFR+MS 8513.65 40,45 71.61 6941.44 6894.44 1324.62 4186.72 5981358.95 692909.67 MWD+IFR+MS 8608.91 40.72 72.10 7013.78 6966.78 1343.92 4245.61 5981379.73 692968.05 MWD+IFR+MS 8703.01 40,00 72.31 7085.49 7038.49 1362.55 4303.64 5981399.80 693025.58 MWD+IFR+MS 8797.73 39.29 72.16 7158.42 7111.42 1380.99 4361.19 5981419.68 693082.65 MWD+IFR+MS 8892.95 38.79 71.49 7232.38 7185.38 1399.69 4418.17 5981439.82 693139.14 MWD+IFR+MS 8986.36 37.91 71.69 7305.63 7258.63 1418.00 4473.16 5981459.50 693193.65 MWD+IFR+MS 9083.01 39.26 73.89 7381.19 7334.19 1435.81 4530.74 5981478.76 693250.75 MWD+IFR+MS 9178.18 41.70 75.75 7453.57 7406.57 1451.96 4590.36 5981496.41 693309.95 MWD+IFR+MS 9273.16 41.79 75.86 7524.44 7477.44 1467.47 4651.67 5981513.45 693370.84 MWD+IFR+MS 9368.43 41.82 76.25 7595.46 7548.46 1482.77 4713.30 5981530.30 693432.07 MWD+IFR+MS 9462.62 45.29 77.81 7663.71 7616.71 1497.31 4776.54 5981546.43 693494.92 MWD+IFR+MS 9555.54 48.72 81.98 7727.08 7680.08 1509.16 4843.42 5981559.96 693561.48 MWD+IFR+MS 9586.91 48.83 84.67 7747.75 7700.75 1511.90 4866.85 5981563.29 693584.83 MWD+IFR+MS 9622.82 49.45 89.55 7771.25 7724.25 1513.26 4893.96 5981565.33 693611.89 MWD+IFR+MS 9649.74 51.54 93.15 7788.38 7741.38 1512.77 4914.72 5981565.36 693632.65 MWD+IFR+MS 9730.00 51.54 93.15 7838.30 7791.30 1509.31 4977.47 5981563.49 693695.47 PROJECTED Halliburton Company Survey Report Company: BP Amoco Date: 6i2i2006 I~inre: OS26.14 Pake: ] Field: Prudhoe Bay (various) Co-onlinalcl.AIJ kcfcrencc: Well. AGI-07, Tr ue North Sfle: AGI Ve rtical (ll'll) Re ference: 33.5 + 13.5 47.0 ~1e11: AGI-07 Section (~'ti) IZefcr rncc Well (O OON.O.OO E.72-86Azi) ~~"ellpath: AGI-07A Survey Calculnriuu ~teihud: Minimum Curvature Db: Crracle 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: bggm2005 Well: AGI-07 Slot Name: AGI-07 Well Position: +N/-S 6546.81 ft Northing: 5979929.37 ft Latitude: 70 20 59.646 N +E/-W 3913.91 ft Easti ng : 688757.89 ft Longitude: 148 28 2.673 W Position Uncertainty: 0.00 ft Wellpath: AGI-07A Drilled From: AGI-07AP61 500292234301 Tie-on Depth: 9368.43 ft Current Datum: 33 .5 + 13.5 Height 47.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/5/2006 Declination: 24.65 deg Field Strength: 57617 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direcfion ft ft ft deg 33.50 0.00 0.00 72.86 Survey Program for DeTinitive Wellpath Date: 6/8/2006 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 39.40 3921.25 1 : Schlum berger GCT multishot G CT-MS Schlumberger GCT multishot 3941.00 9368.43 AGI-07APB1 IIFR (3 941.00-9649. MWD+IFR+MS MWD +IFR + Multi Stati on 9417.00 10469.73 AGI-07A (9417.00-1 0469.73) MWD+IFR+MS MWD +IFR + Multi Stati on Survey Mll fncl Azim fVD Sys TVD N1S E/~~ Map\ MapE Tool ft deg deg ft ft ft ft ft ft 33.50 0.00 0.00 33.50 -13.50 0.00 0.00 5979929.37 688757.89 TIE LINE 39.40 0.04 207.99 39.40 -7.60 0.00 0.00 5979929.37 688757.89 GCT-MS 52.80 0.11 181.35 52.80 5.80 -0.02 0.00 5979929.35 688757.89 GCT-MS 66.20 0.11 182.21 66.20 19.20 -0.04 0.00 5979929.33 688757.89 GCT-MS 79.60 0.11 183.81 79.60 32.60 -0.07 -0.01 5979929.30 688757.89 GCT-MS 89.30 0.11 181.52 89.30 42.30 -0.09 -0.01 5979929.28 688757.89 GCT-MS 98.40 0.10 176.58 98.40 51.40 -0.11 -0.01 5979929.26 688757.89 GCT-MS 107.60 0.11 175.21 107.60 60.60 -0.12 -0.01 5979929.25 688757.89 GCT-MS 116.75 0.13 177.79 116.75 69.75 -0.14 0.00 5979929.23 688757.89 GCT-MS 126.00 0.14 183.23 126.00 79.00 -0.16 0.00 5979929.21 688757.89 GCT-MS 135.25 0.16 190.41 135.25 88.25 -0.19 -0.01 5979929.18 688757.89 GCT-MS 144.60 0.15 189.15 144.60 97.60 -0.21 -0.01 5979929.16 688757.88 GCT-MS 153.85 0.14 182.49 153.85 106.85 -0.24 -0.01 5979929.13 688757.88 GCT-MS 163.15 0.13 183.85 163.15 116.15 -0.26 -0.02 5979929.11 688757.88 GCT-MS 172.45 0.13 182.78 172.45 125.45 -0.28 -0.02 5979929.09 688757.88 GCT-MS 181.75 0.12 175.78 181.75 134.75 -0.30 -0.02 5979929.07 688757.88 GCT-MS 191.10 0.11 174.19 191.10 144.10 -0.32 -0.01 5979929.05 688757.88 GCT-MS 200.45 0.11 176.83 200.45 153.45 -0.34 -0.01 5979929.03 688757.89 GCT-MS 209.75 0.11 176.54 209.75 162.75 -0.35 -0.01 5979929.02 688757.89 GCT-MS 219.15 0.10 176.43 219.15 172.15 -0.37 -0.01 5979929.00 688757.89 GCT-MS 228.45 0.11 181.83 228.45 181.45 -0.39 -0.01 5979928.98 688757.89 GCT-MS 238.25 0.12 186.17 238.25 191.25 -0.41 -0.01 5979928.96 688757.89 GCT-MS 252.55 0.12 184.47 252.55 205.55 -0.44 -0.01 5979928.93 688757.89 GCT-MS 266.85 0.13 181.41 266.85 219.85 -0.47 -0.02 5979928.90 688757.89 GCT-MS 280.95 0.14 179.61 280.95 233.95 -0.50 -0.02 5979928.87 688757.89 GCT-MS 295.05 0.13 177.73 295.05 248.05 -0.53 -0.02 5979928.84 688757.89 GCT-MS 309.25 0.13 178.30 309.25 262.25 -0.57 -0.01 5979928.80 688757.89 GCT-MS 323.50 0.12 178.03 323.50 276.50 -0.60 -0.01 5979928.77 688757.89 GCT-MS y ~ Halliburton Company Survey Report Conyiany: BP Amoco Uah•: 6/812006 ~~~~~~finx~: 0826.14 Page: 2 Field: Pru dhoe Ba y (various] Co-or din~te(,VP:) Reference: Well: AGI-07. Tr ue td6rti7 Site: AG I ~~cr[ic al (l I'll) Re ference: 33.5 + 13.5 47.0 1tcll: AG I-07 Sectio n (~'S) ReCcr cucc: Well (0-OON,O.OO E.7286A,~i? N~ellpa~h: AGI -07A Sunc ~_C`ulculatio n ~~lcthod~ ~-1inimum Curvat ure Ub: OraCle ~ Survey ~~~ MD 1nc1 ~zim I~~'l) Sys'FVD N/S Ei~~' 11apv MapE 'Fool ft deg deg ft ft ft ft ft ft 332.20 0.12 179.83 332.20 285.20 -0.62 -0.01 5979928.75 688757.89 GCT-MS 341.10 0.07 168.43 341.10 294.10 -0.63 -0.01 5979928.74 688757.89 GCT-MS 357.70 0.02 164.02 357.70 310.70 -0.64 -0.01 5979928.73 688757.90 GCT-MS 375.45 0.01 173.92 375.45 328.45 -0.65 -0.01 5979928.72 688757.90 GCT-MS 392.90 0.01 180.05 392.90 345.90 -0.65 -0.01 5979928.72 688757.90 GCT-MS 410.30 0.01 182.20 410.30 363.30 -0.65 -0.01 5979928.72 688757.90 GCT-MS 427.70 0.04 170.29 427.70 380.70 -0.66 -0.01 5979928.71 688757.90 GCT-MS 445.15 0.08 146.10 445.15 398.15 -0.68 0.00 5979928.69 688757.91 GCT-MS 462.55 0.12 123.51 462.55 415.55 -0.70 0.02 5979928.67 688757.93 GCT-MS 480.05 0.18 103.05 480.05 433.05 -0.71 0.06 5979928.66 688757.97 GCT-MS 497.35 0.28 88.44 497.35 450.35 -0.72 0.13 5979928.65 688758.04 GCT-MS 514.55 0.41 79.33 514.55 467.55 -0.71 0.24 5979928.67 688758.14 GCT-MS 531.65 0.58 74.50 531.65 484.65 -0.67 0.38 5979928.71 688758.29 GCT-MS 548.75 0.74 72.50 548.75 501.75 -0.62 0.57 5979928.77 688758.47 GCT-MS 565.75 0.82 70.34 565.75 518.75 -0.54 0.79 5979928.85 688758.69 GCT-MS 582.80 0.90 70.01 582.79 535.79 -0.45 1.03 5979928.94 688758.93 GCT-MS 599.85 1.05 71.10 599.84 552.84 -0.36 1.30 5979929.04 688759.20 GCT-MS 616.80 1.30 71.30 616.79 569.79 -0.25 1.63 5979929.16 688759.53 GCT-MS 633.90 1.71 71.00 633.88 586.88 -0.10 2.06 5979929.32 688759.95 GCT-MS 650.90 2.12 69.47 650.87 603.87 0.09 2.59 5979929.53 688760.48 GCT-MS 667.90 2.61 67.27 667.86 620.86 0.35 3.24 5979929.80 688761.12 GCT-MS 684.75 3.09 65.47 684.69 637.69 0.69 4.01 5979930.16 688761.88 GCT-MS 701.65 3.34 64.76 701.56 654.56 1.09 4.87 5979930.58 688762.73 GCT-MS 718.50 3.52 64.90 718.38 671.38 1.52 5.78 5979931.03 688763.63 GCT-MS 735.35 3.75 65.29 735.20 688.20 1.97 6.75 5979931.51 688764.59 GCT-MS 752.30 4.03 65.66 752.11 705.11 2.44 7.80 5979932.01 688765.62 GCT-MS 769.25 4.24 65.69 769.01 722.01 2.95 8.91 5979932.54 688766.72 GCT-MS 786.15 4.34 65.84 785.87 738.87 3.47 10.06 5979933.09 688767.86 GCT-MS 803.15 4.45 66.23 802.82 755.82 3.99 11.25 5979933.65 688769.04 GCT-MS 820.15 4.58 67.09 819.76 772.76 4.52 12.48 5979934.21 688770.25 GCT-MS 837.05 4.75 67.85 836.61 789.61 5.05 13.75 5979934.77 688771.51 GCT-MS 854.05 4.90 68.32 853.55 806.55 5.58 15.08 5979935.33 688772.82 GCT-MS 871.00 5.05 68.78 870.43 823.43 6.12 16.45 5979935.90 688774.18 GCT-MS 887.95 5.19 69.11 887.31 840.31 6.67 17.86 5979936.48 688775.57 GCT-MS 904.90 5.35 69.51 904.19 857.19 7.22 19.31 5979937.07 688777.01 GCT-MS 921.85 5.53 69.87 921.07 874.07 7.77 20.82 5979937.66 688778.51 GCT-MS 938.80 5.77 70.15 937.93 890.93 8.34 22.39 5979938.27 688780.06 GCT-MS 955.70 6.09 70.32 954.74 907.74 8.93 24.03 5979938.91 688781.69 GCT-MS 972.70 6.28 70.25 971.65 924.65 9.55 25.76 5979939.57 688783.40 GCT-MS 989.65 6.34 70.08 988.49 941.49 10.18 27.51 5979940.24 688785.13 GCT-MS 1006.70 6.39 70.08 1005.44 958.44 10.83 29.29 5979940.93 688786.89 GCT-MS 1023.70 6.47 70.09 1022.33 975.33 11.48 31.08 5979941.62 688788.67 GCT-MS 1040.70 6.58 70.28 1039.22 992.22 12.13 32.89 5979942.33 .688790.47 GCT-MS 1057.70 6.73 70.75 1056.11 1009.11 12.79 34.75 5979943.03 688792.31 GCT-MS 1074.80 6.91 71.30 1073.08 1026.08 13.45 36.67 5979943.74 688794.21 GCT-MS 1091.80 7.03 71.68 1089.96 1042.96 14.10 38.63 5979944.44 688796.15 GCT-MS 1108.80 7.10 71.97 1106.83 1059.83 14.76 40.61 5979945.14 688798.12 GCT-MS 1125.70 7.20 72.27 1123.60 1076.60 15.40 42.62 5979945.84 688800.10 GCT-MS 1142.60 7.27 72.48 1140.36 1093.36 16.05 44.64 5979946.53 688802.11 GCT-MS 1159.30 7.33 72.57 1156.93 1109.93 16.68 46.67 5979947.22 688804.12 GCT-MS 1176.00 7.45 72.82 1173.49 1126.49 17.32 48.72 5979947.91 688806.15 GCT-MS 1192.90 7.58 73.27 1190.24 1143.24 17.97 50.83 5979948.61 688808.25 GCT-MS • ~ Halliburton Company • Survey Report Company: BP Amoco Ficid: Prudhoe Bay (variousi Site: AGI ~~~ell: AGI-07 ~~cllpath: AGf-07A Uare: 6/8/2006 7~imc: 082614 Page: Co-ordinate(\'Ej Reference Well: ACI-07. True North Vertual (Il D) Refc~ encc: 33.5 + 1 .5 47.0 Section (~'S) Reference: Well (0-00N.O.OOE.72.b6Azi) SurveyCalculntion ~Icrhod: Minimun~i Curvature Db: 3 racle j Sur~cv 11D lncl Azim l~U Sys"1'Vll N/S E/ti~ ylapti ~~lapE Tool ft c7eg deg ft ff ft ft ft ft 1209.75 7.69 73.54 1206.95 1159.95 18.61 52.98 5979949.30 688810.38 GCT-MS 1226.75 7.84 73.67 1223.79 1176.79 19.25 55.18 5979950.01 688812.57 GCT-MS 1243.85 7.96 73.72 1240.73 1193.73 19.91 57.44 5979950.72 688814.80 GCT-MS 1260.95 8.07 73.70 1257.66 1210.66 20.58 59.73 5979951.45 688817.08 GCT-MS 1278.05 8.16 73.48 1274.59 1227.59 21.26 62.04 5979952.19 688819.37 GCT-MS 1295.05 8.25 73.05 1291.41 1244.41 21.96 64.37 5979952.95 688821.68 GCT-MS 1312.15 8.35 72.59 1308.34 1261.34 22.69 66.72 5979953.73 688824.02 GCT-MS 1329.25 8.46 72.13 1325.25 1278.25 23.45 69.11 5979954.55 688826.38 GCT-MS 1346.25 8.58 71.69 1342.06 1295.06 24.23 71.50 5979955.39 688828.75 GCT-MS 1363.30 8.67 71.11 1358.92 1311.92 25.05 73.92 5979956.27 688831.15 GCT-MS 1380.30 8.76 70.58 1375.73 1328.73 25.89 76.36 5979957.18 688833.57 GCT-MS 1397.35 8.87 70.39 1392.57 1345.57 26.77 78.82 5979958.11 688836.01 GCT-MS 1414.40 9.00 70.34 1409.42 1362.42 27.66 81.31 5979959.06 688838.48 GCT-MS 1431.45 9.15 70.28 1426.25 1379.25 28.56 83.85 5979960.03 688840.98 GCT-MS 1448.70 9.26 70.22 1443.28 1396.28 29.49 86.44 5979961.03 688843.56 GCT-MS 1466.10 9.33 70.32 1460.45 1413.45 30.44 89.09 5979962.05 688846.18 GCT-MS 1483.10 9.41 70.57 1477.23 1430.23 31.37 91.70 5979963.04 688848.76 GCT-MS 1500.20 9.47 70.81 1494.09 1447.09 32.30 94.34 5979964.03 688851.38 GCT-MS 1517.10 9.55 71.08 1510.76 1463.76 33.21 96.98 5979965.01 688854.00 GCT-MS 1533.85 9.63 71.36 1527.28 1480.28 34.11 99.62 5979965.97 688856.62 GCT-MS 1550.55 9.68 71.63 1543.74 1496.74 35.00 102.28 5979966.93 688859.25 GCT-MS 1567.30 9.77 71.98 1560.25 1513.25 35.88 104.97 5979967.88 688861.91 GCT-MS 1584.00 9.90 72.34 1576.71 1529.71 36.75 107.68 5979968.82 688864.61 GCT-MS 1601.25 10.03 72.49 1593.70 1546.70 37.65 110.53 5979969.79 688867.43 GCT-MS 1619.75 10.17 72.60 1611.91 1564.91 38.63 113.62 5979970.85 688870.50 GCT-MS 1645.65 10.38 72.84 1637.39 1590.39 40.00 118.03 5979972.33 688874.87 GCT-MS 1671.85 10.60 73.08 1663.16 1616.16 41.40 122.60 5979973.84 688879.40 GCT-MS 1697.85 10.78 73.11 1688.70 1641.70 42.80 127.21 5979975.36 688883.97 GCT-MS 1723.85 10.93 73.18 1714.24 1667.24 44.22 131.90 5979976.90 688888.62 GCT-MS 1750.20 11.14 73.45 1740.10 1693.10 45.67 136.73 5979978.46 688893.42 GCT-MS 1776.85 11.51 73.56 1766.23 1719.23 47.15 141.75 5979980.08 688898.39 GCT-MS 1803.55 12.12 73.70 1792.37 1745.37 48.69 146.99 5979981.75 688903.60 GCT-MS 1830.45 13.09 73.98 1818.62 1771.62 50.33 152.63 5979983.52 688909.19 GCT-MS 1857.30 14.53 73.95 1844.69 1797.69 52.10 158.79 5979985.45 688915.31 GCT-MS 1884.40 16.19 73.19 1870.82 1823.82 54.13 165.67 5979987.65 688922.14 GCT-MS 1911.30 17.74 72.07 1896.55 1849.55 56.48 173.16 5979990.19 688929.56 GCT-MS 1938.40 19.23 70.88 1922.25 1875.25 59.21 181.31 5979993.12 688937.64 GCT-MS 1965.50 20.52 70.18 1947.74 1900.74 62.28 189.99 5979996.41 688946.24 GCT-MS 1992.65 21.30 70.10 1973.10 1926.10 65.57 199.11 5979999.93 688955.27 GCT-MS 2019.85 21.65 70.21 1998.41 1951.41 68.95 208.47 5980003.55 688964.55 GCT-MS 2046.85 21.89 70.38 2023.49 1976.49 72.33 217.90 5980007.16 688973.89 GCT-MS 2073.85 22.06 70.51 2048.52 2001.52 75.71 227.42 5980010.78 688983.32 GCT-MS 2100.85 22.20 70.61 2073.53 2026.53 79.10 237.01 5980014.41 688992.82 GCT-MS 2127.85 22.36 70.71 2098.52 2051.52 82.49 246.67 5980018.04 689002.39 GCT-MS 2155.05 22.64 70.91 2123.65 2076.65 85.91 256.50 5980021.71 689012.13 GCT-MS 2182.40 23.11 71.15 2148.85 2101.85 89.36 266.56 5980025.42 689022.09 GCT-MS 2209.80 23.82 71.36 2173.98 2126.98 92.87 276.89 5980029.18 689032.33 GCT-MS 2237.20 24.57 71.28 2198.97 2151.97 96.47 287.53 5980033.04 689042.88 GCT-MS 2264.65 25.24 