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Home My WebLink About202-109Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 T40714PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522 PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-108 PRUDHOE BAY UN BORE L-108 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 L-108 50-029-23090-00-00 202-109-0 W SPT 6359 2021090 1590 1225 1223 1223 1223 330 336 336 336 4YRTST P Adam Earl 8/9/2024 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 UN BORE L-108 Inspection Date: Tubing OA Packer Depth 97 1926 1882 1873IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812125353 BBL Pumped:0.6 BBL Returned:0.8 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 999 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 14:46:43 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Change of well name___ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Nikaitchuq Schrader bluff 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18053'1413 N/A N/A Casing Collapse Structural Conductor N/A Surface 3,430 Intermediate 7,630 Production Liner Slotted Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Stefano Pierfelici 10/13/2022 Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): 10475' 10141'-18025' 5.5 4140'-4114' 10,141-10,025'7884' 4.5" 4,140'-4,114' 24 13.375 122.5 9.62510442' 2529' MD 8,150 N/A 5,380 160' 2394' 4170' 160' 2564' Length Size Proposed Pools: TVD Burst Schrader bluff 4115'18025'4114' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0391283, 0388583, 0388581 222-109 3700 Centerpoint Dr. Anchorage, AK, 99503 50-629-23721-60-00 Eni US Operating Co. Inc. SI41-E3 L1 (SP41-E3 L1) Slotted liner Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft):Tubing Size: L-80 9,990' October 13th, 2022 N/A 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 Well Operations Project Manager m n P s 66 t _ Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 11:24 am, Dec 06, 2022 322-689 DLB 12/06/2022 None BJM 12/7/22 DSR-12/6/22 X GCW 12/08/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.08 11:10:46 -09'00' RBDMS JSB 120922 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 Email: Stefano.pierfelici@eni.com October 13, 2022 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for Change of Name in Approved PTD from Injector SI41-E3 L1 to Producer SP41-E3 L1. Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Change in Approved well name Sundry for well SI41-E3. The SI41-E3 L1 well spudded on Spy Island on August 25th, 2022 and is currently is on production. However, For Better reservoir management Eni had decided to convert this well into a dual lateral producer instead of an injector, which was planned and permitted. For this purpose it is necessary to change the name in approved permit to drill and in AOGCC well data. The new name of the well will be SP41-E3 L1.Eni had applied and got approval for change in well name for main bore SI41-E3 to SP41-E3 under approved Sundry 322-584. The estimated date for beginning this work is October 13th, 2022. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907- 865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager SSI41-E3 L1 (SP41-E3 L1) Sundry – Summary Page PTD#:222-109 Current Status Well, SI43-E3 L1 is currently on Production. Scope of Work Scope of this Sundry is to Change of Name from SI41-E3 L1 to SP41-E3 L1, change in well name was submitted for the main bore SI41-E3 to SP41-E3 and it has been approved under Sundry number 322-584 dated 10/12/2022. General Well info Reservoir Pressure/TVD: This well is expected to have a static max bottom hole pressure of approximately 2032 psi (4,157’ ssTVD). Wellhead type/pressure rating: Vault PC, MB-247/5000 psi BOP configuration: Annular/VBR/shear rams/VBR TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8” was tested to 3000 psi prior to drill out on August 13th, 2022. Well type: Producer Estimated start date: October 13th, 2022 Drilling rig: Doyon Rig 15 Senior Drilling Engineer Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations project Manager Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 PProcedure: 1. N/A Below the proposed schematic of the well: Propsed name of the well Since SP41-E3 L1 is the lateral from the mainbore SP41-E3 so in the completion schematic name is just for mainbore MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, August 31, 2020 P.I. Supervisor 11,4e'Wit/azc' SUBJECT: Mechanical Integrity Tests rBP Exploration (Alaska) Inc. L-108 FROM: Jeff Jones PRUDHOE BAY UN BORE L-108 Petroleum Inspector Src: Inspector Reviewed By: P. 1. Supry 1 Z— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-108 API Well Number 50-029-23090-00-00 Inspector Name- JeffJones Permit Number: 202-109-0 Inspection Date: 8/15/2020 Insp Num: mitJJ200828142659 Rel Insp Num: Packer Depth Well L-108 Type Inj w "TVD 4209 PTD -- 2021090 Type Test SPT 'Test psi' 1500 BBL Pumped: I iBBL Returned: I Interval 4YRTST !P/F P Notes' I well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing1520 1520526 1527 IA 60 2197 - 2159 - I 2150 ' QA 360 - 369 C 370. 370 Monday, August 31, 2020 Page 1 of I 0 M MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 31,2016 TO: Jim Regg P.I.Supervisor 'Tell• gbil%(o SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC. L-108 FROM: Jeff Jones PRUDHOE BAY UN BORE L-108 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry )j.e NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-108 API Well Number 50-029-23090-00-00 Inspector Name: Jeff Jones Permit Number: 202-109-0 Inspection Date: 8/27/2016 Insp Num: mitJJ160827150515 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-108 • Type Inj TVD 4209 - Tubing 1110 . 1114 1113. 1108 PTD 1 2021090 ' Type Test SPT Test psi 1500 - IA 202 2299 • ' 2266 _ 2259 _ I Interval 4YRTST P/F P ✓ OA 163 171 - 172- 172 Notes: 1 BBL diesel pumped. 1 well inspected,no exceptions noted. . SCANNED JUN 2 3 2017, Wednesday,August 31,2016 Page 1 of 1 ECEIVED STATE OF ALASKA AlIA OIL AND GAS CONSERVATION COMMION NOV 0 1 2012 REPORT OF SUNDRY WELL OPERATIONS �� 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Bfightwater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extensio❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended We❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ ' * 202 -109 -0 3. Address: P.O. Box 196612 Stratigraphi4 Service El 6. API Number: Anchorage, AK 99519 - 6612 " 50- 029 - 23090 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028241 BRLS L -108 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, BOREALIS OIL 11. Present Well Condition Summary: Total Depth measured 8294 feet Plugs measured None feet true vertical 7039.23 feet Junk measured None feet Effective Depth measured 8194 feet Packer measured See Attachment feet true vertical 6954.3 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 29 - 109 29 - 109 1490 470 Surface 2691 9 -5/8" 40# L -80 29 - 2720 29 - 2621.06 5750 3090 