70.88 2223.87 2176.87 100.22 298.46 5980037.07 689053.71 GCT-MS 2292.10 25.87 70.49 2248.64 2201.64 104.13 309.64 5980041.26 689064.79 GCT-MS 2319.55 26.44 70.23 2273.28 2226.28 108.20 321.03 5980045.62 689076.07 GCT-MS 2347.00 27.15 70.00 2297.78 2250.78 112.41 332.67 5980050.12 689087.60 GCT-MS 2374.75 27.99 69.86 2322.38 2275.38 116.82 344.73 5980054.83 689099.55 GCT-MS ' ~ Halliburton Company Survey Report Company: BP Amoco Nield: Prudhoe Bay {various) Site: AGI Nell: AGl-07 Ncllpxth: AGI-07A Date: 6/8!2006 Time: 0826.14 Pa~c: 4 Co-ordinate(NR) Reference: Well. AGI-07, True North Vertical (TVD) Reference: 33.5 + 13.5 47-0 Section (VSI Reference Well (O OON,O.OOE72.86Azi) Survey Calcula8on tilethod: Minimum Curvature Ub: Oracle Survc~ ~1D Incl ~ziw IUD Sys 'Ti'll N/S E/W ~~tap1V Ma~r~ fool J ft deg deg ft ft ~t fit ft ft 2402.55 28.75 69.92 2346.84 2299.84 121.36 357.14 5980059.68 689111.83 GCT-MS 2430.15 29.30 70.09 2370.97 2323.97 125.94 369.72 5980064.57 689124.30 GCT-MS 2457.40 29.65 70.30 2394.69 2347.69 130.48 382.33 5980069.43 689136.79 GCT-MS 2484.50 29.96 70.50 2418.21 2371.21 135.00 395.02 5980074.27 689149.36 GCT-MS 2511.50 30.47 70.82 2441.54 2394.54 139.50 407.84 5980079.09 689162.07 GCT-MS 2538.00 31.30 71.16 2464.28 2417.28 143.93 420.71 5980083.84 689174.81 GCT-MS 2564.85 32.47 71.43 2487.08 2440.08 148.48 434.14 5980088.73 689188.13 GCT-MS 2591.70 33.73 71.53 2509.57 2462.57 153.13 448.04 5980093.73 689201.91 GCT-MS 2618.55 34.72 71.48 2531.77 2484.77 157.92 462.36 5980095.88 689216.10 GCT-MS 2645.45 35.41 71.42 2553.79 2506.79 162.84 477.02 5980104.16 689230.62 GCT-MS 2672.30 35.79 71.40 2575.62 2528.62 167.82 491.83 5980109.52 689245.31 GCT-MS 2699.15 35.95 71.44 2597.38 2550.38 172.84 506.74 5980114.91 689260.09 GCT-MS 2726.00 36.08 71.56 2619.10 2572.10 177.85 521.71 5980120.29 689274.93 GCT-MS 2752.75 36.24 71.66 2640.70 2593.70 182.83 536.69 5980125.64 689289.77 GCT-MS 2779.60 36.51 71.60 2662.31 2615.31 187.84 551.80 5980131.04 689304.75 GCT-MS 2806.10 36.96 71.41 2683.55 2636.55 192.87 566.84 5980136.45 689319.65 GCT-MS 2832.60 37.66 70.95 2704.63 2657.63 198.05 582.04 5980142.01 689334.72 GCT-MS 2859.10 38.27 70.57 2725.52 2678.52 203.43 597.43 5980147.77 689349.97 GCT-MS 2885.65 38.58 70.53 2746.32 2699.32 208.92 612.99 5980153.65 689365.39 GCT-MS 2912.45 38.78 70.65 2767.24 2720.24 214.49 628.79 5980159.61 689381.04 GCT-MS 2939.25 38.98 70.80 2788.11 2741.11 220.04 644.67 5980165.56 689396.77 GCT-MS 2966.05 39.34 70.89 2808.89 2761.89 225.59 660.65 5980171.52 689412.61 GCT-MS 2992.90 40.01 71.03 2829.55 2782.55 231.19 676.86 5980177.52 689428.67 GCT-MS 3019.65 40.88 71.18 2849.91 2802.91 236.80 693.27 5980183.55 689444.94 GCT-MS 3046.50 41.76 71.29 2870.07 2823.07 242.51 710.06 5980189.67 689461.57 GCT-MS 3073.25 42.67 71.45 2889.89 2842.89 248.25 727.09 5980195.84 689478.45 GCT-MS 3100.00 43.65 71.86 2909.40 2862.40 254.01 744.46 5980202.03 689495.67 GCT-MS 3126.80 44.56 72.52 2928.64 2881.64 259.71 762.22 5980208.18 689513.28 GCT-MS 3153.40 45.17 73.17 2947.50 2900.50 265.25 780.15 5980214.17 689531.06 GCT-MS 3179.90 45.49 73.87 2966.13 2919.13 270.59 798.22 5980219.96 689548.99 GCT-MS 3206.45 45.68 74.53 2984.71 2937.71 275.75 816.47 5980225.59 689567.10 GCT-MS 3233.00 45.83 74.90 3003.23 2956.23 280.77 834.81 5980231.06 689585.32 GCT-MS 3259.75 45.79 75.09 3021.88 2974.88 285.73 853.34 5980236.49 689603.71 GCT-MS 3286.35 45.54 75.26 3040.47 2993.47 290.60 871.73 5980241.82 689621.97 GCT-MS 3312.95 45.31 75.49 3059.14 3012.14 295.39 890.07 5980247.06 689640.18 GCT-MS 3339.65 45.23 75.56 3077.93 3030.93 300.13 908.43 5980252.27 689658.42 GCT-MS 3366.45 45.29 75.29 3096.79 3049.79 304.92 926.86 5980257.52 689676.72 GCT-MS 3393.30 45.41 74.81 3115.66 3068.66 309.85 945.31 5980262.91 689695.04 GCT-MS 3420.90 45.52 74.25 3135.02 3088.02 315.09 964.27 5980268.63 689713.86 GCT-MS 3447.90 45.52 73.54 3153.93 3106.93 320.44 982.78 5980274.44 689732.23 GCT-MS 3474.90 45.32 72.42 3172.89 3125.89 326.07 1001.17 5980280.53 689750.47 GCT-MS 3501.30 45.06 71.30 3191.49 3144.49 331.90 1018.97 5980286.81 689768.11 GCT-MS 3527.40 44.91 70.73 3209.95 3162.95 337.90 1036.41 5980293.25 689785.40 GCT-MS 3553.45 44.82 70.59 3228.42 3181.42 343.99 1053.75 5980299.77 689802.58 GCT-MS 3579.45 44.62 70.62 3246.89 3199.89 350.06 1071.01 5980306.28 689819.68 GCT-MS 3605.65 44.34 70.80 3265.58 3218.58 356.12 1088.34 5980312.77 689836.85 GCT-MS 3631.90 44.07 71.04 3284.40 3237.40 362.11 1105.63 5980319.19 689853.99 GCT-MS 3658.25 43.88 71.26 3303.36 3256.36 368.02 1122.95 5980325.54 689871.15 GCT-MS 3684.60 43.86 71.40 3322.36 3275.36 373.86 1140.25 5980331.81 689888.29 GCT-MS 3710.90 44.00 71.35 3341.30 3294.30 379.69 1157.54 5980338.08 689905.43 GCT-MS 3737.30 44.28 70.94 3360.25 3313.25 385.63 1174.94 5980344.45 689922.67 GCT-MS 3763.60 44.59 70.43 3379.03 3332.03 391.72 1192.31 5980350.98 689939.89 GCT-MS ' ~ Halliburton Company Survey Report Company: BP Amoco L):~tc: 6i8i'2006 7~imc: 08.26:14 Pat;c: 5 Field: Prudhoe Bay (various) Co-or diuaLc(~f~:) R eference: Well: AGI-67. Tr ue North ~itc: AGI ~crtical ~'I~~;1)) kc lcrcncc: 33.5 + 1 ;_5 47.0 ~~ell: AGI -07 ticctio n (~'SI Rctcr cnce: Well (O OON,O.OO E,72.86Azi) 1icllpa6h: AGI -07A Sumer Cnlcul:nio n Dlerhod; Minimum Curvat ure Db: Oracle 4 Survev - - MD Incl - _ _- ~znn __ TVD Svs ~I~~"U V/5 E/W P _ eta N . A Ma ~ l'oo! rt aeg deg fi tt ft ft tt rt 3789.90 44.87 70.19 3397.71 3350.71 397.96 1209.74 5980357.65 689957.15 GCT-MS 3816.30 44.99 70.15 3416.40 3369.40 404.29 1227.28 5980364.42 689974.52 GCT-MS 3842.50 45.03 70.17 3434.92 3387.92 410.57 1244.71 5980371.14 689991.79 GCT-MS 3868.55 45.12 70.21 3453.32 3406.32 416.82 1262.06 5980377.83 690008.98 GCT-MS 3894.55 45.23 70.23 3471.65 3424.65 423.07 1279.42 5980384.50 690026.17 GCT-MS 3921.25 44.97 70.27 3490.50 3443.50 429.46 1297.22 5980391.34 690043.80 GCT-MS 3941.00 44.55 70.33 3504.52 3457.52 434.14 1310.31 5980396.35 690056.77 MWD+IFR+MS 3964.24 43.49 72.24 3521.23 3474.23 439.33 1325.60 5980401.92 690071.93 MWD+IFR+MS 4060.80 39.46 81.00 3593.63 3546.63 454.28 1387.63 5980418.43 690133.55 MWD+IFR+MS 4154.58 38.50 75.77 3666.55 3619.55 466.12 1445.37 5980431.72 690190.98 MWD+IFR+MS 4251.88 40.17 74.90 3741.80 3694.80 481.74 1505.03 5980448.84 690250.22 MWD+IFR+MS 4345.43 40.27 75.12 3813.23 3766.23 497.37 1563.39 5980465.93 690308.16 MWD+IFR+MS 4440.85 41.26 69.80 3885.52 3838.52 516.16 1622.74 5980486.21 690367.02 MWD+IFR+MS 4531.55 41.19 72.25 3953.75 3906.75 535.59 1679.25 5980507.06 690423.02 MWD+IFR+MS 4626.96 41.37 72.39 4025.45 3978.45 554.71 1739.23 5980527.68 690482.49 MWD+IFR+MS 4709.09 41.94 73.33 4086.81 4039.81 570.79 1791.39 5980545.07 690534.23 MWD+IFR+MS 4819.17 42.40 73.55 4168.40 4121.40 591.85 1862.22 5980567.91 690604.50 MWD+IFR+MS 4912.41 42.99 73.51 4236.93 4189.93 609.78 1922.86 5980587.35 690664.66 MWD+IFR+MS 5006.74 43.56 73.04 4305.61 4258.61 628.39 1984.78 5980607.52 690726.10 MWD+IFR+MS 5092.10 41.48 74.22 4368.52 4321.52 644.66 2040.13 5980625.17 690781.01 MWD+IFR+MS 5199.65 40.99 73.54 4449.40 4402.40 664.34 2108.23 5980646.56 690848.59 MWD+IFR+MS 5294.05 41.53 72.83 4520.36 4473.36 682.35 2167.82 5980666.07 690907.71 MWD+IFR+MS 5387.41 41.64 72.46 4590.19 4543.19 700.83 2226.96 5980686.03 690966.36 MWD+IFR+MS 5483.37 41.57 71.50 4661.94 4614.94 720.54 2287.55 5980707.26 691026.43 MWD+IFR+MS 5578.89 41,72 72.05 4733.32 4686.32 740.40 2347.84 5980728.62 691086.20 MWD+IFR+MS 5676.64 41.51 71.56 4806.40 4759.40 760.67 2409.52 5980750.44 691147.34 MWD+IFR+MS 5770.18 40,67 72.25 4876.90 4829.90 779.76 2467.95 5980771.00 691205.27 MWD+IFR+MS 5862.09 41.01 71.84 4946.44 4899.44 798.29 2525.13 5980790.96 691261.96 MWD+IFR+MS 5955.95 41.22 72.08 5017.15 4970.15 817.41 2583.81 5980811.55 691320.14 MWD+IFR+MS 6049.56 39.93 71.88 5088.25 5041.25 836.24 2641.71 5980831.83 691377.55 MWD+IFR+MS 6145.15 40.12 72.81 5161.45 5114.45 854.88 2700.29 5980851.95 691435.63 MWD+IFR+MS 6241.46 40.45 73.82 5234.92 5187.92 872.76 2759.94 5980871.32 691494.81 MWD+IFR+MS 6335.25 40.50 73.75 5306.27 5259.27 889.76 2818.40 5980889.78 691552.82 MWD+IFR+MS 6429.50 39.77 74.34 5378.32 5331.32 906.46 2876.81 5980907.95 691610.79 MWD+IFR+MS 6524.69 39.73 74.93 5451.51 5404.51 922.59 2935.51 5980925.55 691669.05 MWD+IFR+MS 6619.73 39.68 75.02 5524.63 5477.63 938.33 2994.15 5980942.76 691727.27 MWD+IFR+MS 6713.64 38.74 76.34 5597.39 5550.39 953.02 3051.66 5980958.89 691784.40 MWD+IFR+MS 6805.45 38.89 76.72 5668.93 5621.93 966.42 3107.63 5980973.70 691840.00 MWD+IFR+MS 6896.91 38.97 76.98 5740.08 5693.08 979.50 3163.59 5980988.18 691895.62 MWD+IFR+MS 6993.87 40.53 74.09 5814.63 5767.63 995.01 3223.60 5981005.20 691955.22 MWD+IFR+MS 7092.99 44.75 70.01 5887.54 5840.54 1015.77 3287.40 5981027.57 692018.47 MWD+IFR+MS 7188.22 45.21 70.64 5954.90 5907.90 1038.44 3350.79 5981051.82 692081.26 MWD+IFR+MS 7284.12 45.80 70.87 6022.11 5975.11 1060.98 3415.37 5981075.98 692145.25 MWD+IFR+MS 7377.80 45.01 70.10 6087.88 6040.88 1083.26 3478.25 5981099.84 692207.54 MWD+IFR+MS 7472.36 45.23 71.11 6154.61 6107.61 1105.51 3541.45 5981123.67 692270.16 MWD+IFR+MS 7566.60 42.79 70.43 6222.38 6175.38 1127.07 3603.27 5981146.77 692331.41 MWD+IFR+MS 7661.65 42.91 70.96 6292.07 6245.07 1148.44 3664.28 5981169.67 692391.86 MWD+IFR+MS 7757.00 42.23 70.85 6362.29 6315.29 1169.54 3725.23 5981192.30 692452.26 MWD+IFR+MS 7851.47 40.72 70.80 6433.07 6386.07 1190.09 3784.32 5981214.33 692510.81 MWD+IFR+MS 7945.05 39.47 71.48 6504.65 6457.65 1209.58 3841.36 5981235.25 692567.33 MWD+IFR+MS 8040.41 39.93 71.42 6578.02 6531.02 1228.95 3899.10 5981256.07 692624.57 MWD+IFR+MS 8134.12 39.31 71.69 6650.21 6603.21 1247.86 3955.79 5981276.40 692680.76 MWD+IFR+MS 8229.02 39.61 71.32 6723.48 6676.48 1266.99 4012.99 5981296.97 692737.45 MWD+IFR+MS t • ~ Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay (various} Side: AGI ~~cll: AGI-07 Ncllpath: AGI-07A ~ ----- - - .Sllfcc~ Date: 6!8/2006 Iinu: OfS 2F>:14 Page: 6 Cn-ordinafc(V~) Reference: Well: AGI-u7 True North ~ crtir.~l ~"I ~U) Reference: 33.5 + 13.5 47.0 Section I~S1 Reference: Well (O.OON.QOOE,72.86Azi) Surer Calculation ~ic[hod: Minimum Curvature Db: Oracle MD lncl Azim 'FVD ScsTVD N/S E/W ~lap'S MapE Tool ~ ft deg deg ft ft fit ft ft ft 8323.87 39.95 71.93 6796.37 6749.37 1286.12 4070.58 5981317.54 692794.54 MWD+IFR+MS 8419.12 40.09 71.55 6869.31 6822.31 1305.32 4128.75 5981338.19 692852.20 MWD+IFR+MS 8513.65 40.45 71.61 6941.44 6894.44 1324.62 4186.72 5981358.95 692909.67 MWD+IFR+MS 8608.91 40.72 72.10 7013.78 6966.78 1343.92 4245.61 5981379.73 692968.05 MWD+IFR+MS 8703.01 40.00 72.31 7085.49 7038.49 1362.55 4303.64 5981399.80 693025.58 MWD+IFR+MS 8797.73 39.29 72.16 7158.42 7111.42 1380.99 4361.19 5981419.68 693082.65 MWD+IFR+MS 8892.95 38.79 71.49 7232.38 7185.38 1399.69 4418.17 5981439.82 693139.14 MWD+IFR+MS 8986.36 37.91 71.69 7305.63 7258.63 1418.00 4473.16 5981459.50 693193.65 MWD+IFR+MS 9083.01 39.26 73.89 7381.19 7334.19 1435.81 4530.74 5981478.76 693250.75 MWD+IFR+MS 9178.18 41.70 75.75 7453.57 7406.57 1451.96 4590.36 5981496.41 693309.95 MWD+IFR+MS 9273.16 41.79 75.86 7524.44 7477.44 1467.47 4651.67 5981513.45 693370.84 MWD+IFR+MS 9368.43 41.82 76.25 7595.46 7548.46 1482.77 4713.30 5981530.30 693432.07 MWD+IFR+MS 9417.00 43.61 77.08 7631.14 7584.14 1490.37 4745.36 5981538.70 693463.92 MWD+IFR+MS 9463.13 42.26 75.64 7664.91 7617.91 1497.77 4775.90 5981546.87 693494.26 MWD+IFR+MS 9557.68 42.92 75.72 7734.52 7687.52 1513.60 4837.89 5981564.26 693555.84 MWD+IFR+MS 9650.10 41.57 75.46 7802.94 7755.94 1529.06 4898.07 5981581.23 693615.60 MWD+IFR+MS 9746.00 40.19 75.72 7875.44 7828.44 1544.68 4958.86 5981598.37 693675.97 MWD+IFR+MS 9841.19 .40.50 75.03 7947.99 7900.99 1560.24 5018.49 5981615.43 693735.19 MWD+IFR+MS 9902.40 39.47 74.36 7994.89 7947.89 1570.62 5056.42 5981626.76 693772.85 MWD+IFR+MS 9967.16 37.99 74.81 8045.41 7998.41 1581.39 5095.48 5981638.51 693811.62 MWD+IFR+MS 10060.81 37.74 75.48 8119.34 8072.34 1596.13 5151.04 5981654.64 693866.79 MWD+-FR+MS 10156.21 36.93 74.90 8195.20 8148.20 1610.92 5206.98 5981670.83 693922.33 MWD+IFR+MS 10249.67 36.61 74.41 8270.06 8223.06 1625.72 5260.93 5981686.99 693975.89 MWD+IFR+MS 10343.82 36.17 74.28 8345.85 8298.85 1640.79 5314.71 5981703.41 694029.27 MWD+IFR+MS 10441.41 35.59 73.69 8424.92 8377.92 1656.57 5369.69 5981720.57 694083.83 MWD+IFR+MS 10469.73 35.28 73.56 8448.00 8401.00 1661.20 5385.44 5981725.59 694099.46 MWD+IFR+MS 10525.00 35.28 73.56 8493.12 8446.12 1670.23 5416.06 5981735.40 694129.84 PROJECTED TREE _ WELLHEAD = CTUATOR= FMC BAKERC KB. ELEV = BF. ELEV = .33.60' 30.30' KOP = 3938' Max Angle = 46 @-3235' Datum MD = 10525' -Datum TVD = 8494' •AGI-07A FROM OR~G -DRAFT (_13-3/8" CSG, 68#, L-80, ID = 12.415" ~-~ 3936' 13-3/8" CSG, 68#, K-55, ??? (TOP TWO JOINTS) Minimum ID = 5.770" @ 9836' 7" OTIS RN NIPPLE TOP OF 9 5/8" 4020' 9 5/8" EZSV 4200' 7 5/8" TBG, 29.7#, L-80-IPC, VAM TOP HC, ID = 6.875", 0.0459 BBL/FT 7844' 9 518" HES CEMENTER W/ x- over TGII TO BTC 9779' 7 5/8" x 7" 26# TGII TO VAM TOP HC XO Top of 7" 9590' 9792' --~ 7" OTIS R Nipple, ID = 5.963" 9812, 9 5/8" x 7" Baker S-3 Pkr, 7" 26# TGII, ID = 6.059" - 9836' 7" OTIS RN Nipple, ID = 5.770" 7" HMC Liner hanger/ ZXP 9850' Packer w! 11.6' TBS (7.5" ID) 26# BTC 9856' 7" 26# TGII Muie Shoe 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" 10306' 7" LNR, 29#, NT-80-S 11013' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/03!93 ORIGINAL COMPLETION 11/01/05 PGS Proposed Sidetrack 06!01106 CPC Actual Cpmpletion 9 5/8" CSG, 47#, L 9958' TGII, ID = 8.681 ", 0.07321 BBLlFT 9957' T' 26# L-80 I~rforated 10523' I-17" 26# L-80 Perforated PBTD 10525' 7" 26# TD PRUDHOE BAY UNIT WELL: AGI-07A PERMff No: 206-252 API No: 50-029-22343-01 SEC 36, T12N, R14E, UM 2292' FSL, 2516' FEL BP Exploration {Alaska) SAFETY NOTES: 7-5l8" Vam Top HC is IPC. " Perorated Liner. RHC-M plug is set in 7" is RN Nipple @ 9836' 2121' 7 5/8" x 7" XO (ID 6.250") w / 7" 26# TGII Pup _ 2132' 7" OTIS DB-6 SSSV NIP, ID = 6.0" TGII 2144' 7" x 7 518" XO (ID 6.184") w/ 7" 26# TGII Pup ~A Sch[umherger ,,ti ~~~ ~ ZOi)6 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ,;u w~ ~. ~,;p;, ;rtir'sS•'«~T'f'31SS+Cs1 Anchorage, AK 99503-2838 ,~P~C(^~$ ATTN: Beth Woll .Inh ~1 Inn tln¢erintinn ~~ i ~~ ~ q~J~ to NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay r1~tu RI r`nlnr rn 06/20/06 07-18 9153238 LDL 01/31/03 1 C-04A 10649975 SBHP SURVEY 06/26/03 1 N-11C 10980595 PRODUCTION PROFILE 08/09/05 1 MPF-89 11084328 SCMT 11/24/05 1 D-10 10913021 MULTI-FINGER CALIPER 06/02/05 1 NGI-09 11212860 USIT 05/23106 1 MPH-09 11211412 USIT 05!28106 1 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12/15/05 Prints sent earlier 1 MPS-90 11162721 CH EDIT PDC-GR OF USIT 11/27/05 Prints sent earlier 1 AGI-07A 11212865 CH EDIT PDC-GR OF USIT 05/28/06 1 1 15-20C 11075906 MCNL 08/12/05 1 1 18-30 11209593 MCNL 03/25/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,vlaslca uata rs< consumng 5ervlces 2525 Gambell Street, Suite a00 Anchorage, AK 99503-2838 ATTN: Beth • • I ~a • 3 ~ m °~S ALASSA OIL A1QD GAS COI~TSERQATI011T CO1~II-IISSIOI~T Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ,, FRANK H. MURKOWSKI, GOVERNOR ~' a 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI-07A BP Exploration (Alaska) Inc. Permit No: 206-052 Surface Location: 2292' FSL, 2516' FEL, SEC. 36, T12N, R14E, UM Bottomhole Location: 1289' FNL, 1929' FEL, SEC. 31, T12N, R15E, UM Dear Mr. Wesley Enclosed is the approved application for permit to redrill 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 aI1 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 an equired test, contact the Commission's petroleum field inspector at (907)607 (pager). .N DATED this~~day of April, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~ STATE OF ALASKA ~' '~-''~ ~~~ ~ ALASKA~AND GAS CONSERVATION COMMISS~ PERMIT TO DRILL 20 AAC 25.005 I~,lU~-- ¢[tr(ioo~, ~~AR ~ 1 2006 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class O Exploratory ^ Development Gas ®Service / ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. S ecify if well i pr ose for: ~+(~~~ }~~3'~r1 ^ Shale Gas a ~'siC~lt~t'~ 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU AGI-07A;~~'°~~` 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10534 TVD 8469 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2292' FSL 2516' FEL SEC T12N R14E 36 UM 7. Property Designation: ADL 034628 Pool , , , . , , Top of Productive Horizon: 1395' FNL, 227T FEL, SEC. 31, T12N, R15E, UM - 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2006 Total Depth: 1289' FNL, 1929' FEL, SEC. 31, T12N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-688758 y-5979929 Zone-ASP4 10. KB Elevation (Height above GL): 54.4 feet 15. Distance to Nearest Well Within Pool: 1122' away from AGI-09 16. Deviated Wells: Kickoff Depth: 4025 feet Maximum Hole Angle: 44.44 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC~25.035) Downhole: 3495 Surface: 88 18. Casin Pro ram: S ecifications Top - Settin Depth -Bottom Quantit of ent, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/2" 9-5/8" 47# L-80 TC-II 10000' Surface Surface 10000' 8071' 899 sx Litecrete, 405 sx 'G' 8-1/2" 7" 26# L-80 BTC 681' 9853' 7945' 10534' 8473' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations} Total Depth MD (ft): 11015 Total Depth TVD (ft): 8474 Plugs (measured): 10123 Effective Depth MD (ft): 10992 Effective Depth TVD (ft): 8459 Junk (measured): 11010 Casing Length Size CemenYVolume MD TVD Conductor /Structural 76' 20" 11 ds Arcticset 106' 106' Surface 3903' 13-3/8" 2604 cu ft'E', 460 cu ft 'G' 3937' 3502' Intermediate 10271' 9-5/8" 60 cu ft Class'G' 10306' 8017' Production Liner 883' 7" Uncemented Slotted Liner 10130' - 11013' 7903' - 8472' Perforation Depth MD (ft): 10630' - 10958' Perforation Depth TVD (ft): 8226' - 8437' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program Q 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. 1 hereby certify that the foregoing is true and correct. Contact Shane Gagliardi, 564-5251 Printed Name ave Wesley . Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~ ..~ G ~~ ~ ~~ Phone 564-5153 Dated ~`~ ~~ ~ Sondra Stewman, 564-4750 Commission Use Onl y Permit To Drill Number: ,tea .~Q API Number: 50-029-22343-01-00 Permit A proval Date: See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales Samples Req'd: ^ Yes ~No Mu Log Req'd: ^ Yes~,'No T'e 5~ ~ ~~ l 0 l.~O O O ~ S.c ~ HZS Measures: Yes ^ No ectional S rvey Req'd~ Yes ^ No Other: IV l Z ~~ Ce U~c P.vt l Q ~C~t. ~S ~) Go ~i V eel t~ -'~2~ . (J t [ 0 ROVED BY THE COMMISSIO Date ~Z ~~ ,COMMISSIONER Form 10-401 Revised 12/2005 a '. -- ~ § /! • , ~ `~ ~,/ ~ Submit In Duplicate • • Well Name: AGI-07A Planned Well Summary Well AGI-07A Well Gas Injector Target Ivishak Zone T e Objective 3,2 and 1 AFE Number: PBD4P9200 API Number: 50-029-22343-01 Surface Northin Eastin Offsets TRS Location 5,979,928 688,759 2,290' FSL / 2,515' FEL 12 N, 14 E, 36 Target Northin Eastin Offsets TRS Location 5,981,652 693,822 1,395' FNL / 2,277' FEL 12 N, 15 E, 31 Bottom Northin Eastin Offsets TRS Location 5,981,767 694,166 1,289' FNL / 1,929' FEL 12 N, 15 E, 31 Planned KOP: 4,025' and / 3,571' tvd Planned TD: 10,530' and / 8,469' tvd Ri Nabors 27E CBE: 54.4' RTE^ 82.9' Estimated S ud Date: 4/15/2006 Planned O eratin Da s: 21.8 days Directional Program A roved Well Ian: W 04 Exit oint: 4,036' and / 3,571' tvd Maximum Hole Inclination: -44.44° at 4,056' in the tanned 12-~/a" Intermediate section. Proximity Issues: All surrounding wells pass major risk criteria. Wells AGI-06 and AGI-08 are the closest nei hborin wells, at 118.5' and 121.4 from center. Survey Program: Standard MWD with IIFR /Cassandra. Nearest Well Within Pool: Well AGI-09 with center-to-center distance of 1,122' at -10,517' md. Nearest Pro ert Line PBU bounda 10,000' North of TD Logging Program Hole Section: Required- Sensors /Service 12'/2" intermediate: Real time MWD Dir/GR/PWD 8'/2" roduction: Real time MWD Dir/GR/PWD Recorded Neutron Densit /Sonic O en Hole: None Cased Hole: USIT in Intermediate section AGI-07A Permit to Drill Application Page 1 Mud Program Hole Section / o eration: Drillin 12-'/4" interval, surface shoe - 9,694 To HRZ T e Densit Viscosit PV YP Chlorides API FL H LSND 8.8-9.3 45-60 15-22 25-30 <600 6.0-8.0 9.0-9.5 Hole Se 'on / o eration: Drillin 12-'/a" interval, 9,694 HRZ -10,000 Int TD T e Dens' Viscosit PV YP Chlorides API FL H LSND 0. 45 - 60 18 - 25 25 - 35 <600 < 5.5 9.0 - 9.5 L/ Hole Section / o eration: Drillin 8-'/z" roduction interval to 10,534' TD T e Densi Viscosi 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 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connectio n Length Top and / tvd Bottom and / tvd 12'/z" 9 5/8" 47# L-80 TC-II 10,000' Surface 10,000' / 8,071' 8'/i" 7" 26# L-80 BTC 681' 9,853'/ 7,945' 10,534' / 8,473' Tubin 7 5/a" 29.7# L-80 Vam To 9,750' Surface 9,750' / 7,870' Cementing Program Casin Strin 9-5/8", 47#, L-80, BTC-M Intermediate casin Ion strin 2 Sta e Slurry Design Basis: (Stage 1) Tail slurry. 1,000' of 9 5/8" x 12-'/a" annulus with 40% excess, plus ~86' of 9 5/8", 47#, shoe tract. Tail TOC C~ 9,000 md. Lead Slurry. 1,550' of 9-5/8" x 12-Ya" annulus with 40% excess. Lead TOC to 7,450' and C~ sta a tool set in the UG1. Pre-Flush Sta e 1 : None Planned S acer Fluid Sta e 1 : 300.0 bbls MudPush II at 10.70 pp Slur T e 11.0 Litecrete L d Sl Mix method Batch Mix urry: ea St l BHST /BHCT 80° F / 80° F ) ( age Thickenin time 4 hrs 26 min Slur Volume 121.04 bbl / 680 cf / 275 sx Litecrete, 11.0 ; 2.47 cf/sk Slur T e 15.8 Class `G' liner slur with `GASBLOK' additive T il Sl Mix method Batch mix a urry: St 1 BHST /BHCT 170° F / 100° F age ) ( Thickenin time 4 hrs 26 min Slur Volume 84.4 bbl / 474 cf / 405 sx Class `G', 15.8 ; 1.17 cf/sk. Slurry Design Basis: Sta e 2 Lead TOC to -3,936' md, 13 3/8"surface casing shoe. Lead slurry. 3,514' of 9 5/8" x 12-'/a" annulus with 40% excess. Pre-Flush Sta e 2 : None Planned S acer Fluid Sta e 2 : 300.0 bbls MudPush II at 10.70 Slur T e 11.0 Lite Crete slur Mix method Batch mix Lead Slurry: BHST /BHCT 80° F / 80° F (Stage 2) Thickenin time 4 hrs 27 min Slurry Volume 274.8 bbls / 1541 cf / 624 sx Litecrete, 11.0 ppg; 2.47 cf/sk. AGI-07A Permit to Drill Application Page 2 • Casing /Formation Integrity Testing • Test Test Point Test Type Test pressure 13 3/8" Casin Cement Plu to Surface 30 min recorded 2,750 si surface 13 3/8" Casin Shoe 20' new formation be and LOT Min 12.7 EMW 9-5/8" Casin Float a ui ment to surface 30 min recorded 4,000 si surface 8-Yz" Shoe 20' new formation be and FIT 9.5 EMW 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 ~/z" intermediate interval into TSAD Maximum antici ated BHP: 3,495 si at 8,071' tvd. Maximum surface ressure: 2,688 SI (based upon BHP and a full column of gas from TD Ca? 0.10 psi/ft) Calculated kick tolerance: 51.7 bbls with 12.7 EMW LOT Planned BOPE test ressure: 250 si low / 4,000 si hi h -14 da test c cle Drillin o erations BOPE configuration for 9 5/a" intermediate casing (top to bottom . Annular preventer, pipe rams, blind/shear rams. Well Interval: 8'/z" in~ection interval in Ivishak Zones 1, 2, 3 and 4 sands Maximum antici ated BHP: 3,400 si at 8,469' tvd. Maximum surface pressure: 2,553 psi (based upon BHP and a full column of gas from Td ~ 0:10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT. Planned BOPE test ressure: 250 si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.6 seawater / 7.1 Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. 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. In'ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject Handlin station at 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. AGI-07A Permit to Drill Application Page 3 ! • Geologic Prognosis Est. Formation Tops Uncertainty Est. Pore Press. Formation MD TVD TVDss (feet) (Psi) (ppg) KOP SV1 5343 4566 -4520 30 UG4 5987 5051 -5005 30 UG3 6306 5291 -5245 30 UG1 7063 5861 -5815 30 WS2 7907 6496 -6450 20 WS1 8073 6621 -6575 20 CM3 8206 6721 -6675 20 CM2 8531 6966 -6920 20 CM1 9036 7346 -7300 20 THRZ 9694 7841 -7795 10 LCU 9982 8058 -8012 10 43SB 10000 8071 -8025 10 TCGL 10013 8081 -8035 10 BCGL 10133 8171 -8125 10 23SB 10219 8236 -8190 10 22TS 10246 8256 -8210 15 21TS 10292 8291 -8245 15 TZ1B 10412 8381 -8335 15 TDF 10452 8411 -8365 15 BSAD 10498 8446 -8400 15 3383 7.7 TD Criteria TD Criteria: Sufficient rathole below BSAD required to complete lowest Z1 B sand. Final TD will be determined b town and wellsite eolo Fault Prognosis No faults are expected in the well. AGI-07A Permit to Drill Application Page 4 Operations Summary Current Condition: / Currently well is Sl. / 9--%'; 47#, NT-80-S intermediate set at 10,306' / 7", 29#, NT-80-S liner landed at 11,013' / 9-%"x 5-%"Baker SB-3A packer at 10,055' / 5-1/2", 17#, L-801PC x 7'; 26#, NT-80-S IPC Tubing with WLEG at 10,135' / 6-%" CIW tree FMC Big Bore. / MIT T to 3000 psi (PASSED). MIT IA to 3000 psi (FAILED) at a LLR of 2.0 bpm @ 2200 psi. MIT OA to 2000 psi (PASSED) 8/25/05 / Set 5 1 /2 XXN Q 10, 095 SLM 8/28/05 / Leak detection log showed 9-%" casing leak at 7665' and 8/31/05 / PPPOT-T&IC Passed 9/14/05 • Notify the field AOGCC representative with intent to plug and abandon Detailed Pre-Ria Work Request 1. S Pull Tailpipe plug at 10,123' md. 2. S Run static pressure survey to determine BHP for proper mud weight during drilling operations. 3. O Circulate out freeze protect and fluid-pack the well to seawater or kill-weight fluid. 4. C R/U coiled tubing. RIH and plug and abandon the open perforations (328' from 10,630' -10,958') with a minimum of 900' (>35 bbls) of 15.8ppg class `G' cement from PBTD @ 10,992' to the 7"x 5-'/z" crossover C 10,051'. Pressure test the cement plug to 3,500 psi for 30 minutes. 5. S Drift the 7" 26# L-80 tubing to estimated TOC C~ 10,051' md, below the planned tubing cut depth of 10,000' md. Tag cement to verify TOC depth. 6. E R/U SWS E-line. RIH with the appropriate chemical cutter and cut the 7" tubing at ± 10,000' md, in the middle of the full length tubing joint. 7. O Circulate the well to seawater through the tubing cut until returns are clean. 8. O Bleed casing and annulus pressures to zero. Freeze protect to 2,200' and with diesel. 