Intermediate None None None None None None Production 8254 7" 26# L -80 25 - 8279 25 - 7026.49 7240 5410 Liner None None None None None None Perforation depth Measured depth 4958 - 5006 feet 5042 - 5080 feet 5096 - 5116 feet 5167 - 5184 feet 5235 - 5276 feet 7686 - 7750 feet 7760 - 7766 feet 7774 - 7781 feet 7785 - 7791 feet True Vertical depth 4350.11 - 4386.41 feet 4413.63 - 4442.47 feet 4454.68 - 4470.02 feet 4509.39 - 4522.55 feet 4562.1 - 4594.12 feet 6518.99 - 6574.5 feet 6583.14 - 6588.33 feet 6595.24 - 64,01 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 Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: SCANNED JAN 2.03 Intervals treated (measured): 7686' - 7750', 7760' - 7766', 7774' - 7781', 7785' - 7791' Treatment descriptions including volumes used and final pressure: 3491 Gallons ECj9350A Surfactant, 15098 Gallons EC9398A Polymer 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 4386 0 1429 Subsequent to operation: 0 0 4002 0 1531 14. Attachments: 15. Well Class after work: - Copies of Logs and Surveys Run Exploratorl❑ Development ❑ ServicJ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: o Oil 111 Gas ❑ WDSPt❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Gar .Catron .b BP.Com Printed Name Garry Catron Title PDC PE Signature 4 ,i pti(if/I , Phone 564 -4424 Date 11/1/2012 1/L T if02...._ ►RRr., S NOV 0 <? 2012 ` 1 g /4 ii Form 10 -404 Revised 10/2012 Submit Original Only . • • Packers and SSV's Attachment ADL0028241 SW Name Type MD TVD Depscription L -108 PACKER 4762 4125.24 3 -1/2" Merla Patch Packer 1 L -108 PACKER 4769 4130.43 4 -1/2" Baker Premier Packer L -108 PACKER 4788 4144.53 3 -1/2" Merla Patch Packer L -108 PACKER 7502 6280.32 4 -1/2" Baker S -3 Packer Casing / Tubing Attachment ADL0028241 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 29 - 109 29 - 109 1490 470 PRODUCTION 8254 7" 26# L -80 25 - 8279 25 - 7026.49 7240 5410 SURFACE 2691 9 -5/8" 40# L -80 29 - 2720 29 - 2621.06 5750 3090 TUBING 4753 4 -1/2" 12.6# L -80 23 - 4776 23 - 4214.02 8430 7500 PATCH 26 3 -1/2" 9.3# L -80 4762 - 4788 4203.64 - 4222.93 10160 10530 TUBING 2784 3 -1/2" 9.3# L -80 4776 - 7560 4214.02 - 6409.21 10160 10530 • • Daily Report of Well Operations ADL0028241 ACTMTYDATE 1 SUMMARY • = 1 1 1 emp =' o :rig a er - eservoir weep Y o. Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 106 gal. EC9360A (Surfactant) Average of 35.3 gph for 3 hrs. Pumped a total of 106 gal. since start of project. Pumped 393 gal. EC9398A ( Polymer) Average of 131 gph for 3 hrs. Pumped a total of 393 gal. since start of project. 10/3/2012 ** *Continued on WSR 10- 04- 2012*** T /I /O = 1436/1000/320 ** *Continued WSR from 10 -03- 2012 * ** Temp =Hot ( Brightwater • Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 653 gal. EC9360A (Surfactant) Average of 27.2 gph for 24 hrs. Pumped a total of 759 gal. since start of project. Pumped 3501 gal. EC9398A ( Polymer) Average of 145.8 gph for 24 hrs. Pumped a total of 3894 gal. since start of project. 10/4/2012 ** *Continued on WSR 10 -05- 2012 * ** T /I /O = 1446/980/320 ** *Continued WSR from 10 -04- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 730 gal. EC9360A (Surfactant) Average of 30.4 gph for 24 hrs. Pumped a total of 1489 gal. since start of project. Pumped 3243 gal. EC9398A ( Polymer) Average of 135.1 gph for 24 hrs. Pumped a • total of 7137 gal. since start of project. 10/5/2012 ** *Continued on WSR 10- 06- 2012 * ** T /I /O = 1451/1000/320 ** *Continued WSR from 10 -05- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 767 gal. EC9360A (Surfactant) Average of 31.9 gph for 24 hrs. Pumped a total of 2256 gal. since start of project. Pumped 3017 gal. EC9398A ( Polymer) Average of 125.7 gph for 24 hrs. Pumped a total of 10154 gal. since start of project. 10/6/2012 ** *Continued on WSR 10 -07- 2012 * ** Daily Report of Well Operations ADL0028241 T /I /O = 1452/1020/320 ***Continued WSR from 10- 06- 2012*** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 801 gal. EC9360A (Surfactant) Average of 33.3 gph for 24 hrs. Pumped a total of 3057 gal. since start of project. Pumped 3403 gal. EC9398A ( Polymer) Average of 141.7 gph for 24 hrs. Pumped a total of 13557 gal. since start of project. 10/7/2012 ** *Continued on WSR 10 -08- 2012 * ** T71 /0 = 1463/780/300 ** *Continued WSR from 10 -07- 2012 * ** Temp =Hot (Brightwater • Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4400 bwpd. Pumped 434 gal. EC9360A (Surfactant) Average of 36.1 gph for 24 hrs. Pumped a total of 3491 gal. since start of project. Pumped 1541 gal. EC9398A ( Polymer) Average of 128.4 gph for 24 hrs. Pumped a total of 15098 gal. since start of project. Job Complete, Rig down in Progress 10/8/2012 ** *Continued on WSR 10 -09- 2012 * ** T /I /O = 1450/780/300 Rig down and move out 10/9/2012 FWHP = 1450/780/300 SW= CLOSED MV,SSV,WV =OPEN IA,OA =OTG ill TRH= 4- 1/16" CNV WELLHEAD= FMC SATES: H2S READINGS AVERAGE 125 ppm NA - 1 0 8 WHEN ON MI ""' WELL REQUIRES A SSSV WHEN ON Ml ACTUATOR = ... KB. B.EV = 78.4' BF. B.EV = NA KOP= 300' I 1018' H 9 - 5/8" TAM PORT COLLAR MEt Angle = 43° @ 4672' Datum MD = 7871' Datum TVD = 6600' SS I I 2237' H 4 -1/2" HES X Nom, D = 3.813" I GAS LFT I 9 -5/8" CSG, 40#, L -80, D = 8.835" H 2720' I MANDRELS ST AC Ti/D DEV TYPE LATCH FORT DATE 5 3818 3500 38 KBG-2 DMY BK -5 0 01/04/03 4 4199 3800 39 KBG-2 DMY BK -5 0 07/02/02 3 4693 4250 43 KBG-2 DMY BK -5 0 01/04/03 WATERFLOOD MANDRELS Minimum ID = 2.75" 7548' ST MD 1VD DEV TYFE VLV LATCH FORT DATE 2 4867 ' 4281 41 MMG-W OMY REP 0 07/02/02 3 -112" HES XN NIPPLE 1 4926 4334 40 MMG-W DMY RKP 0 07/02102 ' I 4758' H 4-1/2" HES X NP, D= 3.813" I ='■ 4762' - 4788' H 4 -1/2" MERLA PERM TBG PATCH, D = 3.235" I ►_ 4769' I- 7' X 4-1/2' BKR PREMIER PKR, 0 = 1870' 5 5 I 4-1/2" TBG, 12.6#, L -80, .0152 bpf, D= 3.958" H 4825' I I 4825' H 4 -1/2" X 3 -1/2' XO, D= 2.992" sr I 7489' —{ 3 -1/2" HES X NP, ID= 2.813" I 7500' H 3 -1 /2' X 4-1/2" XO, D= 2.940" 7502• H 7" X 4 -112" BKR S-3 PKR, D = 3.875" I 7505' IH 4 - 1/2" X 3 - 1/2" XO, D = 2.920' 7527' H 3 -1/2" HES X NP, D= 2.813' I 7548' I l 3-1/2- HES XN NP, D = 2.75" I 3-1/2" TBG, 9.2#, L -80, .0087 bpi, ID = 2.992" — 7558' I 7560' H 3 - 1/2" WLEG, D = 2.905' FERFORATION SUMMARY REF LOG: TCP FERF ANGLE AT TOP PERF: 40° @ 4958' g♦ I 7624• H RA TAG Note: Refer to Roduction DB for historical perf data SIZE SPF NTBR1/AL Opn /Sqz DATE 4-5/8" P 5 • 4958 - 5006 0 07/02/02 • I 8051 • H RA TAG I 4 ' 5 5042 - 5080 0 07/02/02 4-5/8" r 5 5096 - 5116 0 07/02/02 4-5/8" ' 5 5167 - 5184 0 07/02/02 4-5/8" ' 5 5235 - 5276 0 07/02/02 2 -1/4' ' 6 7686 - 7750 0 12/14 /02 2 -1/4" ' 6 7760 - 7766 0 12/14 /02 2 -1/4' ' 6 7774 - 7781 0 12/14/02 2 -1/4" ' 6 7785 - 7791 0 12/14 /02 I PBTD IH 8194' ••••••••■• 17" CSG, 26#, L -80, D= 6.276" — 8279' 1 '' , ''''''' ) DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 08/31/01 INITIAL COMPLETION WELL: L - 108 07/10/02 TA/Ith INITIAL COMPLETION UPDATE PERMIT No: t021090 01/04/03 .MA /KAK GLV C/O API No: 50-029-23090-00 04/08/03 DRS/7P TVD/MD CORRECTIONS SEC 34, T12N. R11E, 2412' NSL & 3588' WEL 02/15/11 MB /,MAD SSSV SAFETY NOTE 01/17/12 TMN /.MAD H2S SAFETY NOTE BP Exploration (Alaska) ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~;~*;~~4,~LGC~t~ i~`tl,;~ .3L ~ C.