9. O Function all tubing and casing Lock Down Screws. Repair and replace as necessary. Test 9 5/8" packoff to 5,000 psi for 30 minutes. 10. O Set a BPV. Remove well house and flow fine. Level the pad as necessary. Rig Operations: 1. MIRU Nabors 27E. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to 8.8 ppg brine. Install TWC. 3. Nipple down the tree. Nipple up and test BOPS to 4,000 psi. Pull TWC. 4. R/U. Pull the 7" tubing from the tubing cut at 10,000' md. 5. RU wireline and drift the 9 5/8" casing to 4,200' md. Set 9 5/8" bridge plug at 4200'. 6. RIH with multi-string cutter and cut the 9 5/8" casing 80' below the 13 3/8" casing shoe. Attempt to circulate through first cut. if unsuccessful, cut again at 40' above the casing shoe. Lay down cutter. 7. Spear the 9 5/a" casing at surface and recover top 3,900' of 9 5/8" casing. 8. MU spear and jars and recover bottom 120' cut stub. 9. MU 12-'/a" bit and 13 3/8" casing scraper. Cleanout to top of 9 5/8" casing stub. 10. RIH with mule shoe on drill pipe and lay balanced cement kickoff plug from 9 5/8" bridge plug to 200' inside the 13 3/8" casing with 17 ppg cement. `11. PU 12-'/a" drilling assembly and dress cement top to 3,950' md. 12. Swap to 8.8 LSND drilling fluid. 13. Kick off and drill to top of Zone 4 drilling target, weighting up to 10.4 ppg by top of HRZ. CBU, POH 14. RIH with 9 5/8" long string and perform 2-stage cement job through shoe and a Halliburton EZSV stage '~'~•c,S lo' ~ I tool @ 7,450' and in UG1. Top of second stage designed to reach 13 3/6" casing shoe. Bullhead WJ A- ~ • freeze protect to 2,200' with diesel. 15. MU 8-'/z" drilling assembly. Drill ES cementer. Test the casing to 4,000 psi. Drill out shoe tract and swap over to 8.5 ppg Flo-Pro SF. 16. Drill 20' of formation and perform FIT to 9.5 ppg. AGI-07A Permit to Drill Application Page 5 r • 17. Drill ahead, per directional proposal, through the reservoir section. 18. CBU, POH. Spot liner running pill. 19. Run 7" slotted production liner. RU wireline and run USIT in 9 5/8" casing from the intermediate shoe to at least 3,900' and (find TOC). 20. Run 7 5/s" x 7" completion, stinging into the 7" liner tie back sleeve. 21. Space and land the completion. RILDS. 22. Install and test TWC. Nipple down the ROPE. 23. Nipple up the adapter and tree and test to 5,000 psi. Pull the TWC. 24. Circulate the annulus to seawater with Corrosion Inhibitor, followed by 134 bbls diesel. 25. RU U-tube line. Allow diesel to U-tube to the tubing side to provide 2,200' freeze protection. 26. Drop the ball /rod. Set the packer and individually test the tubing to 4,000 psi and annulus to 3,800 psi for 30 minutes. Record each test. 27. Install a BPV. Secure the well. 28. Rig down and move off. Post-RiA Operations: 1. S MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. O Re-install the well house, instrumentation, and flow line. 3. S Set SSSV. AGI-07A Permit to Drill Application Page 6 Phase 1: Move In / Rig Up /Accept Planned Phase Time Planned Phase Cost 54.0 hours $136,552 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - There are two near-by neighboring wells, AGI-06 and AGI-08. AGI-06 is 118.5' to the south and AGI-08 is 121.4' to the north of AGI-07. - Metering shack may need to be moved for MIRU. Care should be taken while moving onto the well. Spotters should be employed at all times. - AGI pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading AGI-06 N/A AGI-06 N/A AGI-08 N/A AGI-08 N!A - No H2S readings have been taken on this pad as it is a gas injection pad. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. - Check the spool height on AGI-07 prior to rig mobilization. The BOP nipple up may need review for proper space-out prior to decomplete. Phase 2: Decomplete Well Planned Phase Time Planned Phase Cost 110.0 hours $527,606 Reference RP • "Casing Cut and Pull w/ Baker Back Off Tool" RP • "Decompletions" RP • "Setting a Kick Off or Abandonment Plug in Open Hole" RP Issues and Potential Hazards - BOP test during this phase is 7 days. - Monitor Annulus for pressure before any work is done on the tree. - Ensure emergency slips are welded the Intermediate casing prior to pulling to prevent lost junk in the hole. Phase 5: Drill 12-~/a" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 190.0 hours $891,492 Reference RP • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" RP AGI-07A Permit to Drill Application Page 7 • ~ • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - This well bore will drill the HRZ at ~41 ° inclination, terminating in the top of the Sag. The HRZ will require a mud weight of 10.4 ppg. Maintain mud weight at 10.4 ppg from above the HRZ to 9-5/a" casing point. Follow all shale drilling practices to minimize potential problems. - Lost circulation is not expected. Monitor ECD and consult the Lost Circulation Decision Tree, embedded in the mud program, regarding LCM treatments and procedures if necessary. - Offset wells did experience difficulty with pipe sticking. Work pipe through tight spots and maintain the programmed mud specs. In the neighboring pads, stuck pipe, by far, was the worst problem encountered. Keep pipe moving as much as possible, minimize the "in slips" time. - In offset pads, gas cut mud was witnessed in the Colville. Watch for such signs and weight up if necessary. - KICK TOLERANCE: In the scenario of 10.0 ppg pore pressure in the West Sak, a minimum fracture gradient of 12.7 ppg at the surface casing shoe, and 8.8 ppg mud in the hole, the kick tolerance is 51.7 bbls. Phase 6: Run and Cement 9 5/S" Intermediate Casing Planned Phase Time Planned Phase Cost 48 hours $861,694 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. The 10.4 ppg LSND used for drilling the HRZ will create a 600 psi over-balance in the West Sak. There is a higher possibility of differential sticking with this mud weight. Minimize the amount of time spent stationary. Connection times should not be 20 minutes. - This intermediate casing cement job is planned as a two stage job, the first stage consisting of 1,000' of 15.8 ppg class G and 1,550' of 11.0 ppg Litecrete to the stage tool @ 7,450' and and a second stage consisting of a 11.0 ppg Litecrete slurry to the surface casing shoe C~3 3,936'. - Ensure that the first stage cement has reach 70 Bc prior to pumping the second stage. Prior to opening the stage tool for the second stage, ensure that the closing plug has been loaded in the cement head. - Immediately after closing the ES Cementer, begin injection down the backside to ensure shoe is cleared and open. - Confirm that the intermediate casing cement has had adequate thickening time (70 Bc value), prior to freeze protecting the 13 3/8" by 9 5/8" casing annulus. If necessary, ensure a double barrier is in place on the annulus, at the surface, until the cement has set up for at least 12 hours. - Request a UCA from Schlumberger Dowell. Confirm a cement compressive strength of 1,000 psi prior to pressure testing the 9 5/8" casing. AGI-07A Permit to Drill Application Page 8 • Phase 7: Drill 8-'h" Production Hole Interval Planned Phase Time Planned Phase Cost 42 hours $349,397 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - There are no expected fault crossings in the production hole section; losses are not expected. However, should losses occur, follow the Lost Circulation Decision Tree, embedded in the mud program, regarding LCM treatments and procedures. Consider swapping to seawater if losses are substantial. - KICK TOLERANCE: In the scenario of 9.0 ppg pore pressure in the Ivishak, a minimum fracture gradient of 10.0 ppg at the intermediate casing shoe, and 8.8 ppg mud in the hole, the kick tolerance is infinite. - If a request is made to extend the well bore beyond the planned TD coordinate, regardless the revised TD location relative to the polygon, contact the drilling engineer prior to drilling ahead. - Ensure that gas cut mud is reported immediately. Heightened awareness should be used during all trips and circulations. Due to the volume of gas that has been historically injected, the potential exists for well control problems if any gas to surface is not reported immediately. Phase 9: Run 7" Slotted Liner Planned Phase Time Planned Phase Cost 33 hours $210,903 Reference RP • N/A Issues and Potential Hazards - The planned production liner is a 7", 26#, L-80, BTC slotted liner through the production interval. - Differential sticking is possible. The 8.5 ppg Flo-Pro will be slightly over balanced to the Ivishak Sands. Minimize the time the pipe is left stationary while running the liner. - Sufficient 7" 26# solid liner will be run to extend -150' back to the 9 5/8" casing shoe. - Ensure the 7" liner top packer is set prior to POOH. Phase 12: Run 7 5/8" IPC L-80 Completion Planned Phase Time Planned Phase Cost 31 hours $583,020 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP AGI-07A Permit to Drill Application Page 9 C7 • Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 7-5/8", 29.7# , L-80 IPC, Vam Top production tubing string crossing over to 7", 26# L-80 IPC Vam Top just above the S-3 packer and stinging into the 7" liner tieback sleeve. Phase 13: ND/NU/Release Ria Planned Phase Time Planned Phase Cost 14 hours $48,041 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - There are two near-by neighboring wells, AGI-06 and AGI-08. AGI-06 is 118' to the south and AGI-08 is 122' to the north of AGI-07A well. - Care should be taken while moving off of the well. Spotters should be employed at all times. - During ND BOPE/NU tree operations, the AGI-07A well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - During RD/MO operations, the AGI-07A well bore will be secured with the following barriers: o Tubing: BPV and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. AGI-07A Permit to Drill Application Page 10 • Drillin r n 4nin i POST THIS NCITICE Ily THE DOGHaUS I. Well Control A. The Ugnu may be over pressured. Although this pad is relatively far from the G&I plant, over pressuring in the UGNU is possible. B. Be wary of possible overpressure towards TD. Static surveys indicate that the reservoir is under pressured; however, untested charged zones may exist. II. Hydrates and Shallow gas A. Gas Hydrates are not expected; however, they may exist in close proximity to the surface casing shoe. Recommended practices and precautions for drilling hydrates should be followed for the first several hundred feet after kick off. B. Offset pads experienced gas cut mud in the Colville, be prepared to weight up if necessary. 111. Lost Circulation/Breathing A. Lost circulation is possible, and has been mostly associated with running casing and cementing. Ensure that good casing running practices are followed and cement ECD guidelines are honored. B. Breathing is not expected in this well, Kingak and Shublik have been eroded by the Lower Cretaceous Unconformity (LCU). IV. Kick Tolerance/Integrity Testing A. The 7" casing will be cemented with 15.8 Ib/gal tail and 11.0 Ib/gal lead cement to the surface shoe @ 3,936' and in two stages. B. The Kick Tolerance at the surface casing shoe is 53.6 bbls with 10.3 ppg mud, 12.7 ppg LOT, and a 10.5 ppg pore pressure. Integrity Testing -12.7 ppg EMW LOT C. The 7" production liner is slotted and will not require cement. a. The Kick Tolerance for the intermediate casing is infinte with 8.8 ppg mud, 10.0 ppg FIT and a 10.5 ppg pore. pressure. Integrity Testing - 10.0 ppg EMW FIT V. Stuck Pipe A. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions B. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide AGI Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Personal monitors must be worn at all times. There have been no H2S readings on this pad: Adjacent Producers at Surface: AGI-06 N/A AGI-08 N/A Adjacent Producers at TD: AGI-06 N/A AGI-08 N/A VII. Faults A. No faults are expected in this wellbore. T SHEETS D4 NOT EXIST FOR THE GAS I,JCTIC?N PADS AGI-07A Permit to Drill Application Page 11 TREE _ WELLHEAD = ACTUATOR = KB. ELEV = CIW BAKERC 49' BF. ELEV KOP = 1600' Max Angle = 50 @ 11015' Datum MD = 11506' Datum TVD = 8800' SS ~ AGI-07 I 13-3/8" CSG, 68#, K-55, ~ ??? (TOP TWO JOINTS) 13-318" CSG, 68#, L-80, ID = 12.415" 3936' Minimum ID = 4.455" @ 10123' 5-1 /2" OTIS XN NIPPLE 7" TBG, 26#, NT-80-S-IPC, NSCC, .0383 bpf, ID = 6.276" 10051' TOP OF 5-1(2" TBG 10051' S NOTES: LINER NOT CEMENTED. AL G IS IPC W ITH NSCC THREAD. 2186' ~-~ 7" CAMCO BAL-O SSSV NIP, ID = 5.937" 10051' ~-~ 7" X 5-112" XO, ID = 4.875" 10054' --~ ANCHOR, ID = 4.875" 10055' 9-5/8" X 5-1/2" BAKER SB-3A PKR, ID = 4.874" 10102' (~ 5-1/2" PARKER SWS NIP, ID = 4.562" ~ ~-v2' a~s~avl~lw f~4.4~' I OF 7" LNR I1 10129' ~ ~ 5-1/2" TBG, 17#, L-80-IPC, NSCC, .0232 bpf, ID = 4.892" ~-j 10135' 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" ~-j 10306' PERFORATION SUMMARY REF LOG: MWD DPR ON 04(28/93 ANGLE AT TOP PERF: 49 @ 10630' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 10630 - 10650 C 06/17/93 3-318" 6 10668 - 10678 C 06!17(93 3-318" 6 10764 - 10784 C 06/17/93 3-318" 6 10824 - 10844 C 06/17/93 3-3/8" 6 10858 - 10868 C 06/17/93 3-318" 6 10938 - 10958 C 06/17/93 7" LNR, 29#, NT-80-S, .0371 bpf , ID = 6.184" ~-~ 11013' 10135' -~ 5-1/2" WLEG, ID = 4.892" 101 ELMD TT LOGGED 06108!93 11010' J~(2) SHEAROUT BALLS W/RODS, 05/01/93 PBTD I~ 10992' DATE REV BY COMMENTS DATE REV BY COMMENTS 05!03!93 ORIGINAL COMPLETION 05!22/01 RhUKAK CORRECTIONS 03/09/03 ASlTP ADD tPClfl-TREAD FOR TBG 05/12/03 JRC/KK ADD 13-3/8", K-55 CSG 09/22/05 MORlTL XN TTP SET (08128/05) PRUDHOE BAY UNff WELL: AGI-07 PERMIT No: 1930270 API No: 50-029-22343-00 SEC 36, T12N, R14E, 1271.69' FEl & 1056.95' FNL BP Exploration (Alaska) TRFF = WELLHEAD = ACTUATOR= CIW BAKERC KB. ELEV = BF. ELEV = 49' KOP = 1600' Max Angle = Datum MD = 50 @ 11015' 11506' Datum TVD = 8800`SS AGI-~'A Proposed 13-318" CSG, 68#, K-55, ??? (TOP TWO JOINTS) 13-318" CSG, 68#, L-80, ID = 12.415" 3936' Minimum ID = 5.770" @ 9760` 7" HES RN NIPPLE TOP OF 9 5/8" 4025' 9 5/8" EZSV 4200' 7 5/8" TBG, 29.7#, L-80-IPC, VAM Top HC, ID = 6.875", 0.04591 BBL/FT 7450' 9 5l8" TAM port collar Top of 7" 10000' TOP OF 7" LNR I-i 10129' 9-5/8" CSG, 47#, NT-80-S, ID = 8.681" 10306' 2060' 7 5/8" x 7" XO 2100' 7" CAMCO DB SSSV NIP, ID = 6.0" 2140' 7" x 7 5/8" XO 9750' 7 5!8" x 7" 26# TGII XO 9790' 7" R Nipple, ID = 5.963" 9 5/8" x 7" Baker S-3 Pkr, 7" 9805, 26# TGII, ID = 6.059" 9830' 7" RN Nipple, ID = 5.770" -, PERFORATION SUMMARY REF LOG: MWD DPR ON 04!28/93 ANGLE AT TOP PERF: 49 @ 10630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10630 - 10958 S 06/17/93 10450' 7" 29# L-80 Slotted PBTD 7" LNR, 29#, NT-80-S 11013' 10534' 7" 29# TD DATE REV BY COMMENTS DATE REV BY COMMENTS 05/03/93 ORIGINAL COMPLETION 11(01(05 PGS Proposed Sidetrack PRUDHOE BAY UNfT WELL: AGI-07A PERMIT No: 1930270 API No: 50-029-22343-01 SEC 36, T12N, R14E, 1271.69' FEL & 1056.95' FNL BP Exploration (Alaska) 0 ;-~ z a a J ~ a ~ -N- I AG[ SOUTH ACCESS ROAD ~ #5 ~ #4 ~ #3 ~ #2 ~ #1 AGI PAD LEGEND J ~ CONDUCTOR AS-BUILT THIS SURVEY. LUC.AItU mmirv YK UIKACItU 5ECIION 36, T12N , R14E, U.M., AK. WELL A.S.P. PLANT GEODETIC CELLAR BOX SECTION N0. COORDINATES COORDINATE POSITION ELEVATION OFFSETS 6 Y=5979811.69 N.5640.06 70'20'58.482" , 2174' FSL X= 688781.77 E.4999.95 148'28'02.062" 13.5 2495' FEL 7 Y=5979929.37 N.5760.15 70'20'59.645" ' 2292 FSL X= 688757.89 E.5000.01 148'28'02.673" 13.5 2516' FEL 8 Y=5980046.92 N.5880.12 70'21'00.807" ' 2410' FSL X= 688733.95 E.4999.99 148'28'03,286" 13 5 2537' FEL 9 Y=5980164.22 N.5999.79 70'21'01.966" ' 2528' FSL X= 688710.26 E.5000.16 148'28'03.892" 13 5 2557' FEL 10 Y=5980281.94 N.6119.98 70'21'03.130" , 2646' FSL X= 688686.10 E.4999.94 148'28'04.511" 13.6 2579' FEL 0 11/29/192 ORIGINAL AS-BUILT ISSUE TB AOM ' NO DATE REVISIONS DRAWN CHECK 2 ~ ~~ z vNi W ~ U <~ a ~ #10 o ~ #9 a 0 ~ • #8 v l ~ #7 wf `~ I l I ~ #6 I PRUDHOfI BAY z WEST BEACH I 26 STATE PAD 25~-N- _ __ ___ __ ~T~~~ 35 36' 31 ~ SURVEY o AREA o 0 ~I~ . AGI PAD ~ ; ~ VICINITY MAP N. r. s. ,~~ ^F q~~ *:'49TH °:~ . o ............:....... F. ROBERT BELL ;',~ 's ' ~~°° 3252-5 °~ .~ ssION~~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY OlRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER 24, 1992. NOTES 1. COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4, NAD 27. 2. BASIS OF LOCATION PER MONUMENTS CCP "C" AND L1 NORTH/L1 SOUTH (BRAUN). 3. REFERENCE FIELD BOOKS: PB92-37(pgs.53-55); P892-40(pgs.28-40). 4. DATE OF SURVEY: NOVEMBER 10, 23 dt 24, 1992. 5. ASP GRID SCALE FACTOR = 0.9999405 6. REFERENCE SHEET 1 FOR WELLS 1, 2, 3. 4 & 5. F. ROBERT BELL & ASSOC. ARCO Alaska Inc. ~~ AGI PAD CONDUCTOR AS-BUILT WELLS # 1-10 11/29/92 BARNHART MiNISH N.T.S. 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J ~ F _ i x i I - n O o O o o 00^ oo - _ - ._7 Q O R R O O ~ ~ r I c ~' 3 Ma~~~ .~ ~ I ~ ~ i i _ J ~ _ - <-- = .:.9 ~ 3 0 I ,~ ~ - _ o i 6 E~ - _ 5'. _ -a _ - _ ~~'~ Y z r- r 'J N M - O ~ ~ . . I ~ _ .. I __ - - N _ _ - _ ~ F z I _ _ ~ - _ ~ y. ' ~ ' ~~,x~- + 41 - _ . . 3. -iE.n vi 1~ ? ~f r VI I ~ y _ _ a - I . nc o~ ~ I MMM~b ~ '~ I - - ~~ --- ~" I ~ ~ o O _ C' 7 N N N N ~ ~ ~wr,rr- ~ + . I _ I - I _ ~ r`~~_zm d - cz--- e ~., e ~ -~ I ~ - - a ~ a o -~- ----- I i ~i T ~ ~ _. T ~- -- _ -- - - - ~- - -- ~ _ - . ~ ~. _ ~~~x° 7acoo -- Vl -r~r+l?Vl 0 M 0 N ~ !/ O L~ +)4 o ( )4 0 N 1n s - 0 a ~ ~ • Sperry-Sun BP Planning Report Company:. BP Amoco Date: 3/27/2006 Time: 16:D9:30 Page: i :.Field: Prudhoe Bay (various) - 'Co-ordinate(NE)Reference: WeIL• AGI-07, True North Si e: AGI Vertical ('['YD) Reference: 32.5 + 13.5 46.0 Well: AGI-07 Section (VS) Reference: Well (O.OON,O:OOE,72:68Azi) Wellpath: ' Plan AGI-07A Survey CakulaHon Method: Minimum Curvature Db: Oracle Plan: AGI-07A wp04 Date Composed: 10/17/2005 Version: 15 Principal: Yes Tied-to: From: Definitive Path 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: bggm2005 Site: AGI TR-12-14 UNITED STATES :North Slope Site Position: Northing: 5973288.42 ft Latitude: 70 19 55.268 N From: Map Easting: 685006.87 ft Longitude: 148 29 57.054 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Crid Convergence: 1.41 deg Well: AGI-07 Slot Name: AGI-07 Well Position: +N/-S 6546.81 ft Northing: 5979929.37 ft Latitude: 70 20 59.646 N +E/-W 3913.91 ft Easting : 688757.89 ft Longitude: 148 28 2.673 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10000.67 8071.00 9.625 12.250 9 5/8" 10534.00 8473.02 7.000 8.500 7" Formations MD TVD Formations- Lithology Dep Ar-gle Dip Direction ft ft deg deg 7911.23 6496.00 WS2 0.00 0.00 8077.06 6621.00 WS1 0.00 0.00 8209.73 6721.00 CM3 0.00 0.00 8534.75 6966.00 CM2 0.00 0.00 9038.87 7346.00 CM1 0.00 0.00 9695.54 7841.00 THRZ 0.00 0.00 9983.42 8058.00 LCU 0.00 0.00 10000.67 8071.00 43SB 0.00 0.00 10013.93 8081.00 TCGL 0.00 0.00 10133.33 8171.00. BCGL 0.00 0.00 10219.56 8236.00 23SB 0.00 0.00 10246.09 8256.00 22TS 0.00 0.00 10292.53 8291.00 21 TS 0.00 0.00 10411.92 8381.00 TZ1 B 0.00 0.00 10451.72 8411.00 TDF 0.00 0.00 10498.15 8446.00 BSAD 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude -> Name- Description - TVD +N!-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip..: . Dir. ft ft ft ff ft ` AGI-07A T1 8469.00 1700.01 5450.01 5981766.01 694163.02 70 21 16.345 N 148 25 23.366 W -Circle (Radius: 200) -Plan hit target • Sperry-Sun BP Planning Report Company:. BP Amoco Date:. 3/27/2006- Time: 15:09:30 Page: 2 ..Field: Prudhoe Bay (various) Co-ordinate(NEJ Reference: W eIL• AGI-07, True North Site: AGI Vertical (TVD) Reference: 32.5+.13,546.0 Well: AGI-07 Section (VS) Reference: Well (O.OON,O.OOE,72.68Azi) Wellpath: P lan AGI-07A Survey Calculation Method: Minimum Curvature Db: Oracle '- Plan Section Information MD Incl Azim TVD ' +N/-S" +E/-W DLS Build Turn TFO "Target ft deg deg. ft ft ft deg/100ft deg/t00ft 'degl100ft deg 4036.00 44.17 70.59 3572.33 456.53 1373.39 0.00 0.00 0.00 0.00 4286.00 38.36 82.97 3760.48 495.07 1532.95 4.00 -2.33 4.95 130.00 4462.41 41.08 72.77 3896.30 518.97 1642.77 4.00 1.54 -5.78 -71.35 10528.67 41.08 72.77 8469.00 1700.01 5450.01 0.00 0.00 0.00 0.00 AGI-07A T1 10534.09 41.08 72.77 8473.09 1701.06 5453.41 0.00 0.00 0.00 0.00 Survey MD Inch Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft' deg/100ft ft ft 4036.00 44.17 70.59 3572.33 3526.33 1447.03 456.53 1373.39 0.00 5980420.32 690119.27 Start Dir 4/ 4100.00 42.56 73.49 3618.86 3572.86 1490.97 470.09 1415.18 4.00 5980434.93 690160.70 MWD+IFR 4200.00 40.21 78.38 3693.90 3647.90 1556.93 486.21 1479.25 4.00 5980452.66 690224.34 MWD+IFR 4286.00 38.36 82.97 3760.48 3714.48 1610.82 495.07 1532.95 4.00 5980462.86 690277.79 MWD+IFR 4300.00 38.54 82.12 3771.44 3725.44 1619.40 496.20 1541.58 4.00 5980464.21 690286.39 MWD+IFR 4400.00 40.02 76.24 3848.87 3802.87 1682.25 508.12 1603.69 4.00 5980477.70 690348.18 MWD+IFR 4462.41 41.08 72.77 3896.30 3850.30 1722.79 518.97 1642.77 4.00 5980489.53 690386.97 End Dir 4500.00 41.08 72.77 3924.64 3878.64 1747.49 526.29 1666.36 0.00 5980497.44 690410.37 MWD+IFR 4600.00 41.08 72.77 4000.02 3954.02 1813.20 545.76 1729.13 0.00 5980518.48 690472.62 MWD+IFR 4700.00 41.08 72.77 4075.39 4029.39 1878.91 565.23 1791.89 0.00 5980539.52 690534.86 MWD+IFR 4800.00 41.08 72.77 4150.77 4104.77 1944.62 584.70 1854.65 0.00 5980560.56 690597.11 MWD+IFR 4900.00 41.08 72.77 4226.15 4180.15 2010.33 604.17 1917.41 0.00 5980581.61 690659.36 MWD+IFR 5000.00 41.08 72.77 4301.53 4255.53 2076.04 623.64 1980.17 0.00 5980602.65 690721.60 MWD+IFR 5100.00 41.08 72.77 4376.91 4330.91 2141.76 643.11 2042.93 0.00 5980623.69 690783.85 MWD+IFR 5200.00 41.08 72.77 4452.29 4406.29 2207.47 662.57 2105.69 0.00 5980644.73 690846.10 MWD+IFR 5300.00 41.08 72.77 4527.67 4481.67 2273.18 682.04 2168.45 0.00 5980665.77 690908.35 MWD+IFR 5400.00 41.08 72.77 4603.05 4557.05 2338.89 701.51 2231.21 0.00 5980686.82 690970.59 MWD+IFR 5500.00 41.08 72.77 4678.43 4632.43 2404.60 720.98 2293.97 0.00 5980707.86 691032.84 MWD+IFR 5600.00 41.08 72.77 4753.81 4707.81 2470.31 740.45 2356.73 0.00 5980728.90 691095.09 MWD+IFR 5700.00 41.08 72.77 4829.19 4783.19 2536.02 759.92 2419.50 0.00 5980749.94 691157.33 MWD+IFR 5800.00 41.08 72.77 4904.57 4858.57 2601.73 779.39 2482.26 0.00 5980770.99 691219.58 MWD+IFR 5900.00 41.08 72.77 4979.95 4933.95 2667.44 798.86 2545.02 0.00 5980792.03 691281.83 MWD+IFR 6000.00 41.08 72.77 5055.33 5009.33 2733.16 818.33 2607.78 0.00 5980813.07 691344.07 MWD+IFR 6100.00 41.08 72.77 5130.70 5084.70 2798.87 837.79 2670.54 0.00 5980834.11 691406.32 MWD+IFR 6200.00 41.08 72.77 5206.08 5160.08 2864.58 857.26 2733.30 0.00 5980855.16 691468.57 MWD+-FR 6300.00 41.08 72.77 5281.46 5235.46 2930.29 876.73 2796.06 0.00 5980876.20 691530.81 MWD+IFR 6400.00 41.08 72.77 5356.84 5310.84 2996.00 896.20 2858.82 0.00 5980897.24 691593.06 MWD+IFR 6500.00 41.08 72.77 5432.22 5386.22 3061.71 915.67 2921.58 0.00 5980918.28 691655.31 MWD+IFR 6600.00 41.08 72.77 5507.60 5461.60 3127.42 935.14 2984.34 0.00 5980939.33 691717.55 MWD+IFR 6700.00 41.08 72.77 5582.98 5536.98 3193.13 954.61 3047.10 0.00 5980960.37 691779.80 MWD+IFR 6800.00 41.08 72.77 5658.36 5612.36 3258.84 974.08 3109.86 0.00 5980981.41 691842.05 MWD+IFR 6900.00 41.08 72.77 5733.74 5687.74 3324.56 993.55 3172.63 0.00 5981002.45 691904.29 MWD+IFR 7000.00 41.08 72.77 5809.12 5763.12 3390.27 1013.01 3235.39 0.00 5981023.50 691966.54 MWD+IFR 7100.00 41.08 72.77 5884.50 5838.50 3455.98 1032.48 3298.15 0.00 5981044.54 692028.79 MWD+IFR 7200.00 41.08 72.77 5959.88 5913.88 3521.69 1051.95 3360.91 0.00 5981065.58 692091.04 MWD+IFR 7300.00 41.08 72.77 6035.26 5989.26 3587.40 1071.42 3423.67 0.00 5981086.62 692153.28 MWD+IFR 7400.00 41.08 72.77 6110.64 6064.64 3653.11 1090.89 3486.43 0.00 5981107.67 692215.53 MWD+IFR 7500.00 41.08 72.77 6186.01 6140.01 3718.82 1110.36 3549.19 0.00 5981128.71 692277.78 MWD+IFR 7600.00 41.08 72.77 6261.39 6215.39 3784.53 1129.83 3611.95 0.00 5981149.75 692340.02 MWD+IFR 7700.00 41.08 72.77 6336.77 6290.77 3850.24 1149.30 3674.71 0.00 5981170.79 692402.27 MWD+IFR 7800.00 41.08 72.77 6412.15 6366.15 3915.96 1168.77 3737.47 0.00 5981191.83 692464.52 MWD+IFR 7900.00 41.08 72.77 6487.53 6441.53 3981.67 1188.23 3800.23 0.00 5981212.88 692526.76 MWD+IFR 7911.23 41.08 72.77 6496.00 6450.00 3989.05 1190.42 3807.29 0.00 5981215.24 692533.76 WS2 8000.00 41.08 72.77 6562.91 6516.91 4047.38 1207.70 3863.00 0.00 5981233.92 692589.01 MWD+IFR 8077.06 41.08 72.77 6621.00 6575.00 4098.02 1222.71 3911.36 0.00 5981250.14 692636.98 WS1 Went 0 4S 4S ~S iS ~S i2 4S tS 1S 1S 9S 7S 1S 7S 7S 9S 1S 1S 1S 1S 1S 1S 1S 1S 1S 9S 9S 1S 1S r„ Sperry-Sun BP Planning Report Company: BP Amoco Date: 3/27/2006 Time: 16:09:30 Page:. 