~~{; August 14, 2009 ~ bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, ocT ~ ~ zoo~ ~I~ask~ ~lil ~ Gas Cons. Conxni~sion Anchorage a~~-~~9 ~, ~a~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploretion (Alaska ) Inc. ~ Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~04) ~IaIP_ L pad 8H 3/2609 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 1-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 201t510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 5~29232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27l2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6127i2009 MEMORANDUM To: JimRegg ~,~ fl ~l~~Ze~~ P.I. Supervisor ~ `r`~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Wednesday, Octoher 29, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-108 PRUDHOE BAY UN BORE L-108 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~-- Comm. Well Name• 1'RUDHOE BAY UN BORE L-108 API Well Number 50-029-23090-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ081028173424 Permit Number: 202-109-0 '` Inspection Date: t0/24/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ------ - Well j L-108 Tape Inj. ~ W ~ TVD _ ~__ - - ~-- - - 4209 ~ IA I ~ 720 4010 I 4000 ~ 3990 - p T ~ zo21o9o TypeTest ~ sPT ?Test psi ~ aooo pA --- - -I aso I a6o - ---- 460 ~ aw -- - --- IntervaI 4YRTST p~F P ,/ Tubing ~ - - ---- ]soo ~ ]~so - - _ I ]~so ]~so - __~-_ _ Notes' 2 BBLS methanol pumped. Wednesday, October 29, 2008 Page 1 of 1 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker.doc ) MEMORANDUM State of Alaska Alaska on and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K 't1'~'l'ß1 04' DATE: Wednesday, October 27, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-108 PRUDHOE BAY UN BORE L-1 08 ~Od--I07 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~K- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE L-108 API Well Number: 50-029-23090-00-00 Insp Num: mitCS041 022171933 Permit Number: 202-109-0 ReI Insp Num: Inspector Name: Chuck Scheve Inspection Date: 10/22/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-108 Type Inj. P TVD 4208 IA 425 4000 3960 3960 P.T. 2021090 TypeTest SPT Test psi 1052 OA 560 640 640 640 Interval OTHER P/F P Tubing 1700 1700 1700 1700 Notes: Test performed prior to placing well on MI. SCANNED NO\] 0 9 2.004 Wednesday, October 27, 2004 Page 1 of 1 ~ ~ ~ M.N' '-\ "d DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021090 MD 8294 ./ REQUIRED INFORMATION Samples No ----- ------------- --------- Well Name/No. PRUDHOE BAY UN BORE L-108 Current Status WAGIN fpu--cL /6 J 1/1/1 ~:t API No. 50-029-23090-00-00 ~J. /' Operator BP EXPLORATION (ALASKA) INC TVD 7039 Completion Date 7/4/2002 -- Completion Status WAGIN Mud Log Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, PWD, RES/AIT, DT/BHC, CNL, LDL, GR, Caliper, S Well Log Information: Log/ Data Digital Type Med/Frmt ~c-~- I I L/'+. Log 6 Log ~. ~ 469 I dJ..og/ ¡ iJ&g i I Rpt i~ I !~ ~ ~ ~C ! I i ~oQ ! ~D (/'j" Log {~ Log L_- ---------- Electr Dataset Number Name ~f1'IrnàRay L!J060See Notés Log Log Run Scale Media No 25 Blu 1 1-4 Blu Blu 5 Slu 2 Blu 5 Blu 5 Col 5 Col [ Gra. diO. m......e. .. t..e........f..... - Spinner ~adiometèr L:fêmperatÜre DirectiohafSûrvéy 5 Blu ~Blu ~Blu 1 ~ I nduction/Resistivity ceressure [ßatffmåRay UJMí. See Notes 25 Blu 25 Blu Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 117 8300 117 8300 OHI CH Received Comments Open 8/20/2002 ~me data Open 8/20/2002 (QPenhold LDWG formatted edit of MWD Gamma Ray ~ 1...8730' 9108, cCase 8/9/2002 t&r30 91 08 ~ase 8/9/2002 ~ 8156 Case 12/20/2002 2720 8259 Open 8/16/2002 c..pfaff'orm Express HCAL tAßOO 8156 Case 12/20/2002 3005 8166 ---Case 7/26/2002 LA J I r 3005 8166 Case 7/26/2002 0 8294 Open 7/5/2002 L.4600 8156 Case 12/20/2002 2720 8259 Open 8/16/2002 Platform Express ~ @O ß.730 117 --2512 8292 Open 8/16/2002 Platform Express 9108 Case 8/9/2002 8300 Open 8/20/2002 ¿RealtTme data 8302 Open 8/16/2002 /Opel}!Jøle Platform LExpfess / AIT / BHC Gamma Ray 8292 Open 8/16/2002 ¿e.latform Express Quad Combo ~ ~alSllrvey 0 8294 Open 7/5/2002 25 Blu (2720 8259 Open 8/16/2002 LPratform Express 25 Blu ~ 8259 Open 8/16/2002 ~orm Express DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021090 Well Name/No. PRUDHOE BAY UN BORE L-108 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23090-00-00 MD 8294 , jiog- v ~ Log r 1>09 l/{~09 ~J&19 ¡ ! Log I ~ l-et5. C I ~ I I 14:69 I~/- TVD 7039 Completion Date C Ca~ingC.On.arlocator l-splnner X~Leak ~ Tempèratllre ~ssure GammaR¡:¡y See Notes ~ ~c GarnmaRaY ~Notes -------._"---- Well Cores/Samples Information: Name Well Cored? ADDITIONAL INFORMATION y~ Chips Received? Y / N Analysis Received? ~- ------ Comments: -Y-tN Compliance Reviewed By: )~ 7/4/2002 Completion Status 5 Blu 5 Blu e Blu 1 Blu ~Iu 5 Col 25 Blu 1-4 25 Blu 5 Blu 5 Blu Interval Start Stop Sent WAGIN Current Status WAGIN ~OO 8156 ~ase 12/20/2002 600 8156 ase 12/20/2002 C:730 9108 Case 8/9/2002 730 9108 Case 8/9/2002 ~/) ~156 eâSe 12/20/2002 3005 8166 Case 7/26/2002 ---- 2720 8292 Open 8/16/2002 L?tãffórm Express Subsea 8300 Open 8/20/2002 ~d LDWG formatted edit of MWD Gamma Ray 2720 8276 Open 8/16/2002 Borehole Compensated Sonid 117 ~8156 .ease 12/20/2002 150 8132 Case 12/20/2002 ~ Log Received Sample Set Number Comments <:Y)/N (j)N Formation Tops Daily History Received? _/ Date: 1 ~J :2fìYV( ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRQi~::~ 20 AAC 25.280 Conductor 78 Production 8254 Surface 2691 Perforation Depth MD (ft): 7686 - 7750 7760 - 7766 7774 - 7781 7785 - 7791 Packers and SSSV Type: 3-1/2" Merla Patch Packer 3-1/2" Merla Patch Packer 4-1/2" Baker Premier Packer 4-1/2" Baker 8-3 Perm Packer 12. Attachments: Description Summary of Proposal 0 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6518.99 6574.5 6583.14 6588.3 6595.24 6601.3 6604.73 6609.9 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 78.40 KB 8. Property Designation: ADL-0028241 11. Total Depth MD (ft): 8294 Total Depth TVD (ft): 7039.2 Casing Length Detailed Operations Program 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: June 30, 2004 Development 0 Exploratory 0 Stratigraphic 0 Service ŒJ /' 9. Well Name and Number: L-108 ,,,/ 1 O. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8194 6875.9 MD TVD Suspend 0 Repair Well D Pull Tubing D Operation Shutdown 0 Plug Perforations 0 Perforate New Pool D 4. Current Well Class: Size top 30 25 29 bottom top 108 8279 2720 Tubing Size: 2.765 " 3.5 " 4.5 " \Ai L7Æ- (p /3 0 /zl;)04 /)~ 6/30/1- JUN 2 9 2004 perforateÇ" WaiverÐ Annular DisposalD Stimulater: aska Oit~JJ~~JhqmhËJJmnì¡ssimm Other]] Re-enter susp'M~aijBIW'.