3 :Field: Prutlhoe $ay (various) Co-ordinate(NE} Reference:' W eIL• AGI-07, True North Site: AG I Vertical (TVD} Reference: 32.5 + 13.5 46.0 Well: AG I-07 Section (VS) Reference: Well (O.OON,O.OOE,72:68Azi) ; Wellpath: Plan AGl-07A Survey Calculation Method: Minimum Curvature Db: ' Oracle Survey MD Incl. Azim TVI) SysTVD VS N/S- E/W DLS _MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ff ft ff 8100.00 41.08 72.77 6638.29 6592.29 4113.09 1227.17 3925.76 0.00 5981254.96 692651.26 MWD+IFR 8200.00 41.08 72.77 6713.67 6667.67 4178.80 1246.64 3988.52 0.00 5981276.00 692713.50 MWD+IFR 8209.73 41.08 72.77 6721.00 6675.00 4185.19 1248.53 3994.62 0.00 5981278.05 692719.56 CM3 8300.00 41.08 72.77 6789.05 6743.05 4244.51 1266.11 4051.28 0.00 5981297.05 692775.75 MWD+IFR 8400.00 41.08 72.77 6864.43 6818.43 4310.22 1285.58 4114.04 0.00 5981318.09 692838.00 MWD+IFR 8500.00 41.08 72.77 6939.81 6893.81 4375.93 1305.05 4176.80 0.00 5981339.13 692900.24 MWD+IFR 8534.75 41.08 72.77 6966.00 6920.00 4398.77 1311.81 4198.61 0.00 5981346.44 692921.87 CM2 8600.00 41.08 72.77 7015.19 6969.19 4441.65 1324.52 4239.56 0.00 5981360.17 692962.49 MWD+IFR 8700.00 41.08 72.77 7090.57 7044.57 4507.36 1343.99 4302.32 0.00 5981381.22 693024.74 MWD+IFR 8800.00 41.08 72.77 7165.94 7119.94 4573.07 1363.45 4365.08 0.00 5981402.26 693086.98 MWD+IFR 8900.00 41.08 72.77 7241.32 7195.32 4638.78 1382.92 4427.84 0.00 5981423.30 693149.23 MWD+IFR 9000.00 41.08 72.77 7316.70 7270.70 4704.49 1402.39 4490.60 0.00 5981444.34 693211.48 MWD+IFR 9038.87 41.08 72.77 7346.00 7300.00 4730.03 1409.96 4515.00 0.00 5981452.52 693235.67 CM1 9100.00 41.08 72.77 7392.08 7346.08 4770.20 1421.86 4553.36 0.00 5981465.39 693273.73 MWD+IFR 9200.00 41.08 72.77 7467.46 7421.46 4835.91 1441.33 4616.13 0.00 5981486.43 693335.97 MWD+IFR 9300.00 41.08 72.77 7542.84 7496.84 4901.62 1460.80 4678.89 0.00 5981507.47 693398.22 MWD+IFR 9400.00 41.08 72.77 7618.22 7572.22 4967.33 1480.27 4741.65 0.00 5981528.51 693460.47 MWD+IFR 9500.00 41.08 72.77 7693.60 7647.60 5033.05 1499.74 4804.41 0.00 5981549.56 693522.71 MWD+IFR 9600.00 41.08 72.77 7768.98 7722.98 5098.76 1519.21 4867.17 0.00 5981570.60 693584.96 MWD+IFR 9695.54 41.08 72.77 7841.00 7795.00 5161.54 1537.81 4927.13 0.00 5981590.70 693644.43 THRZ 9700.00 41.08 72.77 7844.36 7798.36 5164.47 1538.67 4929.93 0.00 5981591.64 693647.21 MWD+IFR 9800.00 41.08 72.77 7919.74 7873.74 5230.18 1558.14 4992.69 0.00 5981612.68 693709.45 MWD+IFR 9900.00 41.08 72.77 7995.12 7949.12 5295.89 1577.61 5055.45 0.00 5981633.72 693771.70 MWD+IFR 9983.42 41.08 72.77 8058.00 8012.00 5350.71 1593.85 5107.81 0.00 5981651.28 693823.63 LCU 10000.00 41.08 72.77 8070.50 8024.50 5361.60 1597.08 5118.21 0.00 5981654.77 693833.95 MWD+IFR 10000.67 41.08 72.77 8071.00 8025.00 5362.04 1597.21 5118.63 0.00 5981654.91 693834.36 9 5/8" 10013.93 41.08 72.77 8081.00 8035.00 5370.76 1599.79 5126.96 0.00 5981657.70 693842.62 TCGL 10100.00 41.08 72.77 8145.88 8099.88 5427.31 1616.55 5180.97 0.00 5981675.81 693896.19 MWD+IFR 10133.33 41.08 72.77 8171.00 8125.00 5449.21 1623.04 5201.89 0.00 5981682.82 693916.94 BCGL 10200.00 41.08 72.77 8221.25 8175.25 5493.02 1636.02 5243.73 0.00 5981696.85 693958.44 MWD+IFR 10219.56 41.08 72.77 8236.00 8190.00 5505.88 1639.83 5256.01 0.00 5981700.97 693970.62 23SB 10246.09 41.08 72.77 8256.00 8210.00 5523.31 1644.99 5272.66 0.00 5981706.55 693987.13 22TS 10292.53 41.08 72.77 8291.00 8245.00 5553.82 1654.03 5301.80 0.00 5981716.32 694016.03 21 TS 10300.00 41.08 72.77 8296.63 8250.63 5558.73 1655.49 5306.50 0.00 5981717.89 694020.69 MWD+IFR 10400.00 41.08 72.77 8372.01 8326.01 5624.45 1674.96 5369.26 0.00 5981738.94 694082.93 MWD+IFR 10411.92 41.08 72.77 8381.00 8335.00 5632.28 1677.28 5376.74 0.00 5981741.45 694090.36 TZ1 B 10451.72 41.08 72.77 8411.00 8365.00 5658.43 1685.03 5401.72 0.00 5981749.82 694115.13 TDF 10498.15 41.08 72.77 8446.00 8400.00 5688.94 1694.07 5430.86 0.00 5981759.59 694144.03 BSAD 10500.00 41.08 72.77 8447.39 8401.39 5690.16 1694.43 5432.02 0.00 5981759.98 694145.18 MWD+IFR 10534.00 41.08 72.77 8473.02 8427.02 5712.50 1701.05 5453.36 0.00 5981767.13 694166.34 7" 10534.09 41.08 72.77 8473.09 8427.09 5712.56 1701.06 5453.41 0.00 5981767.15 694166.40 MWD+IFR Went 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S 1S ~~1~-d~5 BP/AAI SHARED SERVICE WELL: AGI-9 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 03/08/93 04:00 SPUD: 03/09/93 02:30 RELEASE: 05/11/93 12:00 OPERATION: DRLG RIG: AUDf 2 WO/C RIG: AUDI 2 03/09/93 ( 1} DRLG. MW: 8.5 VIS: 0 TD: 416'( 4p6U BHA,DSPUD WE ~ @ 02T30 HRS 3 9/93. DRLG TO 4 6 DIVERTER. 03/10/93 ( 2) DRLG. MW: 9.3 VIS:185 TD: 1950'(1534) DRLG F/ 416'-1950'. 03/11/93 ( 3) POOH. MW: 9.5 VIS: 90 TD: 3920'( 1970) DRLG F/ 1950'-2344'. CBU. WIPER TRIP TO KOP. DRLG F/ 2344'-3920'. CBU. WIPER TRIP. CBU. POOH. 03/12/93 { 4) RIH. MW: 9.6 VlS: 61 TD: 3920'( 0) POOH. RIH W/ 13-3/8" CSG. CMT CSG. N/D DIVERTER. TOP JOB. N/U BOPE. TEST BOPE. RIH W/ BHA. 03/13/93 ( 5) SHORT TRIP. MW: 9.3 VIS: 36 TD: 6087'( 2167) RIH TO 3820'. TEST CSG. DRLG FLOAT EOUIP, 10' NEW HOLE. CBU. LOT (12.4 PPG EMW). CIRC. DRLG TO 5056'. CBU. SHORT TRIP. RIH. DRLG TO 6087'. 03/14/93 ( 6) CBU. MW: 9.7 VIS: 40 TD: 7507'( 1420) SHORT TRIP TO 3900'. REAM Fl 4837'-5150'. DRLG Fl 6087'-7117'. CBU. SHORT TRIP TO 3900'. RIH. REAM F/ 6662'-7117'. DRLG F/ 7117'-7507'. CBU. 03/15/93 ( 7) DRLG. MW: 9.7 VIS: 44 TD: 8450'( 943) 'DROP SURVEY. POOH. CHANGE BIT. RIH. REAM F/ 7409'-7507'. DRLG F/ 7507'-8450'. 03/16!93 ( 8} DRLG. MW: 9.9 VIS: 43 TD: 9360'( 910) DRLG TO 8718'. CBU. POOH. CHANGE BiT. RIH. REAM F/ 8628'-8718'. DRLG F/ 8718'-9360'. 03/17/93 ( 9) RUN 9-5/8" CSG. MW: 9.9 VIS: 0 TD:f 0140'( 780) DRLG 7010140'. CBU. SHORT TRIP TO 8534'. CIRC. POOH. TEST BOPE. RlH W/ 9-5/8" CSG. 03/18/93 (10) N/D BOPE. MW: 9.9 VIS: 0 TD:10140'( 0) RIH W/ 9-5/8" CSG. CIRC @ SHOE. RIH W/CSG. CIRC. CMT '~ 7 ~.. ~~ ~, ~ (1 ~(~~°~ GSG. L/D CSG EQUIP. INSTALL PACKOFF. TEST SAME. RiH TO ~ ~ ~ ~ ~ 2000'. F/P WELL W/DIESEL. POOH. N/D BOPE. ~'~ ~; C P -~ 2 ~~93 Ala~k~ Oil & Gas Cons. t;ornrnissian Anchorage WELL AGI 7 OPERATION: RIG AUDI 2 02/24/93 t 10) TD:10326'( 642) . ~ PAGE: 2 POOH. MW: 9.9 VIS: 41 DRLG F/ 9684'.-10233'. POOH TO LOOK FOR WASHOUT. DRLG F/ 10233'-10326'. CBU. SHORT TRIP TO 9713'. CIRC. POOH. 02/25/93 ( 11) N/D BOPE. MW: 8.5 VIS: 0 TD•10326'( 0) POOH. L/D BHA. RIH W/ 9-5/8" CSG. WASH TO 10306'. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 82 BBLS 'G' CMT. DISP W/ SEAWATER. BUMP PLUG W/ 2000 PSI. L/D CSG TOOLS. INSTALL PACKOFF. INJECT 200 BBLS MUD DN ANNULUS. RIH TO 2000'. DISP WELL W/ DIESEL. POOH. F/P ANNULUS. N/D BOPE. 02/26/93 ( 12} RIG RELEASED. MW: 8.5 VIS: 0 TD:10326'( 0) N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 09:00 HRS, 2/25/93. MW: 9.1 VIS: 50 04/28/93 ( 10720'( TD 13) 394) DRLG. HRSB 07 /OO I T/27 TED ~ERIH p, E : I W B~ R H . DISP DIESEL BOPE B4PE. TEST N~U ' . CIRC. TEST CSG. OK. DRLG FLOAT EQUIP, CMT TO 10326 9 FIT (12 ' ' . . -10336 CIRC. DISP TO FLO-PRO. DRLG F/ 10326 PPG EMW). DRLG F/ 10336'-10720'. MW: 9.2 VIS: 60 04/29/93 ( 11015'( TD 14) 295) CIRC. " R 8/9 O H W @ O , T : LNR 7 RIH W/ L/D BHA POOH CBU. SHOED TO TRIP SHORT ON DP. CIRC. RIH TO 11013'. CIRC. NOTE: DAILY COST INCLUDES CORRECTION OF MISSED COSTS. 04/30/93 ( 15) R/I SLICK LINE. MW: 9.3 NaCl DISP WELL W/ BRINE. POOH. L/D RELEASE F/ LNR TD:11015 PB:11015 . SET PKR. RIH O P P M • • S CAMCO. R/U GO ON TBG. NO UP PRESSURE TO ATTEMPT DIESEL 05/01/93 ( I6) RIG RELEASED. MW: 9.3 NaCl TD:11015 R/U CAMCO. PULL DUMMY F/ SSSV. SET PLUG IN NIPPLE. SET PB:11015 PKR. PRESS UP TO 4000 PSI. SET DUMMY IN SSSV. TEST TBG, ANNULUS. OK. SHEAR OUT. PUMP 20 BBLS DIESEL DN TBG. RELAND TBG. RETEST TBG. R/D CAMCO. SET BPV. N/D BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 24:00 HRS, 4/30/93. SIGNATURE: DATE: (drilling superintendent) ~~~~~ A ~ G 2 fi 1993 Alaska Oil & Gas Gans. Commission ~4nchorage WELL AGI-8 OPgRATION: RIG AUDI 2 03/07/93 ( 10) TD:10942'{ 731) 03/08/93 ( il) TD:10942'( 0) 03/09/93 ( 12) TD:10942'( 0) • PAGE: 2 POOH. MW: 9.9 VIS: 44 DRLG. SHORT TRIP. DRLG TO 10942'. CIRC. 25 STDS SHORT TRIP. CBU. POOH. TEST PACKOFF. MW: 8.5 VIS: 0 POOH. L/D BHA. RIH W/ 9-5/8" CSG. CIRC. PUMP 20 BBLS PREFLUSH, 50 BBLS SPACER, 102 BBLLS (500 SX) CMT. DISP W/ SEAWATER. BUMP PLUGS W/ 2500 PSI. R/D HOWCO. INJECT 275 BBLS MUD DN ANNULUS. INSTALL & TEST PACKOFF. RIG RELEASED. MW: 8.5 VIS: 0 DISP TOP 2000' W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. RIG ACCEPTED @ 14:00 HRS, 3/8/93. DATE: SIGNATURE: (drilla.ng supera.ntendent) Yc ~ ~~ ~~ ~~ v 2 F; s99:S gfaska Oil & (;. as E;url.S. ~u~~,rnissis., Anchcraye ,~ >, ;~ ARCO Oti and Gas Company ~~ Dally Well History-Interin inatroeNons: This form is used during ddlling or workover operations. If testing. corm or perloraling,ahow lormation name In deserlbin4 work psrlormed. Number eli drill stem tests segwntially. Attach description of all cores. Work parMrmee~ by Protlucing Seehon will be roportsd on °Inbrim' ahsets until linal comptedon. Repon oflielal or repreaentetivs teat on ' Pinal" form. 1) Submit "Indrkn" ahsets wneh diled out but not lass IrequentlY than every 30 deya, or 121 on WadnesdsY of the week in whiep oil string Is set. Submit weekly for workovers end loilowin9 selling of oil airing until completion, no. Due an depth Complete record for Bash day while tlrilling or workowr in prograu as of 8:00 a.m. 5/02/86 5/03/86 thru 5/05/86 5/06/86 9-5/8" @ 9104' 9088'-9100' Window, Circ Wt. l0, PV 36, YP 22, PH 7.6, WL 4.5, Sol 10 Press core #7 (core #10) f/9992'-10,000'. PU pressure core 116 (core #I1 RIH to shoe, circ, pressure 300 psi high. Pull to window, circ, CO 9' fill. Rn pressure core #8 f/10,000'-10,009.5', POH. MU BHA, RIH to rm core hole. 9-5/8" @ 9104' 9088'-9100' Window, Circ Wt. 10, PV 31, YP 9, PH 7.6, WL 4.8, Sol IO RIH, rm core hole f/10,000'-10,009.5', C&C, POH. PU conventional core bbl, core #12 f/10,009.5'-10,054'; reed 44.5`. RIH w/BHA, rm 9866'-10,054', drl 8~" hole to 10,135', C&C, POH.. RU Schl, log DLL/MSFL/GR f/10,116`-9100', BRCS/GR, LDT/CNL/GR/CAL, RFT/GR. RIH, make wiper trip f/lnr, drop multi-shot, POOH. 7" @ 10,133' 10,135' TD, LD AP Wt. IO+, PV 30, YP 8, PH 7.6, WL 5.1, Sol 10 POH, LD HWDP. RU & rn 30 jta, 7", 29# L-80 BTC lnr w/TOL @ 8760', Mkr j @ 9651', 9670' 6 9689', 7" LC @ 9997', FC @ 10,086' & FS @ !0,133'. Cat w/53$ sx Cl "G" w/5X RC1, 1.2X PZ-19, .5X- CD-31,:-.01X, R-5 St .2X 1PP-8L. ButBp plug. CIP @ 2250 hrs, 5/5/86. Calc TOC ~ 8239' hr/15X excess in OH ann 8 150 sx above Lnr. Rel lnr,'~OII; LD DP. DECEIVED SEP 3 01986 Alaska Oil & Anc Co~ s~ Cr,: Number alt daily wed history forma consecullv0ly Page no. as they ere prepared for seen wall. 3 AR3B-458-2-B '` ~ ~ ~.. • ARCO Oil and Gas Company ~~ Daily Well History-Final Report r and submit the "Final Report" on the first Wednestlay alter allowable has been esse neh of tlmle. Ion Iwo9kove ab whenn an~o icsal dtest is not lnslructione: Pre Pe e "Final Report" should be submitted also when operations ere suspended for an indefinite or appreciabl 9 required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the enure pperatibn if space 'IS available. Addduntin Coat Center Coda f i District COUMy or Parish Alaska North Slo a Borou h Alaska wan no. Field Lease or Unit Prudhoe Bay ADL 4134628 LGI-8 Autn. or w.o. no. nde eFF er.nn99 Drill & Com lets Rowan 4141 ARCO Alaska, Inc. or W.O. begun Saud API 50-029-21562 A.R.CO. W.I. otal number of welt cost tenter prior to I rj0~ abandonment of this Oats Hour 5/03/86 1130 F or inactive) on loft and Prior sl8tus I1 s Date and depth Complete record for each day roported es of 8:00 a. m. 5/29/86 9-5/8" @ 11,966' 13,423', (0'), CBU Wt. 9.4, PV b, YP 4, PH 11.0, WL 8.4, Sol 6 Fin rn'g LSS/GR/Waveform f/13,168'-11,950'. Rn RFT's. Rn CET f/11,940'-8993'. RIH to cond hole f/csg. R E C 5/30/86 7" @ 13,422' 13,423', (0'), POOH wet JUN Wt. 9.4, PV 10, YP 4, PH 10.8, WL 6.8, Sol 6 CBU. Rn 38 jts, 7", L-80, 2911 BTC csg w/LC @ 13,24b', FC @ q;askd 0!) & G8 375' FS @ 13,422', TOL @ 11,767'. Cmt lnr w/600 ex 35./65. 13 , Pozz Cl'"G" cu-t; CIP @ 0435 hrs, 5/30/86. POH. AnC 5/31/86 7" @ 13,422' thru 13,375' PBTD, RR 6/02/86 9.4-NaCl brine w/400' diesel cap POOH. RIH w/8'~" bit/9-5/8" csg scrpr, wah 10,883'-11,377', drl cmt to 11,753' TOL, CBU, POOH. RIH w/6" bit & 7" csg scrpr, CO 7" lnr. DO LC & cmt to 13,375'. Tst csg to 3000 psi. Displ well to 9.4 ppg NaCl brine, POOH, LD DP. ND BOPE, NU tree & tst to 5000-psi. RR @ 1830 hrs, 6/1/86. old TD New TD 13, 423' PB Depth 13 , 375' Released rig Date 6/1/86 Kind of rig Rotar 1830 Hrs. Classifications (oft, gas, etc.) Type completion (single, dual, etc.) 011 Single Producing method Official reservoir name(s) Flowing Lisburne Potential test tlat Wall no. a Date Reservoir Producing Interval Oil or gas Test time Production Oil on lest Gas per day Pump size, SPM X length Choke size T. P, C.P. Water % GOR Goeretctetl Allowable Effective data Ina agave is Wnv~r il9 re For form preparation and distribution. see Procedures Manual. Section f0, Drilling, Pages 86 and a7. _. --tDate (Title 6/II/86 Drilling Supervisor EIVED 71986 Cons. Commtssia Forage ~' ~ i WELL - AGI-6 ~ PAGE: 2 OPE`~ATI ON RIG AUDI 2 MW: 9.8 VIS: 43 02/12/93 ( • 9550'( 10) 707) POOH. DRLG TO 9550'. CBU. SURVEY. POOH. CHANGE MTR, SIT. TD 02/13/93 ( 11) SHORT TRIP. DRLG T M 75' TO BTM MW: O 10590'. TD 9.9 VIS: 42 12-1/4" HOLE. TD:10590'( 1040) . RIH. REA CBU. 15 STDS SHORT TRZP. 02/14/93 ( 12) CMT 9-5/8^ CSG. R/U WOTCO POOH MW: RIH W/ 9-5/ 9.9 VIS: 44 8" CSG. WASH TO TD:10590'( 0) . . CIRC SWEEP. TD. CIRC. 02/15/93 ( 0' 13) 0) RIG RELEASED. MW: PUMP 105 BBLS SLURRY. DISP P7/ R/U HOWCO 9.9 VIS: 0 MUD. BUMP PLUG { TD:1059 . W/ 2000 PSI. R/D CSG EQUIP. SET PACKOFF. TEST SAME. OK. RIH TO 2000'. DISP W/ DIESEL. POOH. N/D BOPE. N/U TREE. TEST TREE. OK. RIG RELEASED @ 19:00 HRS, 2/14/93. DATE: SIGNATURE: (drilling superintendent) ~~~El VED MA R ~ ~ 1993 Alaska Oil & Gas Eons. ~urnmission Anchorage AGI-07A with 1320 ft circle 691.000 692.000 693.000 694.000 695.000 co m m m N m m m m m m co m m m m m cn cfl co m m m 696.00e ~ RG -10 / OD RG1-09 - 340 ~- " _ -836m -~ , ' WB L 1-08 H-01 ~ RG - 7 m R I-0 _ ~~i ~~~ R G I -~0 G ~, -8380 8 -~~ 6 r, - e 3'~ 8 ~8 ~`~6 `~~9 -8380 ._ -0 „g e- ~ , e \\ 8400 4 RGI-04 .---~ 8410. ~--84 0 ~~ -$ 43 RGI-03 -8349-8439 ~~- ~'~~8-~~~ R G I - 01 s o~vwamon uuwc~i x~c. 1:12000 BSRD RGI FOR RGI-07R NELL PLRN FEET 0 1000 2000 FEET r cI ~ 10 FT _--- ~nrr~oa~ _i~nsa~w _ M Contours =BSAD depth map Gray triangles = TSAD well picks Blue triangles =BSAD well picks SONDRA D STEWMAN ss-siz52 144 BP EXPLORATION AK INC "Mastercard Check" PO BOX 1.96612. MB 7-5 _ ~°~, ANCHORAGE, AK 99519-6612 oaTEV:I ~-1_~ PAY. TO THE ~ ~ (' - $ ~. V~ • V ORDER OF ~~2 DOLLARS Firsf National Ba Alaska Anchorage; AK 995r~0~7,`] MEMO 1 ~ V 1 _ I ~: L 2 5 2 0 0 0 6 0 ~: 9 9 L 4 ~~~ 6 2 2 7 ~~~ L 5 6 4 ~~` 0 L 4 4 144 SONDRA D STEWMAN as-sn 252 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 TE~_~~ ~~~ ANCHORAGE, AK 99519-6612 DA PAY TO THE ~~ ~ ~ ~ ~ ~~~ • V~ v ORDER OF `~ _` _j ~; 1 ~~~ DOLLARS -^ ~~ ~ l~Y , ~, t.,t.Y`C.Z. Cam, C~-- -, First National Ba Alaska 1 Anchorage, AK 995 (0 MEM0~1' ~ _ ` ~: L 25 200060:99 L4~~~6 2 27~~~ L56411' 0 L44 SONDRA D STEWMAN BP EXPLORATION- AK INC "Mastercard Check" PO BOX 1986.12 MB 7-5 / ANCHORAGE, A`IC 99519-6612 PAY TO THE ORDER OF First National~Bank Alaska Anchor e, AK 99501 MEM~ DOLLARS ~:Y2~ 200060:99 L4~~~6 2 27~~~ L564~~' 0 i45 / SON D STEWMAN 89-6/1252 146 BP EXPL T(ON AK ING ^Mastercard eck" PO BOX 1966 B 7-5 _ ,D ANCHORAGE, AK 519-6612 DATE - PAY TO THE ,~ ~~ ORDER OF First Nationa Bank Alaska Anchors e, A 99501 MEMO - _ ~' 1- 69-6!1252 1 45 DATEv J -~~^~~~ ~ ~~l~td~ -~' DOLLARS ~: L 2 5 200060:99 L4~~~6 2 2 7~~~ L 564~~' 0 X46 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~d,~~ ~~~'~ ~i~! PTD# Z4 ~' - O .S Z- Development Service Exploratory Stratigraphic Test Non-Conventiona Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing we 11 (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well] until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (,Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. 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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. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 11 18:42:44 2006 Reel Header Service name .............LISTPE Date .....................06/07/11 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/07/11 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 2 MW-000431545 B. TRANI C. NOAKES SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~t3~~~I Scientific Technical Services Scientific Technical Services AGI-07A PB1 500292234370 BP Exploration Inc. (Alaska) Sperry Sun 11-JUL-06 36 12N 14E 2290 2515 .00 47.00 33.50 U 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE BIT SIZE (IN) 12.250 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3931.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW, AND BAT DATA - SMOOTHED TO A 1.5 FT WINDOW. 3. MWD RUNS 1-2 ARE DIRECTIONAL WITH DUAL GAMMA RAY. (DGR ) UTILIZING GEIGER-MUELLER-TUBE DETECTORS. MWD RUN 1 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. LOG AND DIGITAL DATA (MERGED CURVES) ARE SHIFTED TO THE PDC-GR LOG OF 05/28/06 (USI-GR) TO 9417'MD (MWD DEPTH), AND BLOCK SHIFTED BELOW. LOG AND DIGITAL DATA HEADERS AND ANNOTATIONS RETAIN ORIGINAL DRILLER'S DEPT REFERENCES. 5. MWD RUNS 1-2 REPRESENT WELL AGI-07A PB1 WITH API #: 50-029-22343-70 THIS WELL REACHED A TOTAL DEPTH (TD) OF 9730'MD, 7839'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number.. ........1.0.0 Date of Generation.......06/07/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3888.0 9684.5 • • ROP 3926.0 9724.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3895.5 3900.5 3932.0 3938.5 3934.0 3940.5 3938.0 3944.5 3945.0 3951.5 3949.5 3956.5 3960.0 3968.5 3974.0 3982.0 3982.0 3990.0 3990.5 3998.5 4005.5 4013.5 4031.0 4039.0 4032.5 4040.5 4034.5 4042.5 4036.5 4044.5 4039.0 4047,0 4040.5 4048.5 4042.0 4050.0 4044.0 4052.5 4047.5 4056.5 4050.0 4058.5 4065.5 4072.5 4067.0 4074.5 4075.5 4083.0 4082.5 4090.0 4093.5 4103.0 4119.0 4127.0 4128.0 4136.0 4147.0 4153.5 4149.5 4157.0 4153.5 4161.5 4172.0 4182.5 4242.0 4248.0 4244.0 4250.5 4260.5 4266.0 4264.5 4270.5 4268.0 4274.5 4270.0 4276.5 4279.0 4283.5 4282.0 4287.0 4296.0 4299.5 4298.5 4302.0 4302.5 4306.5 4337.0 4341.0 4350.5 4354.5 4354.5 4358.5 4356.5 4360.5 4375.5 4379.5 4377.0 4381.0 4386.0 4390.0 4387.5 4391.5 4394.0 4398.0 4396.5 4400.5 4398.0 4402.5 i • 4406.5 4417.0 4422.5 4425.0 4427.0 4429.0 4430.5 4434.5 4436.0 4440.0 4442.0 4450.0 4454.0 4458.0 4498.5 4506.0 4509.0 4513.0 4517.0 4526.0 4530.0 4532.5 4544.5 4547.0 4551.0 4552.5 4566.0 4568.0 4570.0 4574.5 4579.0 4599.0 4603.5 4607.0 4610.5 4619.5 4621.0 4622.5 4627.0 4649.5 4659.0 4665.0 4668.0 4677.0 4679.5 4684.0 4692.5 4698.5 4702.0 4707.0 4727.0 4746.0 4752.0 4759.5 4769.0 4776.0 4783.5 4788.0 4799.5 4829.5 4840.0 4410.5 4420.0 4427.0 4430.0 4432.5 4434.0 4435.5 4440.5 4442.0 4446.0 4448.0 4456.0 4460.0 4464.5 4504.0 4510.5 4515.0 4519.0 4523.0 4532.0 4536.0 4540.0 4551.5 4554.0 4558.0 4559.5 4572.5 4575.5 4577.5 4582.0 4586.5 4603.5 4608.0 4611.5 4615.0 4624.0 4625.5 4627.0 4631.5 4654.0 4660.5 4664.5 4667.5 4677.0 4679.5 4684.0 4692.5 4699.0 4702.5 4707.5 4729.0 4752.0 4757.0 4764.5 4774.0 4779.5 4789.5 4794.5 4804.5 4836.0 4845.0 • • 4863.5 4865.5 4873.0 4876.5 4878.5 4882.5 4902.5 4919.5 4927.0 4934.5 4938.5 4964.0 4973.0 4976.0 4978.5 4984.0 4988.5 4996.5 4998.5 5004.5 5006.5 5009.0 5013.5 5016.0 5202.0 5205.0 5210.0 5215.0 5223.5 5252.5 5261.0 5277.5 5280.0 5286.5 5289.5 5298.5 5306.0 5313.0 5316.5 5321.0 5357.5 5364.0 5366.5 5372.0 5375.5 5395.0 5420.5 5425.5 5442.0 5463.5 5471.5 5474.5 5476.5 5480.0 5482.5 5486.5 5495.5 5507.0 5511.5 5514.5 5520.5 4869.0 4871.0 4879.0 4882.0 4884.0 4888.0 4907.5 4925.5 4933.5 4939.5 4943.0 4971.0 4980.0 4983.0 4987.0 4992.5 4996.0 5004.0 5006.5 5013.0 5014.5 5016.5 5022.0 5024.5 5207.0 5210.0 5215.0 5220.0 5227.5 5257.5 5266.5 5283.0 5285.5 5292.0 5295.5 5304.5 5312.0 5321.0 5323.5 5327.0 5364.5 5370.0 5372.5 5378.0 5381.5 5403.0 5430.0 5434.5 5450.5 5468.5 5476.5 5479.5 5481.5 5485.5 5487.0 5491.0 5501.0 5512.5 5516.5 5519.0 5523.5 ~ • 5522.0 5530.5 5533.0 5536.5 5541.0 5547.5 5557.5 5561.0 5562.5 5573.0 5574.0 5576.5 5578.5 5583.5 5585.5 5592.0 5595.0 5599.5 5601.5 5610.0 5622.0 5624.0 5633.0 5635.5 5649.0 5661.0 5667.5 5673.5 5678.0 5684.0 5686.5 5688.5 5696.5 5702.0 5704.0 5729.0 5732.5 5736.0 5743.5 5747.5 5754.5 5756.5 5758.0 5760.5 5772.0 5792.0 5806.5 5816.5 5824.0 5828.5 5830.5 5846.0 5854.0 5859.5 5862.0 5877.0 5885.5 5892.5 5913.0 5925.5 5934.0 5525.0 5534.0 5536.5 5540.0 5544.5 5551.0 5560.0 5563.5 5566.5 5577.0 5578.0 5581.0 5583.5 5589.5 5591.5 5598.0 5601.0 5605.5 5608.0 5616.5 5629.0 5631.5 5642.0 5644.0 5655.0 5665.0 5672.5 5679.0 5683.5 5689.5 5692.0 5694.5 5703.0 5708.0 5710.0 5734.5 5738.5 5741.5 5749.0 5754.0 5761.0 5763.0 5764.5 5766.5 5777.5 5797.5 5812.0 5820.5 5828.5 5833.0 5834.5 5850.0 5857.0 5862.5 5865.0 5880.0 5889.5 5895.5 5917.5 5930.0 5938.0 • • 5943.5 5962.0 5964.5 5968.0 5972.5 5979.5 5989.0 5997.5 6017.5 6020.0 6027.5 6035.0 6037.0 6038.5 6040.5 6044.0 6049.0 6051.0 6056.0 6060.0 6073.0 6083.0 6094.0 6096.5 6101.5 6115.0 6117.0 6129.5 6145.0 6149.0 6154.0 6157.0 6159.5 6177.0 6179.5 6185.0 6188.5 6196.0 6201.0 6203.0 6206.5 6210.0 6212.5 6214.0 6218.0 6224.5 6232.0 6233.5 6236.0 6237.5 6241.5 6264.5 6268.5 6270.0 6272.5 6276.0 6279.0 6283.5 6289.5 6295.0 6297.5 5948.0 5965.5 5967.5 5971.0 5975.0 5983.0 5991.0 5999.5 6020.0 6023.0 6030.5 6038.0 6040.0 6041.5 6043.5 6046.5 6051.5 6053.5 6058.5 6062.5 6071.5 6084.5 6095.5 6098.0 6102.5 6116.5 6121.5 6133.5 6148.5 6152.5 6157.5 6161.0 6163.5 6181.0 6183.0 6189.5 6192.0 6199.5 6205.5 6207.5 6211.0 6214.5 6217.0 6218.5 6221.0 6227.5 6235.0 6236.0 6238.5 6240.0 6244.5 6267.5 6271.5 6273.0 6275.5 6279.5 6282.0 6286.5 6293.0 6298.5 6301.0 6299.5 6305.0 6309.0 6311.0 6312.5 6319.0 6324.5 6326.0 6336.5 6340.0 6349.5 6359.0 6365.5 6368.0 6371.5 6376.0 6379.5 6380.5 6391.0 6395.0 6396.5 6405.0 6408.5 6420.5 6432.5 6444.5 6452.0 6455.5 6461.5 6473.5 6480.5 6486.5 6493.5 6495.5 6499.5 6510.5 6518.0 6519.5 6527.0 6553.5 6556.0 6558.0 6561.0 6567.0 6574.5 6589.0 6595.5 6601.0 6606.0 6611.0 6614.0 6619.0 6621.5 6624.5 6652.5 6659.0 6667.5 6670.0 6678.5 6680.5 6685.0 6303.5 6309.0 6313.0 6315.0 6316.0 6322.0 6327.5 6329.0 6340.0 6344.0 6353.0 6362.0 6369.0 6371.5 6375.0 6379.5 6382.5 6384.0 6394.5 6398.5 6400.0 6409.0 6412.0 6424.0 6438.0 6447.5 6455.5 6458.5 6464.5 6476.5 6483.5 6489.5 6496.5 6499.0 6503.0 6514.0 6521.5 6523.0 6530.5 6557.0 6559.5 6561.5 6564.5 6570.5 6577.5 6592.0 6599.0 6604.5 6609.0 6614.0 6617.0 6622.0 6625.0 6628.0 6655.5 6661.5 6670.0 6673.5 6681.0 6683.0 6687.5 • • • 6686.5 6691.5 6694.5 6710.5 6713.5 6720.5 6729.0 6733.5 6738.5 6744.5 6746.5 6753.0 6760.5 6792.5 6798.0 6804.0 6808.5 6837.5 6850.5 6868.0 6870.0 6872.5 6875.0 6877.0 6879.5 6883.0 6889.0 6892.0 6896.0 6906.0 6913.5 6922.0 6942.0 6951.0 6966.0 6984.0 6993.5 6998.0 7001.5 7017.5 7022.0 7030.5 7035.5 7040.0 7045.5 7049.0 7054.0 7057.0 7067.5 7079.5 7087.0 7093.0 7111.0 7120.0 7126.0 7133.5 7141.0 7142.5 7146.0 7150.5 7159.0 6689.0 6694.0 6697.0 6711.0 6714.5 6722.0 6731.5 6736.5 6741.5 6748.0 6750.0 6756.5 6762.5 6793.5 6799.0 6807.0 6811.5 6841.0 6854.0 6870.0 6872.0 6874.5 6878.0 6880.0 6882.5 6886.0 6891.0 6894.0 6898.0 6908.0 6915.5 6923.0 6941.5 6948.5 6964.5 6984.5 6995.0 7000.0 7003.5 7021.0 7026.0 7033.0 7038.0 7043.0 7047.5 7050.5 7056.5 7059.5 7070.5 7082.5 7090.0 7095.5 7114.0 7122.5 7128.0 7135.5 7143.0 7144.5 7148.0 7152.5 7161.0 • • 7165.5 7173.5 7190.5 7196.0 7209.0 7211.0 7218.0 7224.0 7227.5 7240.0 7244.5 7247.0 7253.0 7258.0 7264.0 7266.5 7273.5 7278.5 7280.0 7285.0 7298.0 7303.5 7307.0 7317.0 7320.0 7331.5 7335.0 7360.5 7380.0 7388.0 7396.5 7407.5 7411.0 7413.0 7417.0 7422.0 7425.0 7427.5 7443.0 7451.0 7453.5 7456.5 7465.5 7475.5 7478.0 7483.5 7493.0 7496.0 7502.5 7505.5 7521.5 7535.5 7537.5 7546.5 7551.5 7557.5 7575.5 7579.0 7590.5 7594.5 7595.5 7167.5 7177.0 7192.5 7198.0 7210.0 7211.5 7220.0 7226.0 7229.5 7242.0 7246.5 7248.5 7254.5 7259.0 7265.0 7267.5 7274.5 7281.0 7282.5 7288.5 7301.0 7306.0 7309.5 7319.5 7322.5 7334.0 7338.0 7364.5 7383.0 7390.0 7398.5 7409.5 7412.5 7414.5 7418.5 7422.5 7425.5 7428.0 7444.5 7453.5 7456.0 7459.0 7468.0 7478.0 7479.5 7486.5 7495.0 7498.5 7505.0 7508.0 7524.0 7537.0 7539.5 7548.5 7553.5 7559.5 7576.0 7580.5 7592.0 7596.0 7597.0 7598.0 7600.5 7603.5 7608.5 7612.5 7615.0 7628.0 7656.0 7661.5 7670.0 7674.5 7679.0 7682.5 7692.5 7699.0 7701.5 7710.0 7724.0 7727.5 7738.5 7751.5 7761.5 7766.5 7771.5 7776.0 7779.0 7787.0 7794.5 7821.0 7830.5 7840.0 7851.5 7854.0 7857.0 7864.5 7878.0 7883.0 7886.0 7888.5 7891.5 7928.5 7932.0 7943.5 7948.0 7951.5 7957.0 7959.5 7982.5 7987.0 7990.5 7996.5 7999.5 8005.0 8013.5 8016.5 8047.0 8048.5 8050.0 8054.0 8066.0 8069.5 7599.5 7602.0 7605.0 7610.0 7614.0 7616.5 7629.5 7657.5 7664.5 7671.0 7675.5 7681.0 7686.0 7693.5 7699.5 7702.5 7712.0 7726.0 7728.5 7739.5 7753.5 7762.5 7767.5 7774.0 7779.5 7782.5 7789.0 7797.0 7822.5 7831.0 7839.5 7853.0 7855.5 7858.5 7866.5 7880.0 7884.0 7887.0 7888.5 7892.0 7929.0 7933.0 7942.5 7946.0 7949.5 7954.0 7957.0 7983.0 7988.0 7991.5 7997.5 8000.5 8006.0 8015.0 8017.5 8046.5 8049.0 8051.0 8055.0 8067.0 8070.5 • • • • 8079.0 8082.5 8084.0 8090.0 8097.0 8110.0 8112.5 8116.5 8131.5 8133.5 8136.5 8141.5 8146.5 8152.0 8155.5 8157.0 8160.0 8165.5 8168.0 8205.5 8207.5 8216.0 8218.0 8229.0 8236.0 8243.0 8247.0 8249.5 8257.5 8260.5 8264.5 8268.5 8274.5 8277.5 8287.5 8295.5 8315.0 8326.0 8332.0 8339.0 8342.0 8344.0 8357.5 8359.5 8366.5 8370.0 8376.5 8387.0 8390.0 8421.0 8427.5 8433.0 8435.0 8438.5 8453.0 8459.5 8482.5 8494.0 8505.5 8514.5 8540.5 8080.5 8084.0 8086.0 8092.5 8098.5 8111.5 8114.0 8118.0 8133.0 8134.5 8137.5 8142.5 8148.0 8153.5 8156.0 8158.0 8161.0 8166.5 8169.0 8207.0 8208.5 8217.0 8218.5 8230.0 8237.0 8243.5 8248.0 8250.5 8258.5 8261.5 8266.5 8271.0 8279.0 8282.5 8294.0 8303.5 8319.0 8328.0 8333.5 8341.0 8344.0 8346.5 8359.0 8361.0 8367.5 8370.5 8379.0 8390.0 8392.5 8428.0 8434.0 8440.5 8442.0 8445.5 8464.5 8470.5 8495.5 8504.5 8516.0 8523.5 8549.0 8550.0 8557.5 8563.0 8568.0 8576.5 8579.5 8581.0 8590.5 8608.5 8625.0 8629.0 8632.0 8641.0 8644.5 8667.0 8680.0 8683.5 8686.5 8690.5 8699.0 8709.5 8726.5 8729.0 8742.5 8756.5 8760.5 8765.5 8778.5 8786.0 8809.0 8815.5 8820.0 8823.0 8829.5 8833.5 8847.0 8848.5 8851.0 8853.5 8860.5 8865.0 8872.5 8875.0 8877.0 8881.5 8885.0 8890.0 8900.5 8914.0 8917.5 8925.5 8927.0 8941.5 8944.0 8947.0 8953.5 8964.0 8967.0 8972.5 8976.0 8989.0 8558.0 8569.0 8574.5 8578.5 8588.0 8592.5 8593.5 8600.5 8620.5 8635.5 8639.0 8643.0 8652.0 8656.0 8676.0 8687.0 8689.5 8691.5 8694.5 8702.0 8711.5 8726.5 8729.5 8743.0 8757.0 8761.0 8766.0 8778.5 8785.0 8810.5 8816.5 8819.5 8823.0 8828.0 8831.0 8845.5 8847.5 8850.0 8853.0 8860.0 8864.0 8872.0 8875.0 8877.5 8882.0 8885.5 8890.5 8899.0 8914.5 8919.5 8928.0 8929.5 8942.5 8944.5 8946.5 8952.5 8961.5 8964.0 8970.0 8975.0 8987.0 • C~ 8990.5 9012.0 9025.5 9068.0 9075.0 9079.0 9086.0 9089.5 9137.5 9144.0 9156.5 9160.0 9169.0 9170.5 9176.0 9178.0 9184.5 9188.0 9192.0 9197.5 9201.0 9205.0 9213.5 9217.0 9220.5 9226.5 9233.0 9236.5 9241.0 9242.5 9245.0 9251.0 9252.5 9254.0 9259.5 9261.5 9263.0 9275.5 9279.5 9282.0 9285.5 9290.5 9296.5 9302.0 9309.0 9312. 0 9315.0 9317.5 9322.0 9325.0 9331.5 9339.0 9345.5 9351.0 9358.5 9362.5 9365.0 9380.5 9384.0 9386.5 9388.5 8988.5 9010.5 9023.5 9067.5 9076.5 9080.5 9087.0 9090.0 9136.0 9142.5 9155.5 9159.5 9169.0 9170.0 9175.5 9177.5 9184.0 9187.5 9191.0 9196.0 9200.0 9204.5 9212.5 9215.5 9219.0 9225.0 9231.5 9234.5 9240.0 9241.5 9243.5 9250.0 9251.0 9253.0 9258.0 9259.5 9261.0 9275.0 9278.5 9280.5 9284.0 9289.0 9296.0 9300.5 9306.0 9309.5 9314.0 9316.5 9321.0 9324.0 9330.5 9339.0 9345.5 9351.0 9357.5 9361.5 9364.0 9379.5 9383.5 9386.0 9388.0 • • 9392.5 9391.5 9397.0 9397.0 9399.0 9400.5 9404.0 9404.0 9410.5 9416.5 9411.0 9417.0 9724.0 9730.