énD Convert to Mllnj 5. Permit to Drill Number: 202-1090 /' 6. API Number / 50-029-23090-00-00 Plugs (md): Junk (md): None None Burst Collapse 30.0 25.0 29.0 bottom 108.0 7026.5 2621.1 Tubing Grade: H-40 L-80 L-80 4788 7560 4827 1490 7240 5750 Tubing MD (ft): 4762 4827 4 - 235 - 470 5410 3090 9.3 # 12.6 # Packers and SSSV MD (ft): 4762 4788 4769 7502 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI // Date: 15. Well Status after proposed work: Oil D / GasD PluggedD AbandonedD WAG 181 / GINJ~ WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Bruce Smith (~ '>-tJ 4 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Form 10-403 Revised 06/2004 BOP TestD Mechanciallntegrity Test D Contact Bruce Smith Title Phone Petroleum Engineer 564-5093 6/29/04 Sundry Number: .3:;<1- if Ý ? Location Clearance D f:A-{ ý ý ~ f- {¡Uf / ( çJc~ ~ ~ i s \,oJ J\-4 IN ' BY ORDER OF THE COMMISSION Date: -- ~¡Ó1/' MlI06. OR\G\NAL RmMSBFl SUBMIT IN DUPLICATE ) TREE = 4-1/16" CIW WELLHEAD = FMC .............".,."'........................."'..., ACTUA. TOR = NA ."..m".........................."" ........ KB. ELEV ::: 78.4' ~B'F.'1i EV::: -.._. -"""'-""NA KOP';;---"""'-'''---- m 30õ' 'MaxAngie.; .......43 @ 46ii -bätümMD= ......mm. 78if 'ÖätlÚi1 i\tö ,;; .0000' SS L-1 08 = 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 2720' ~ Minimum ID = 2.75" @ 7548' 3-1/2" HES XN NIPPLE 4-1/2" TBG, 12,6#, L-80, .0152 bpf, ID = 3.958" H 4825' Z 8 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2,992" H 7558' PERFORA1l0N SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 40 @4958' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 5 4958 - 5006 0 07/02/02 4-5/8" 5 5042 - 5080 0 07/02/02 4-5/8" 5 5096 - 5116 0 07/02/02 4-5/8" 5 5167 - 5184 0 07/02/02 4-5/8" 5 5235 - 5276 0 07/02/02 2-1/4" 6 7686 - 7750 0 12/14/02 2-1/4" 6 7760 - 7766 0 12/14/02 2-1/4" 6 7774 - 7781 0 12/14/02 2-1/4" 6 7785 - 7791 0 12/14/02 ) SAFETY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" MMG- WS WATERFLOOD MANDRELS. =--1 1018' 1--1 9-5/8" TAM PORT COLLAR 1 1 2237 1-1 4-1/2" H:S X NIP, ID = 3.813" 1 I I 7489' 7500' 7502' 7505' 7527 7548' 7560' ~ GAS LIFT MANDRELS L ST MD TVD DEV TYPE VLV LATCH PORr DATE 5 3818 3500 38 KBG-2 DMY BK-5 0 01/04/03 4 4199 3800 39 KBG-2 DMY BK-5 0 07/02/02 3 4693 4250 43 KBG-2 DMY BK-5 0 01/04/03 WATERFLOOD MANDRELS ST MD TVD DEV TYPE VLV LATCH PORr DATE 2 4867 4281 41 MMG-W DMY RKP 0 07/02/02 1 4926 4334 40 MMG-W DMY RKP 0 07/02/02 I 4758' I" 4-1/2" HES X NIP, ID = 3.813" 1 8'-----j 4762' - 4788' 1-1 4-1/2" MffiLA PffiM TBG PA Ta;, ID = 3,235" 1 :8: I 4 769' ~I 7" X 4-1/2" BKR PREMIER PKR, ID = 3.870" I 8 1 4825' 1-1 4-1/2" X 3-1/2" XO, ID= 2.992" 1 c 1--1 3-1/2" HES X NIP, ID = 2.813" 1 I" 3-1/2" X 4-1/2" XO, ID= 2.940" 1 H 7" X 4-1/2" BKR 8-3 A<R, ID = 3.875" I I" 4-1/2" X 3-1/2" XO, ID = 2.920" 1 1-1 3-1/2" HES X NIP, ID = 2.813" 1 1--1 3-1/2" HES XN NIP, ID = 2.75" 1 1-1 3-1/2" WLEG, ID = 2.905" 1 7624' 1--1 RA TAG 1 8051' 1-1 RA TAG 1 1 PBTD H 8194' ~ 1 ì' CSG, 26#, L-80, ID = 6.276" H 8279' DATE REV BY COM\llENTS DA. TE RBI BY COM\llENTS BOREALS LJ..JIT 08/31/01 ORIGINAL COI'vPLErION 121Ü71Ü2 JBMlKK SET MffiLA ÆRM TBG PATCH WELL: L-108 OS/20/02 JDF ffiOPOSED COMPLETON 12/141Ü2 CAO/KK A (PERFS PERMIT No: 2021090 07/02/02 WRD INITIAL COI'vPLErION 12/161Ü2 rv'H/KK GLV DA. TECORREC1l0N API No: 50-029-23090-00 07/10/02 T AItlh INITIAL COI'vPLErION LPDA. TE 011Ü41Ü3 JMKAK GLV GO sæ 34, T12N, R11 E, 2412' NSL & 3588' WEL 07/31/02 JB/KAK GL V C/O 041Ü81Ü3 DRS/lP TV D'rvD CORRECTIONS 08/06/02 RUtlh GL V UFÐA TE BP Exploration (Alaska) I 8 " ---1 ~ ,¡I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: CONVERSION to H2O INJECT 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X Plugging - Perforate - Repair well - Other _X CONVERSION H2O 6. Datum elevation (DF or KB feet) RKB 78 feet 7. Unit or Property name 2868' FNL,3588'FEL,Sec.34,T12N, R11E,UM At top of productive interval 4449' FNL,2629'FEL,Sec.34,T12N, R11E, UM At effective depth 721' FNL, 1515' FEL, Sec. 03, T11N, R11E, UM At total depth 764'FNL, 1486'FEL,Sec.03, T11N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Prudhoe Bay Unit 8. Well number (asp's 583328,5978135) L-108 "" 9. Permit number I approval number (asp's 584307, 5976564) ~ 202-109/302-309 \" 1 o. API number (asp's 585441, 5975026) "-.J. 50-029-23090-00 11. Field I Pool Prudhoe Bay Field / Borealis Pool (asp's585471,5974983) 8294 feet 7039 feet Plugs (measured) Effective depth: measured 8194 feet Junk (measured) true vertical 6954 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 108' 20" 260 sx ArcticSet (Aprox) 137' 137' Surface 2691' 9-5/8" 555 sx ArcticSet Lite, 2720' 2621' 249 sx Class IG' Production 8254' 7" 490 sx Class 'G' 8279' 7026' .~''''''' :." 1:; :\ '0;'" ~~ it' ¡:r~" measured Open Perfs 4958'-5006', 5042'-5080', 5096'-51161, 5167'-5184', 5235'-5276' ,J/Ü\! ~~) "¡ 200~) true vertical Open Perfs 4350'-4386',4414'-4443',4455'-4470', 4509'-4523', 4562'-4594' j.\iaska Oil & Cm1S. Gorm1~¡ssion Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4827'. 4-1/2" x 3-1/2" XO @ 4827'; 3-1/2" 9.2# ~!a'Ó'~B(3Ð@ 7560'. Perforation depth: Packers & SSSV (type & measured depth) r x 4-1/2" Baker Premier Packer @ 4769'. 7" x 4-1/2" Baker S-3 Packer @ 7502' MD. 4-1/2" HES 'X' Landing Nipple @ 2237' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation SHUT-IN Subsequent to operation 01/10/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my kno~dge. 4~~.#(J~ DeWayne R. Schnorr 12106 16. Status of well classification as: 1392 Suspended - Service WATER INJECTION Title: Technical Assistant Date January 16. 2003 Prepared by DeWayne R. Schnorr 564-5174 ~eOMS 8Fl FEG 4 20m SUBMIT IN DUPLICATE ~ Form 10-404 Rev 06/15/88 . 01/03/2003 01/04/2003 01/04/2003 01/05/2003 01/07/2003 01/08/2003 01/09/2003 01/11/2003 01/12/2003 -) ) L-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS NEW WELL POST: AC-FLUID LEVEL PATCH TUBING / LINER: GAS LIFT--TO DUMMY VALVES; STATIC BOlTOM HOLE PRESSURE SURVEY NEW WELL POST: MIT-IA NEW WELL POST: MIT-IA FIRST DAY OF WATER INJECTION NEW WELL POST: AC-FLUID LEVEL NEW WELL POST: AC-BLEED; AC-FLUID LEVEL NEW WELL POST: AC-MITIA NEW WELL POST: AC-MONITOR EVENT SUMMARY 01/03/03 T/I/O=1380/770/50 TBG FL @ 62501. IA FL @ 50001. For W/L. 01/04/03 DID STATIC SURVEY W/ PETRADAT GAUGES, LOCATED T.T. @ 75561 SLM + 4 = 75601 MD / TAG TD @ 81541 SLM + 4 = 81581 CORRECTED TO MD. DUMMY OFF STA # 5 & 3. BEGIN MITIA TO 3000 PSI. 01/04/03 MIT IA @ 3000 PSI -INTIAL PSI T/I/O= 1250/1200/0. LOAD LA. W/40 BBLS INHIB SW & 50 BBLS 60/40. PRESSURE UP TO 3000 PSI. 01/05/03 MIT IA @ 3000 PSI (PASSED) - PULL CATCHER @ 47521 SLM. LOAD TBG W/41 BBLS INHIB SW & 50 BBLS 60/40. FINAL T/I/O= 300/1200/0. «< RETURNED WELL TO OPERATOR »> . 01/07/03 FIRST DAY OF WATER INJECTION. 01/08/03 T/I/O = 1460/650/260 TEMP = 116 IA FL (PREP FOR AOGCC MITIA) IA FL @ 1561 (3 BBLS) 01/09/03 T/I/O = 1370/640/180 TEMP = 116 BLEED IA (PREP FOR AOGCC MITIA). BLED IA FROM 640 PSI TO 160 PSI (FLUID TO SURFACE). BRUP IA A COUPLE OF TIMES WITH IA BLEED CRACKED AND FLUID FLOWED TO SURFACE QUICKLY. SIIA BLEED AND MONITOR FOR 20 MIUTES. IA PRESSURE INCREASED 60 PSI IN 30 MINUTES. FINAL WHP's = 1370/220/200. 