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3893.0 9730.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3888 9724 6806 11673 3888 9724 ROP MWD FT/H 0 780.26 129.794 11597 3926 9724 GR MWD API 16.31 242.91 83.3011 11594 3888 9684.5 First Reading For Entire File..........3888 Last Reading For Entire File...........9724 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header • ~ Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/11 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3893.0 9690.5 ROP 3932.0 9730.0 LOG HEADER DATA DATE LOGGED: 18-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 -DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9730.0 TOP LOG INTERVAL (FT) 3893.0 BOTTOM LOG INTERVAL (FT) 9730.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 51.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3931.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S) 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1900 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 136.0 MUD FILTRATE AT MT: .000 .0 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 .............. ......-999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3893 9730 6811.5 11675 3893 9730 ROP MWD020 FT/H 0 780.26 129.763 11597 3932 9730 GR MWD020 API 16.31 242.91 83.3431 11596 3893 9690.5 First Reading For Entire File..........3893 Last Reading For Entire File...........9730 File Trailer Service name....... ....STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/11 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/11 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer • Service name .............LISTPE Date .....................06/07/11 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File ~o~ - o5a ~~39g~ • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jul 06 15:54:50 2006 Reel Header Service name .......... ...LISTPE Date .................. ...06/07/06 Origin ................ ...STS Reel Name ............. ...UNKNOWN Continuation Number... ...01 Previous Reel Name.... ...UNKNOWN Comments .............. ...STS LIS Writing Library Tape Header Service name .......... ...LISTPE Date .................. ...06/07/06 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 MWD RUN 2 JOB NUMBER: MW-000431545 LOGGING ENGINEER: B. TRANI OPERATOR WITNESS: C. NOAKES SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services AGI-07A 500292234301 BP Exploration Inc. (Alaska) Sperry Sun 06-JUL-06 MWD RUN 3 MWD RUN 4 MW-000431545 MW-000431545 B. TRANI E. QUAM C. NOAKES B. LASLEY 36 12N 14E 2290 2515 .00 47.00 33.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3931.0 2ND STRING 12.250 13.375 3931.0 3RD STRING 5.500 9.625 9958.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED • • TO A 1.1 FT WINDOW, AND BAT DATA - SMOOTHED TO A 1.5 FT WINDOW. 3. MWD RUNS 1-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR ) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 1 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. MWD RUN 4 IS DIRECTIONAL WITH DGR, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND BOTH BIMODAL ACOUSTIC TOOL (BAT) AND CROSS-DIPOLE BAT (MADBAT). OWING TO PRESSURE DAMAGE TO BAT TRANSCEIVERS, MADBAT DATA IS PRESENTED TO 10395'MD/ 8388'TVD. CONVENTIONAL BAT DATA ARE PRESENTED BELOW THIS DEPTH. 5. THIS WELL KICKS OFF FROM AGI-07A PB1 AT 9417'MD/7632'TVD. 6. LOG AND DIGITAL DATA (MERGED CURVES) ARE SHIFTED TO THE PDC-GR LOG OF 05/28/06 (USI-GR) LOG AND DIGITAL DATA HEADERS/RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT WELL AGI-07A WITH API #: 50-029-22343-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10525'MD, 8494'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, VARIABLE HOLE CTFA = SMOOTHED AVERAGE OF FAR NEUTRON DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR NEUTRON DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION {LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DTCP = SMOOTHED COMPRESSIONAL WAVE INTERVAL TRANSIT TIME. DTSP = SMOOTHED SHEAR WAVE INTERVAL TRANSIT TIME. VP/VS = RATIO OF COMPRESSIONAL TO SHEAR WAVE VELOCITY. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: VARIABLE (ACAL), BIT SIZE 8.5" MUD WEIGHT: 8.4-8.9 PPG MUD SALINITY: 10,000 PPM CHLORIDES FORMATION WATER SALINITY: 20,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD • Depth shifted and clipped curves; all bit runs merged DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3883.5 10488.5 ROP 3883.5 10524.5 DTC 9831.5 10445.5 SCRA 9947.5 10445.5 DTSH 9947.5 10445.5 DRHO 9948.0 10456.0 NCNT 9948.0 10442.5 NPHI 9948.0 10442.5 RHOB 9948.0 10456.0 FONT 9948.0 10442.5 PEF 9948.0 10456.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3883.5 3890.0 3932.0 3938.5 3934.0 3940.5 3938.0 3944.5 3945.0 3951.5 3949.5 3956.5 3960.0 3968.5 3974.0 3982.0 3982.0 3990.0 3990.5 3998.5 4005.5 4013.5 4031.0 4039.0 4032.5 4040.5 4034.5 4042.5 4036.5 4044.5 4039.0 4047.0 4040.5 4048.5 4042.0 4050.0 4044.0 4052.5 4047.5 4056.5 4050.0 4058.5 4065.5 4072.5 4067.0 4074.5 4075.5 4083.0 4082.5 4090.0 4093.5 4103.0 4119.0 4127.0 4128.0 4136.0 4147.0 4153.5 4149.5 4157.0 4153.5 4161.5 4172.0 4182.5 4242.0 4248.0 4244.0 4250.5 4260.5 4266.0 4264.5 4270.5 4268.0 4274.5 4270.0 4276.5 4279.0 4283.5 4282.0 4287.0 4296.0 4299.5 4298.5 4302.0 4302.5 4306.5 4337.0 4341.0 4350.5 4354.5 4354.5 4358.5 4356.5 4360.5 4375.5 4379.5 4377.0 4381.0 4386.0 4390.0 4387.5 4391.5 4394.0 4398.0 4396.5 4400.5 4398.0 4402.5 • 4406.5 4410.5 4417.0 4420.0 4422.5 4427.0 4425.0 4430.0 4427.0 4432.5 4429.0 4434.0 4430.5 4435.5 4434.5 4440.5 4436.0 4442.0 4440.0 4446.0 4442.0 4448.0 4450.0 4456.0 4454.0 4460.0 4458.0 4464.5 4498.5 4504.0 4506.0 4510.5 4509.0 4515.0 4513.0 4519.0 4517.0 4523.0 4526.0 4532.0 4530.0 4536.0 4532.5 4540.0 4544.5 4551.5 4547.0 4554.0 4551.0 4558.0 4552.5 4559.5 4566.0 4572.5 4568.0 4575.5 4570.0 4577.5 4574.5 4582.0 4579.0 4586.5 4599.0 4603.5 4603.5 4608.0 4607.0 4611.5 4610.5 4615.0 4619.5 4624.0 4621.0 4625.5 4622.5 4627.0 4627.0 4631.5 4649.5 4654.0 4659.0 4660.5 4665.0 4664.5 4668.0 4667.5 4677.0 4677.0 4679.5 4679.5 4684.0 4684.0 4692.5 4692.5 4698.5 4699.0 4702.0 4702.5 4707.0 4707.5 4727.0 4729.0 4746.0 4752.0 4752.0 4757.0 4759.5 4764.5 4769.0 4774.0 4776.0 4779.5 4783.5 4789.5 4788.0 4794.5 4799.5 4804.5 4829.5 4836.0 4840.0 4845.0 4863.5 4869.0 4865.5 4871.0 4873.0 4879.0 4876.5 4882.0 4878.5 4884.0 4882.5 4888.0 4902.5 4907.5 4918.5 4925.5 4927.0 4933.5 4934.5 4939.5 4938.5 4943.0 4964.0 4971.0 4973.0 4980.0 4976.0 4983.0 4978.5 4987.0 • • 4984.0 4992.5 4988.5 4996.0 4996.5 5004.0 4998.5 5006.5 5004.5 5013.0 5006.5 5014.5 5009.0 5016.5 5013.5 5022.0 5016.0 5024.5 5202.0 5207.0 5205.0 5210.0 5210.0 5215.0 5215.0 5220.0 5223.5 5227.5 5252.5 5257.5 5261.0 5266.5 5277.5 5283.0 5280.0 5285.5 5286.5 5292.0 5289.5 5295.5 5298.5 5304.5 5306.0 5312.0 5313.0 5321.0 5316.5 5323.5 5321.0 5327.0 5357.5 5364.5 5364.0 5370.0 5366.5 5372.5 5372.0 5378.0 5375.5 5381.5 5395.0 5403.0 5420.5 5430.0 5425.5 5434.5 5442.0 5450.5 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9496.0 9517.0 9520.0 9520.0 9521.5 9524.0 9525.5 9527.0 9527.5 9534.0 9534.0 • • 9537.0 9537.0 9544.5 9545.5 9560.5 9560.5 9574.0 9572.5 9578.0 9576.5 9585.0 9586.0 9597.5 9598.0 9605.5 9605.5 9611.0 9611.0 9623.0 9625.5 9626.0 9628.5 9628.5 9631.0 9630.5 9633.0 9640.0 9643.0 9641.5 9644.0 9650.0 9651.0 9652.5 9653.5 9660.5 9661.0 9662.5 9662.5 9665.5 9665.0 9687.5 9687.0 9691.5 9690.5 9705.5 9705.5 9707.5 9708.0 9710.5 9711.5 9712.5 9713.5 9717.5 9718.0 9719.0 9720.0 9723.5 9724.0 9725.5 9726.5 9727.5 9728.5 9732.0 9731.5 9745.5 9744.5 9750.5 9751.5 9756.5 9756.5 9760.0 9760.0 9763.0 9763.0 10524.5 10524.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3890 .0 9417.0 MWD 3 9417 .5 9960.0 MWD 4 9831 .5 10524.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 NPHI MWD PU-S 4 1 68 12 4 FONT MWD CNTS 4 1 68 16 5 NCNT MWD CNTS 4 1 68 20 6 RHOB MWD G/CM 4 1 68 24 7 DRHO MWD G/CM 4 1 68 28 8 PEF MWD BARN 4 1 68 32 9 DTC MWD US/F 4 1 68 36 10 DTSH MWD US/F 4 1 68 40 11 SCRA MWD 4 1 68 44 12 • • First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3883.5 10524.5 7204 13283 3883.5 10524.5 ROP MWD FT/H 0.13 780.26 123.87 13283 3883.5 10524.5 GR MWD API 14.04 397.16 84.4067 13211 3883.5 10488.5 NPHI MWD PU-S 9.44 57.54 21.2113 990 9948 10442.5 FONT MWD CNTS 496.41 3568.57 1754.53 990 9948 10442.5 NCNT MWD CNTS 104432 180680 148398 990 9948 10442.5 RHOB MWD G/CM 0.894 2.907 2.3281 1017 9948 10456 DRHO MWD G/CM -2.329 0.363 0.0273707 1017 9948 10456 PEF MWD BARN 1.12 12.06 2.49016 1017 9948 10456 DTC MWD US/F 48 113 83.5557 1229 9831.5 10445.5 DTSH MWD US/F 96 183 152.909 997 9947.5 10445.5 SCRA MWD 1.32 2.92 1.68623 997 9947.5 10445.5 First Reading For Entire File..........3883.5 Last Reading For Entire File...........10524.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: ..5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 3890.0 9417.0 GR 3890.0 9417.0 LOG HEADER DATA DATE LOGGED: 18-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9417.0 TOP LOG INTERVAL (FT) 3890.0 BOTTOM LOG INTERVAL (FT) 9417.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 51.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3931.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1900 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 136.0 MUD FILTRATE AT MT: .000 .0 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 ......................-999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3890 9417 6653.5 11055 3890 9417 ROP MWD020 FT/H 0 780.26 133.151 11055 3890 9417 GR MWD020 API 16.31 242.91 79.5324 11055 3890 9417 First Reading For Entire File..........3890 Last Reading For Entire File...........9417 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 ~ • Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9417.5 9919.5 ROP 9417.5 9960.0 LOG HEADER DATA DATE LOGGED: 21-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9960.0 TOP LOG INTERVAL (FT) 9417.5 BOTTOM LOG INTERVAL (FT) 9960.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.2 MAXIMUM ANGLE: 43.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 999 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3931.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 10.40 MUD VISCOSITY (S) 55.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 1500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .0 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 ......................-999.25 Depth Units ....................... • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9417.5 9960 9688.75 1086 9417.5 9960 ROP MWD030 FT/H 0.88 259.58 88.9219 1086 9417.5 9960 GR MWD030 API 96.85 397.16 174.691 1005 9417.5 9919.5 First Reading For Entire File..........9417.5 Last Reading For Entire File...........9960 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .......... ...STSLIB.004 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/07/06 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DTC 9831.5 10445.5 GR 9924.5 10488.5 DTSH 9947.5 10445.5 SCRA 9947.5 10445.5 FCNT 9948.0 10442.5 PEF 9948.0 10456.0 DRHO 9948.0 10456.0 RHOB 9948.0 10456.0 NCNT 9948.0 10442.5 NPHI 9948.0 10442.5 ROP 9960.5 10524.5 LOG HEADER DATA DATE LOGGED: 26-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10524.5 TOP LOG INTERVAL (FT): 9960.5 BOTTOM LOG INTERVAL (FT) 10524.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 35.3 38.0 C TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 CTN COMP THERMAL NEUTRON 1844674407370955 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.500 9958.0 Fresh Water Gel 8.50 63.0 10.5 10000 .0 000 .0 000 .0 000 .0 000 .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 .................... ..-999.25 Depth Units ..................... .. Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 NPHI MWD040 PU-S 4 1 68 12 4 FONT MWD040 CNTS 4 1 68 16 5 NCNT MWD040 CNTS 4 1 68 20 6 RHOB MWD040 G/CM 4 1 68 24 7 DRHO MWD040 G/CM 4 1 68 28 8 PEF MWD040 BARN 4 1 68 32 9 DTC MWD040 US/F 4 1 68 36 10 DTSH MWD040 US/F 4 1 68 40 11 SCRA MWD040 4 1 68 44 12 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9831.5 10524.5 10178 1387 9831.5 10524.5 ROP MWD040 FT/H 0.53 186.42 66.7862 1129 9960.5 10524.5 GR MWD040 API 14.04 254.68 49.8547 1129 9924.5 10488.5 NPHI MWD040 PU-S 9.44 57.54 21.2113 990 9948 10442.5 FONT MWD040 CNTS 496.41 3568.57 1754.53 990 9948 10442.5 NCNT MWD040 CNTS 104432 180680 148398 990 9948 10442.5 RHOB MWD040 G/CM 0.894 2.907 2.3281 1017 9948 10456 DRHO MWD040 G/CM -2.329 0.363 0.0273707 1017 9948 104.56 PEF MWD040 BARN 1.12 12.06 2.49016 1017 9948 10456 • • DTC MWD040 US/F 48 113 83.5557 1229 9831.5 10445.5 DTSH MWD040 US/F 96 183 152.909 997 9947.5 10445.5 SCRA MWD040 1.32 2.92 1.68623 997 9947.5 10445.5 First Reading For Entire File..........9831.5 Last Reading For Entire File...........10524.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/06 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/07/06 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File