01/11/03 T/I/O=1500/350/240 (POST DRILLING) (STATE WITNESSED CHUCK SCHEVE) MITIA TO 2000 PSI - PASSED. WELL IS ON INJECTION. IA FL NS. PUMPED 4 BBLS OF METHANOL DOWN THE IA TO PRESSURE THE IA TO 2000 PSI. THE IA LOST 0 PSI IN THE FIRST 15 MINUTES AND 0 PSI IN THE SECOND 15 MINUTES FOR A TOTAL OF 0 PSI IN 30 MINUTES. BLEED IA TO 260 PSI POST MITIA. FINAL WHPs=1500/260/200. 01/12/03 TIO= 1320/200/140. MONITOR WHP's. (POST MIT OA). Page 1 BBLS 1 100 80 181 ') L-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Fluids Pumped PRESSURE TEST LUBRICATOR WI 1 BBL OF DIESEL 60/40 METHANOL WATER INIHIBTED SEA WATER TOTAL Page 2 ) \ ) TREE = 4-1/16"CIW WELLHEAD = FMC ..... ...........,... .............,......,...... ............"..... ACTUA. TOR = NA ..,.............",.."..",....."............. "....."'"". ,,'" KB. I3..EV = 78.4' BF. ELêr,;.-'''w,u, ,... ''''''''NÃ . Kop;-----_.....".....m'.'....'."36ó;' 'fV1aX"ÄrÌgìe'-;""-"43" @YLì6"7'2~ Datum MD ,;;",-~.,._.,w'''82''9~f ~6ãfüñì'TVD-;,-,-".wãäÕÕ".Š-s 9-5/8" CSG, 40#, L-80, ID = 8.835" I., 2720' Minimum ID = 2.75" @ 7548' 3-1/2" HES XN NIPPLE 4-1/2"TBG, 12,6#, L-80, .0152 bpf,lD =3.958" H 4825' 3-1/2"TBG, 9.2#, L-80, .0087 bpf, ID =2.992" H 7558' PERFORATION SUMMl\ RY REF LOG: TCP PERF ANGLE AT TOP PERF: 40 @ 4958' I\bte: Refer to A"oduction DB for historical perf data SIZE SPF INfER\! AL OpnlSqz DATE 4-5/8" 5 4958 - 5006 0 07/02/02 4-5/8" 5 5042 - 5080 0 07/02/02 4-5/8" 5 5096 - 5116 0 07102/02 4-5/8" 5 5167 - 5184 0 07102/02 4-518" 5 5235 - 5276 0 07102/02 2-1/4" 6 7686-7750 0 12/14/02 2-1/4" 6 7760-7766 0 12/14/02 2-1/4" 6 7774-7781 0 12/14/02 2-1/4" 6 7785 - 7791 0 12/14/02 1 PBTD H 8194' 1 7' CSG, 26#. L-80. ID = 6.276" H 8279' DA.TE 08131/01 05120/02 07/02102 07/10/02 07/31/02 08106102 COMWENTS ORIGINAL COMR..EnON PROPOSBJ COrvPLETION INITIA L COMR..EnON INITIAL COMR..EnON UFUATE GLV CiO GLV LPDA. TE REV BY DATE 12/07/02 12/14/02 12/16/02 01/04/03 JDF WRD TA/tlh JBlKAK RL/tlh ) L-1 08 SAFETY NOTES: GLM'S@ STA#1 & #2 ARE3-1/2" X 1-1/2" MMG-WS WATERFLOODMANDRELS. :---t 1018' 1-1 9-5/8" TA M PORT COLLAR 1 I I 1 223T I., 4-1/2" HES X NIP, ID = 3.813" I ~ GAS LIFT MANDRELS l ST fvD TVD DBI TYPE VLV LA TCH PORT DATE 5 3818 3500 38 KBG-2 DMY BK-5 0 01/04/03 4 4199 3800 39 KBG-2 DMY BK-5 0 07/02102 3 4693 4250 43 KBG-2 DMY BK-5 0 01/04103 WA TERFLOOD Ml\NDRELS ST MD TVD DBI TYPE VLV LA TCH PORT DATE 2 4867 4281 41 Mtv'G-W DMY RKP 0 07/02/02 1 4926 4334 40 Mtv'G-W DMY RKP 0 07/02/02 I 4758' H 4-1/2"HESXNIP,ID=3.813" I ~ 4762' - 4788'1" 4-1/2" MERLA PERMTBG PA Ta;, ID = 3.235" I ~ 1 4769' H 7" X 4-1/2" BKR ffiEMER PKR, D = 3.870" 1 :g I 4825' I., 4-1/2" X 3-1/2" XO, ID = 2.992" 1 ~ I :g :8: :g " --.J ~ 7489' 7500' 7502' 7505' 752T 7548' 7560' 1-1 3-1/2" HES X NIP, ID = 2.813" I 1-1 3-1/2" X 4-1/2" XO, ID= 2.940" I H 7" X 4-1/2" BKR &3 A<R, ID = 3.875" I H 4-1/2" X 3-1/2" XO, ID = 2.920" I H 3-1/2" HES X NIP, ID = 2.813" I 1-1 3-1/2" HES XN NIP, ID = 2.75" 1 H 3-1/2" WLEG, ID = 2,905" 1 7624' 1-1 RA TAG I c 8051' H RA TAG 1 ~ REV BY COMWENfS JBM'KK SET MERA PERM TBG PA Ta-I CA QlKK ADPERFS MH'KK GL V DATE CORRECTION JM/KA K GL V C/O GPB BOREA US WELL: L-108 PERMT t\b: 2021090 API t\b: 50-029-23090-00 SEC34, T12N, R11E, 2412' NSL& 3588' WEL 8P Exploration (Alaska) ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Chairman THRU: Tom Maunder i&11'1 ~ P.I. Supervisorft "d ,,,,..-Ð"" FROM: Chuck Scheve Petroleum Inspector NON. CONFIDENTIAL ~ DATE: January 11 2003 SUBJECT: Mechanical Integrity Tests BPX L Pad L-108 PBU Packer Depth Pretest Initial 15 Min. 30 Min. Well L-1 08 Type Inj. S TV.D. 4769 Tubing 1500 1500 1500 1500 Interval I P.T.D. 202-109 Type test P Test psi 1192 Casi ng 350 2010 2010 2010 P/F f Notes: New Well Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: New Well Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj, TV.D. Tubing Interval P.T.D. Type test Test psi Casi ng P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year CYcle s = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial :MIT on well L-I08. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1 Attachments: Number of Failures: Q Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. MIT PBU L-108 1-11-02 CS.xls 2/17/2003 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ISI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2412' NSL, 3588' WEL, SEC. 34, T12N, R11E, UM At top of productive interval 830' NSL, 2629' SEL, SEC. 34, T12N, R11 E, UM At total depth 764' SNL, 1486' WEL, SEC. 03, T11 N, R11 E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.4' ADL 028241 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/18/2002 6/26/2002 7/4/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8294 7039 FT 8194 6954 FT ISI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, RES 1 AIT, DT 1 BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC Sonic, USIT CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 30" 260 sx Arctic Set (Approx.) 29' 2720' 12-1/4" 555 sx Articset Lite, 249 sx Class 'G' 25' 8279' 8-3/4" 490 sx Class 'G' TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 4825' 3-1/2",9.2#, L-80 4825' - 7560' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 87 Bbls Diesel 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf 2-1/4" Gun Diameter, 6 spf MD TVD MD TVD 4958' - 5006' 4350' - 4386' 7686' - 7750' 6519' - 6574' 5042' - 5080' 4414' - 4443' 7760' - 7766' 6583' - 6588' 5096'-5116' 4455'.4470' 7774'.7781' 6595'-6601' 5167' - 5184' 4509' - 4523' 7785' -7791' 6605' - 6610' 5235' - 5276' 4562' - 4594' 25. 26. 27. Date First Production Not on Production Date of Test Hours Tested 12/25/2002 1.8 Flow Tubing Casing Pressure Press. 308 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BBl TEST PERIOD 59 GAs-McF 1,715 GAs-McF WATER-BBl 1.47 WATER-BBl CALCULATED 24-HoUR RATE Oll-BBl Revised: 12/27/02, Perf & Put on Production Classification of Service Well Pre-Produced Injector 7. Permit Number 202-1 09 8. API Number 50- 029-23090-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-108i 11. Field and Pool Prudhoe Bay Field 1 Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2237' MD 1900' (Approx.) AMOUNT PUllED PACKER SET (MD) 4769' 7502' CHOKE SIZE 1760 Oil GRAVITY-API (CORR) GAS-Oil RATIO 28,876 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oj¡, gas or water. Submn core Chi'R E eEl V E D No core samples were taken. 28. RBDMS BFl DEC ':), ,-,I . -.,,--, ~ 1 Form 10-407 Rev. 07-01-80 ~ ~\ DEC 2? 2002 ,:~\laska Oil & fas Cons. Commiss!ür ,.."nchoraqe I, \~ Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Schrader Bluff N Sands Schrader Bluff 0 Sands Base Schrader I Top Colville CM1 HRZ Kalubik Kuparuk D Kuparuk C4 Kuparuk C3 Kuparuk C2 Kuparuk C1 LCU / Top Kuparuk B Kuparuk A Miluveach 4746' 4958' 5429' 6694' 7292' 7540' 7666' 7685' 7703' 7756' 7820' 7879' 8037' 8132' 4192' 4350' 4715' 5704' 6180' 6392' 6502' 6518' 6534' 6580' 6635' 6686' 6821' 6902' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ Title Technical Assistant Date \~. ~ 7.0~ L-108i Well Number 202-1 09 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: James Franks, 564-4468 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .) ) Well: Field: API: Permit: L-108i Prudhoe Bay Unit 50-029-23090-00 202-109 Rig Accept: 06/18/02 Rig Spud: 06/18/02 Rig Release: 07/04/02 Drilling Rig: Nabors 9ES POST RIG WORK 07/26/02 MIT COMBO TUBING/IA. CMIT T X IA TO 2500 PSI PASSED. 07/30/02 PULL STA# 5,1" DGLV BK. SET STA# 5 LGLV, (1/4" 1650#). SET STA# 3 OGLV (5/16). 07/31/02 FINISH SETTING STA# 3 OGLV. PULL 4 1/2" WHIDDON C-SUB. EQUALIZE & PULL 4 1/2" XX PLUG FROM 47581. RMDO. LEAVE WELL SHUT IN. POST RIG. NOTIFY AND HANG TAG THAT TWO PLUGS STILL IN HOLE @ 7521' & 7548'. CMIT TXIA MIT T. 08/01/02 MIT T (INCONCLUSIVE). LEAK RATE LESS THAN 2.2 GPM @ 2500 PSI. POSSIBLE TTP LEAKING. NO INDICATION OF T X IA COMMUNICATION DURING PUMPING OPERATIONS. 08/03/02 LDL. LOG BASELINE PASS DOWN FROM SURFACE AT 120 FPM. PUMPING METH DOWN TUBING AT 2000 PSI - 2500 PSI USING TRIPLEX (PLUG IN TUBING AT 7500') TO LOOK FOR 2.5 GPM LEAK. LOG UP AT 120 FPM FROM 7500' TO SURFACE. LOCATED TEMPERATURE ANOMALY NEAR PACKER AT 4769'. ANOMALY REPEATED. LOG OUT OF HOLE. 8 BBL METH TOTAL PUMPED OVER 2 HOURS = LEAK RATE OF 2.8 GPM. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. LEAK DETECTION LOG MAINTAIN 2500 PSI ON TBG. 08/06/02 DRIFT, PULL 3112 XX PLUG @ 7492' SLM, PULL OGLV STA 3, PULL LGLV STA 5, SET GENERIC GAS LIFT DESIGN, PULL 3112 RHC-M PLUG, D/T WI 2 1/2" X 10' DG TEL SB TAG TD @ 8195' CORR TO MD SAND IN SB. RDMO, WELL SHUT IN. 08/15/02 MITT FAILED. LEAK RATE DOWN TBG WAS 4 GPM @ 2500 PSI. THE lAP DID NOT CHANGE DURING PRESSURE TEST. 1 0/19/02 ATTEMPT TO BREAK ICE PLUG IN TBG, 10 BBLS OF 60/40 METH/WATER PUMPED DOWN TBG. FREEZE PROTECT FLOWLINE WITH 18 BBLS OF 60/40 METH/WATER. FREEZE PROTECT IA WITH 75 BBLS OF 60/40 METH/WATER. 1 0/20/02 DRIFT W/2' 1 7/8 STEM 2.50 CENTSB SD @ 1938' SLM. ICE IN S.BAILER. RDMO (WELL SHUT IN). 10/23/02 MU AND RIH WITH 2.25" OJ NOZZLE. TAG HYDRATES AT 1958 AND WASH THROUGH TO 2769. RIH AND TAG TO AT 8152 CTMD (UP). POH. L-108i, Post Drilling Summary Page 2 ') ) 1 0/24/02 POH DISPLACING NEET MEOH AT 90% TO FREEZE PROTECT WELL TO 4000' WITH NEET MEOH. LINE UP FOR INJECTIVITY TEST WITH 60/40 MEOH. INJECTIVITY TEST RESULTS: 1 B/M AT 350 PSI (11 BBLS PUMPED); 2.5 B/M AT 1650 (25 BBLS PUMPED) SD AND WHP FALLS TO 240 IN 30 SECONDS. MONITOR 5 MINUTES. 2.5 B/M AT 1425 (10 BBLS PUMPED).. SD AND WHP FALLS TO 240 IN 30 SEC. AGAIN. FREEZE PROTECT IA WITH 10 BBLS NEET AT 1.75 B/M AT 1800 PSI. NOTE: IA AND OA REMAINED CONSTANT DURING ALL PHASES OF THE INJECTIVITY TEST. RDMO. NOTIFY OPERATOR THAT WELL REMAINS SI FOR FURTHER TESTING. 10/31/02 PUMP DOWN IA. IA PRESSURED UP TO 2000# @ 28 BBLS. LLRT= 2.3 BPM @ 2000# FOR 10 BBLS. RIG UP TO TBG. ATTEMPT MIT TBG. PUMPED 75 BBLS DIESEL DOWN TBG. 11/01/02 PUMP TOTAL 115 BBLS DIESEL DOWN TBG. 2 BPM @ 1350 PSI. NEVER PRESSURED UP. T/I/0=320/31 0/100 LLRT-IC (LRS); INITIAL IA FL AT SURFACE, TBG FL AT SURFACE. LRS STARTED PUMPING DOWN THE IA AND PRESSURE INCREASED TO 2000 PSI AND THE TBG PRESSURE INCREASED TO 1300 PSI AT 3 BBLS PUMPED, STARTED LEAK RATE TEST. PUMPED 20 BBLS IN 9 MINUTES FOR AN AVERAGE LEAK RATE OF 2.2 BPM @ 2000 PSI. PUMPED A TOTAL OF 23 BBLS OF DIESEL DOWN THE IA. FINAL WHP'S = 350/350/100. PUMP 90 BBLS 60/40 METH DOWN IA @ 1.5 BPM @ 1350 PSI. RIG UP TO TBG TO PUMP 121 BBLS60/40 METH DOWN TBG. 11/03/02 PERFORMED LDL. BASELINE PASS LOGGED FROM TO (81581) TO 4600'. LOGGED UP PASS WHILE PUMPING MEOH DOWN IA @ 2 BPM (FLUID ENTERING TBG THRU GLV'S). LEAK SEEN AT UPPER PKR @ 4770' ELM. LOG DOWN PASS. STOP COUNTS TAKEN IN TUBING TAIL, ABOVE AND BELOW WATERFLOOD MANDRELS & UPPER PKR LEAK. LOGGED ANOMALY UPIDOWN PASSES ACROSS THE LEAK AT 60 FPM WHILE PUMPING @ 1 BPM. POOH. RDMO. WELL LEFT SHUT IN. 11/08/02 PULL LGL V'S FROM GLM'S #3 & #5. SET DGL V'S IN GLM'S # 3 & 5. MITIA TO 2000 PSI (GOOD TEST). 11/09/02 PULLED 4-1/2" CATCHER SUB. RAN 3.805 X 25.65' DUMMY PATCH TO 3 1/2 X-OVER @ 4813' WLM (4-1/2" X 3-1/2" XO @ 4825' MD - PACKER @ 4769' MD) (NO PROBLEMS ENCOUNTERED). WELL LEFT SHUT IN. 12/07/02 HALLIBURTON PATCH SET ACROSS THE LEAKING PACKER. TOP SEAL OF THE PATCH SET @ 4762', BOTTOM SEAL @ 4788'. MIN. 10 OF 3.235" IN PATCH. X-OVER TAGGED @ 4823'. 12/10/02 TII/0=10/530/120 MITIA TO 3000 PSI PASSED (POST PATCH). INITAIL IA FL @ SURFACE. PRESSURED IA TO 3000 PSI. MITIA LOST 5 PSI IN 15 MIN, 0 PSI IN SECOND 15 MIN, FOR A TOTAL OF 5 PSI IN 30 MIN. MONITORED IA FOR ADDITIONAL 30 MIN WITH NO DECREASE IN PRESSURE. PUMPED A TOTAL OF 1 BBLS OF DIESEL. BLED IA BACK TO 100 PSI. FINAL WHP'S 10/200/120. 12/11/02 T/I/O = 10/100/120 MIT-T PASSED TO 3000 PSI (POST TBG PATCH) TBG FL NEAR SURFACE. PRESSURED TBG UP TO 3000 PSI (1 BBL DIESEL). IN FIRST 15 MIN TBG LOST 50 PSI. IN SECOND 15 MIN TBG LOST 20 PSI FOR A TOTAL OF 70 PSI IN 30 MIN. REPRESSURED IA TO 3000 PSI (VERY SMALL FILL UP VOLUME). TBG LOST 20 PSI IN 15 MIN AND 0 PSI IN SECOND 15 MIN FOR A TOTAL OF 20 PSI IN 30 MIN. MONITORED ANOTHER 30 MIN WITH NO DECREASE IN TBG PRESSURE. BLED TBG BACK TO 200 PSI. FINAL WHP'S = 200/140/140. L -1 08i, Post Drilling Summary Page 3 ') ') 12/14/02 PERF INTERVALS: 7791' - 7785', 77811 - 7774',7766' - 7760', 7750' - 7686' IN FOUR RUNS WITH 2.25" 2306 PJ HMX 6 SPF 22.8 PEN, 60 DEGREES, 10 DEG OFF BOTTOM. TIE INTO SWS JEWELRY LOG DATED 29-0CT- 02. TAGGED TD AT 81561. SHOOT WITH WELL SHUT IN. SHUT IN. 12/15/02 SET CATCHER @ 4755' SLM. PULLED 1" DGLV I SET LGLV TRO# 1650 IN STA # 5. ATTEMPT TO SET S/O IN GLM # 3. 12/16/02 PULL DGLV FROM GLM # 3. SET 20/64" S/O IN GLM # 3. PULL CATCHER. RETURN WELL TO OPERATOR. Borealis well L-l 08 Status ) ) Subject: Borealis well L-I08 Status Date: Thu, 12 Dee 2002 11 :05:44 -0600 From: "Smith, Bruce W" <SmithBW@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Smith, Bruce W" <SmithBW@BP.com> ZD 2. - I D q Winton, Borealis well L-I08, had a Merla Patch set across the leak that was found in the straddle. Well was MIT'd last night and held full pressure for 30 min. No leak off was seen after fill up was completed. We are moving forward with the perforation and pre-production period, which will be followed with injection service after approx 10 days of pre-production to cleanup the perfs. We are following the conditions as set out in sundry 302-309. Have a good day. regards Bruce Bruce W. Smith BP Exploration (Alaska) Borealis Development Engineer PO Box 196612 MS 6-5 Anchorage AK 99519-6612 907-564-5093 Cell 440-8008 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Log Description Job# V-105 <1n~-/3L L-108 .~~-llJc..¡ 1-108 V-109 arB "'~od. JEWELRY LOG/GRlPRESS JEWELRY LOG/PSP LDUPSP 22501 USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED DEC 10 2002 Alaska 0;1 & Gas Cons. Commission Anchorage 10/28/02 10/29/02 11/03/02 10/28102 12/10/02 NO, 2590 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color CD Sepia BL '---. Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth ~ n Receive~~~ -------- L-108 status ) ) Subject: L-I08 status Date: Mon, 4 Nov 2002 21 :54:26 -0600 From: "Smith, Bruce W" <SmithBW@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Smith, Bruce W" <SmithBW@BP.com>, "NSU, ADW Well Integrity Engineer" <NSU ADWW ellIntegrityEngineer@BP.com> ZDZ.-iOC) Winton, As we discussed on the phone, here is the current status on L-108 at Borealis: L-108 will be a pre-produced injector. A series of issues have arisen during the prep work to complete initial Perf. Ann Comm Work found a 2.5 BPM leak with a combined IA & Tubing pressure test. Leak was found using a LDL (3-Nov-02) at approx 4770 MD. A 2.2 GPM leak was found earlier on the thread just below the upper packer located at 4769 MD, the current increased flow leak is assumed to be the same location. Upper surface of packer was checked earlier with all gas lift valves dummied off, as being good. Water Injection Mandrels are located at 4867 and 4926 MD with a 4 % by 3 % inch cross over at 4825 MD. A full gas lift design is currently in the well. A Merla (or similar) permanent packer is planned on being used to straddle the leaking packer / thread leak. Once patch is in place a new combo casing and tubing pressure test will be completed, showing casing, straddle, upper and lower packer as ok, perforation program for pre-production is plannned. I will keep you informed of our progress and results. If you have any question give me a call 440-8008. regards Bruce Bruce W. Smith BP Exploration (Alaska) Borealis Development Engineer PO Box 196612 MS 6-5 Anchorage AK 99519-6612 907-564-5093 Cell 440-8008 bp ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 01, 2002 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 994501 Re: L-108i Mechanical Variance Dear Mr. Aubert: RECEI'VED OCT 0' 2002 AlØOi~& Gas Cons. Commtssion Anchorage Based on our meeting of Thursday September 26, 2002, the Operator suggest the following additional surveillance requirements to allow the Prudhoe Bay Satellite Well L-108i to be placed on water injection: . Every six months from the start of injection, a slickline isolation plug will be placed in one of the lower profiles, 7489 MD, 7527 MD or 7548 MD. . AOGCC Field Inspector will be notified 24 hours prior to planned test, to allow them to witness if desired. . Tubing will have a chart recorder attached to it, providing a hard copy of the pressure test. . Tubing will be pressure tested to 2500 psi for 30 min using diesel. 0 If a pressure loss is noted, a rate will be obtained, recording WHP, lA, OA, pressure test pressure, times, rate of injection if noted. . If pressure test holds 2500 psi / 30 min with less than 10% loss, bleed off pressure and repeat test. Notify L-pad Engineer by E-mail with details. Forward Chart by interoffice mail. Pull plug and Place well back on injection immediately. . If pressure test (2500 psi) shows a leak off of between 0-8.0 gpm, record details and send information to L-pad engineer interoffice mail, forward chart by interoffice mail. Pull plug and Place well back on injection immediately. . If pressure test (2500 psi) shows leak off greater than 8.0 gpm, Contact L-pad Engineer, currently Bruce Smith by phone prior to pump leaving location (907)-440-8008, plan to freeze protect well and injection line. Fax chart to Anchorage (907) 564-5016. Leave well shut-in for further evaluation. L-I08i will return to normal water injector surveillance requirements as specified in Borealis Area Injection Order #24, rule #5, once Orion Area Injection order is approved. ) ) If there are any questions or you have any suggestions please contact me (440-8008) or Gil Beuhler. Sincerely, ~ y ~ Bruce W. Smith Development Engineer, GPB- WEND BWS:bws cc: Well File NS Well Integrity Engineer bp ') ') ... ,'-t,.t". ~~~ ~~. .-..- _.~ ........~ '~.,..~ .'I'.~I\. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561.5111 September 24, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for L-1 08 - MIT Variance allowing pre-production & Conversion from Pre-Produced Injector to Water Injector BP Exploration Alaska, Inc. proposes to place L-108 onto pre-production for +/-10 days, converting the well from a pre-produced injection well to an active injector (Water flood only) as part of the Borealis Pool Flood Development project. A MIT Varience is requested for the subject well. Well currently has a 2.5-4.0 gallon per minute leak located at the lower thread of the upper packer at 4770 MD, when tested from the tubing side. Wells cement job was evaluated with good to very good cement quality providing required isolation of all production zones. The Inner Annulus has passed Mechanical Integrity Test (MIT). All well materials are new. The procedure includes the following major steps: Slickline Work: 1. Drift to TO @ 8236 MD. 2. Run GL V. E-Line work: 3. Perforate wellbore in the Kuparuk C formation +/- 7700 MD. 4. Place well on +/- 10 days of Pre-production to cleanup perforations. Slickline Work 5. Pull GL V and Dummy same. 6. Run Static survey. 7. Contact AOGCC for MIT Inner Annulus 8. Place well on Injection. .) ) Last test: No Tests Max Deviation: 43° @ 4672' MD Top Perf deviation: 40° @ 4958' MD Min. 10: 2.75" XN nipple @ 7548' MD Last TO tag: 8195' MD 08/06/2002 Last Downhole Ops: Pulled tubing tail plug 08/18/2002 Latest H2S value: 0 ppm Wellbore Fluids: Tubing Oil, IA Gas Lift. BHT & BHP: L-108 - To be acquired in the next couple of weeks. Reference Log: Schlumberger Platform Express Gamma Ray Log 06/27/2002 Attached are copies of the drilling reports concerning the cementing and completion, also copies of the North Slope PE department troubleshooting and diagnostics telexes are provided for your review. The USIT has already been sent. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @ BP .com 6::IY,~ ~ Bruce W. Smith GPB Borealis Development Engineer ) ') 'yJ4A- ? I tStOL ..» Cf(7£f~ /'At-15 /0/9' ItJ 2.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Pre-Producer Alter casing -- Repair well - Converted to Inject Change approved program- 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2868'FNL,3588'FEL,Sec.34, T12N, R11E,UM At top of productive interval 4449' FNL, 2629' FEL, SEC 34, T12N, R11 E, UM At effective depth 721' FNL, 1515' FEL, Sec. 03, T11N, R11E, UM At total depth 764' FNL, 1486' FEL, Sec 03 T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 2691' 9-5/8" Production 8254' 7'1 Perforation depth: Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 583328, 5978135) (asp's 584307, 5976564) (asp's 585441, 5975026) (asp's 585471, 5974983) 8294 feet 7039 feet 8194 feet 6954 feet Plugs (measured) Junk (measured) Re-enter suspended well - Pre-Producer Converted Time extension - Stimulate - to Injector Variance _X Perforate - Other _X 6. Datum elevation (DF or KB feet) RKB 78.4 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-108 ./ 9. Permit number I approval number 202-1 09 10. API number 50-029-23090-00 11. Field / Pool Prudhoe Bay Field / Borealis Pool ':~ Cemented 260 sx ArcticSet (Aprox) 555 sx ArcticSet Lite, 249 sx Class 'G' 490 sx Class 'G' Measured Depth 137' 27201 True vertical Depth 137' 2621' 8279' 70261 measured Open Perfs 4958'-5006', 5042'-5080', 5096'-5116', 5167'-5184', 5235'-5276' true vertical Open Perfs 43501-4386',4414'-4443',4455'-44701, 4509'-4523', 4562'-4594' Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 4827'.4-1/2" X 3-1/2" XO @ 4827'. 3-1/2" 9.2# L-80 TBG @ 7560'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4769' MD. 7" x 4-1/2" Baker S-3 Packer @ 75021 MD. 4-1/2" HES 'X' Landing Nipple @ 2237'. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: / October 1, 2002 16. If proposal was verbally approved R:;C'IV [ D Gas - ~~fen~e1 2002 AlaSka 01& GaaGønL"'" WATER INJEC~OR - . A-M...øI Questions? Call Bruce W. Smith @ ~4-5093, Oil- Date approved Service and correct to the best of my knowledge, if V 0 - -S-vO 8 Title: Borealis Development Petroleum Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - SOP Test - Location clearance - ,./, I MechanicallntegrityTest~ Subsequent form required 10-1-0; ~iut Î V\.-f-o t'vy¡" YUIL "~(JRIGiNAL SIGNED BY Approved by order of the Commission D Tavlor Sp.~mountCommissioner Name of approver 17. I h~t th~gOing is tr Signed Bruce W, Smith Form 10-403 Rev 06/15/88 . 0 F. '. . \ l'.'\ ~ ~. .1 .::~ l -;: j \~ ~:ì ' II \~ ¿~\ , ; \c.,,)' 9 'ìj ø - Date September 24, 2002 Prepared by DeWayne R Schnorr 564-5174 I Approval no. ~ - -; ,--~o2 3::?¡ Date I n/Or/nd SUBMIT IN TRIPLICATE =-1 1018' 1-1 9-5/8" TAM PORT COLLAR I I 223T 1-1 4-1/2"HESXNIP,ID=3,813" 1 ) 4-1/16" CIW FMC ...J~~, 78.4' .....,..,.,........,m'."NA '"3õõ' " :43"@'4672ì' 8294' . ,,,oo".'aäÕä^ss TREE = WELLHEAD = ,............".....................,.... ......., ACTUô. TOR = ".".".,...........,......".,.".,...,..,."...., KB. B..EV = .BF.'.'ËLEV";" , "RÖp..;,m...... 'Mäx"An'gìe' ';00'00 Datum'MO.;' 5äÙJmTvÕ';".' L-1 08 = I . 9-5/8" CSG, 40#, L-80, 10 = 8.835" 1-1 2720' ~ l Minimum ID = 2.75" @ 7548' 3-1/2" HES XN NIPPLE 4-1/2"TBG, 12.6#, L-80, ,0152 bpf, 10 =3.958" H 4825' I I :8: ~ ... ---1 ~ 3-1/2"TBG, 9.2#, L-80, ,0087 bpf, 10 =2,992" H 7558' PERF ORA TION SUM~ RY REF LOG: TCP PERF ANGLE AT TOP PERF: 40 @ 4958' Note: Refer to R'oduction DB for historical perf data SIZ E SPF INTER\! AL Op nISqz DATE 4-5/8" 5 4958 - 5006 0 07102/02 4-5/8" 5 5042 - 5080 0 07/02/02 4-5/8" 5 5096 - 5116 0 07102/02 4-5/8" 5 5167 - 5184 0 07102/02 4-518" 5 5235 - 5276 0 07102/02 1 PBTD H 8194' 1 7' CSG, 26#, L-80, 10 = 6,276" H 8279' ~ DA.TE R8I BY COrvtv1ENTS DATE REV BY COMTl/ENTS 08131101 ORlGINA.L COMPLETON 08/06102 RLAlh GL V UPDA. TE 05120102 JDF PROPOSED <X>MR..EfION 07/02102 WRD INfTlAL COMR..E1l0N 07/10102 TA/th INfTlAL COMR..E1l0N URJA TE 07/31102 JB/KAK GLV 00 ~ c ~) SAÆTY NOTES: GL M'S @ ST A #1 & #2 ARE3-1/2" X 1-1/2" MMG-WS WA TERFL OOD M ANI:RELS. GAS LFT ~NDRELS MD TVD 081 TYPE VL V LA TCH 3818 3500 38 KBG-2 DOME BK-5 4199 3800 39 KBG-2 DMY BK-5 4693 4250 43 KBG-2 SO BK-5 W A TERFLOOD ~ NDRB..S MD TVD 081 TYPE VL V LA TCH 4867 4281 41 MMG-W DMY RKP 4926 4334 40 MMG-W DMY RKP PORT DATE 16 08/06/02 0 07/02/02 20 08/06/02 PORT DATE 0 07/02/02 0 07/02/02 4758' 1-1 4-1/2" HES X NIP, 10 = 3,813" 1 4769' H 7" X 4-1/2" BKR ffiEMER PKR, D = 3,870" 1 4825' 1-1 4-1/2" X 3-1/2" XO, 10 = 2,992" 1 7489' 7500' 1-1 3-1/2" HES X NIP, 10 = 2.813" 1 1-1 3-1/2" X4-1/2" XO, 10= 2,940" 1 H 7" X 4-1/2" BKR &3 R<R, 10 = 3.875" I 1-1 4-1/2" X 3-1/2" XO, 10= 2.920" 1 1-1 3-1/2" HES X NIP, 10 = 2.813" 1 1-1 3-1/2" HES XN NIP, 10 = 2.75" 1 1-1 3-1/2" WLEG, 10 = 2.905" 1 7502' 7505' 7527' 7548' 7560' 7624' 1-1 RA TAG 1 8051' 1-1 RA TAG 1 GPB BOREALIS WELL: L-108 PERMT N;): 2021090 AA No: 50-029-23090-00 SEC 34, T12N, R11E 2412' NSL & 3588' WB.. BP Exploration (Alaska) . , ') ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 8/1 5/2002 AFE BR D5M4087 JOB SCOPE NEW WELL POST DAILY WORK AC-LLRT; AC-MITIA KEY PERSON VEC-EAGLlNG MINID 0 " I DEPTH 0 FT UNIT UNKNOWN DAY SUPV ANDERS NIGHT SUPV TTL SIZE 0" DAILY SUMMARY MíTT FAILED. LEAK RATE down TBG was 4 GPM @ 2500 psi. The lAP did not change during pressure test.'*** Reviewing results with APE *** Init TbQ, lA, OA -> I 3401 1201 3401 TIME I COMMENT Final TbQ, lA, OA -> 1 3401 01 3001 1 FLUID SUMMARY SERVICE COMPANY - SERVICE PEAK H M ^^ M ^ ^^ M , M ^ "^ . 'u "vEcå ^ 'h" ^. šTj ^^ UNK'NÖWN ^ ,~;;, ^ ^ ~^ . N'N'V YV"" COB^URN MACHIr\fE SC HLUMBERGER HALLIBURTON WAREHOUSE LITTLE RED". ^ ""v.;, '",,""" " ^ . ^ , DAILY C.QSl:., ^ CUM~L,. TOTAL $200 $1,600 """W" ,,,,,",_. , vvv. w.~, "'.m.'" ^ V V v v'$ö'" ,w",,,,w. '.N 'w."''''''~"...v ^ N '^ '^^ ^ $0 ,- v .."'^,, ^ $0 $0 $0 $0 $0 .. $.1 ,800 ~ $460 $(460 "r ,,,w'M$42 '$25'. $'186 $7,755 $6,233 $320 $613 .$20,094 .."""",,-,. "\Y' ''''I VWW\ ,-,- v v",,,,^.. "" I,A I,V\' "V W "W,'V 'IV", V 'WV "v,,, ''',..^..^'' ^ v v ,,,,,^ ..... .................."'.."".......,.,..,.,... ......................""....... . .. TOTAL F.IELD ESTIMATE: .."^...- . http://apps-alaska.bpweb. bp.com/sst_drilling- wells/well_events_query Iwellevent_awgs.asp... 9/23/2002 '") ) Page 1 of2 WELL SERVICE REPORT WELL L-108 DATE 8/6/2002 AFE BRD5M4087 JOB SCOPE NEW WELL POST DAILY WORK GAS LlFT--FOR RATE; TUBING TAIL PLUG KEY PERSON HES-GUNNELS MIN ID 2.75" DEPTH 7548 FT UNIT HES 70311 DAY SUPV FARRIS NIGHT SUPV LlDDELOW TTL SIZE 3.5" DAILY SUMMARY (WELL SHÙT IN ON ARRIVAL) DRIFT, PULL 3 1/2 XX PLUG @ 7492' SLM, PULL OGLV STÄ 3, PULL LGLV STA 5, SET GENERIC GAS LIFT DESIGN, PULL 3112 RHC-M PLUG, D/T WI 21/2" X 10' DG TEL SB TAG TD @ 8195' CORR TO MD SAND IN SB RDMO (WELL SHUT IN) (BOTTOM SHOT @ 7791') Init Tbg, lA, OA -> I 800 I 180 I 350 I TIME COMMENT ÖV1":OOv- MÒVE'~TÕ'~[:1Ò8i. GET F'ORK'vCfFT"ÖÂIVËR'fóvr\ìí'OVE''''RÎG SCAFFOLDvFRorvf'[:105.' W"^.NA^ v -M~.I ^ "õT:26'STANosV FOÂ' FÖÄ'RliFf"õ"ÄÎVER:IÑS"P'ECt'IöòAfION. TGSrv("m,.,,,",,-,,.,.,,... "'.M, , ""'" , Ö~E'35 SCAF'FOItYM'OVED TO L~1Õ8:.spof EoOfpME.Ñy:"mw, , , ,....., ,....-..... ,.,"'-, , ,.. "-,,, "."M ,...., õ2:5(f ""SEGfÑ'''ÃTGGING Üp: . T ""'''M'''''^'''^,m w, ""M ,...".",,,,,,,.,, ,,, w." ^', N ".., 03:35 FUNCTION TEST SSV-OK. 03:45 PRESSURE TEST LUBRICATOR- 5 MIN UP, 10MIN HIP-OK. 04:12 RIH WI 2.51" CENTRALIZER, 3' X 1-1/4"STEM & EQUALIZING PRONG FOR 3-1/2" XX PLUG TO 7492' SLM. TAP DOWN. TUBING PRESSURE DROPPED FROM 800# TO 550#. POOH. 04:58 OOH WI TOOLS. 05:22 RIH WI 3-1/2" GR & EQUALIZING PRONG TO 7492' SLM. LATCHED & PULLED 3-1/2" XX PLUG WI FILL EXTENSION. POOH. 06:16 OOH WI TOOLS. 06:30 RIH W/4 1/2 OK-6 1 1/4" JDS TO STA 3 06:40 CREW CHANGE. 07:05 LOC SD LATCH 1" OGL V 20/64" PORTS BK LATCH @ 4682' SLM ST A 3 POOH Ó7:4Ö ÕÕH WI OGLV STA 3 " , '" . "" M~'Õ7^:51 nRIH Wi-SAME fo šrÄ 5 \V\W' "".,-. '..A. '~-'Õ/8^:'Õ9-NLõ^ëlJsb 1':ÀTCH'W1'ií^OGWLv^"SK LATcAFN@j^3^âðVS'VŠLM-t'STÄ^5 po5R""VAVn, .V.UMAM A'^^Ah^^ v vWW'''W--W--'"'N'f,'^N AV '''08:29 OOH WI DGL V' STÄ'.~f ' . "" '., . 'Ö8:37 RIH WI 41/2 OK=Ë3'1" LGLV 16/64J'PORTS 150Óit:'TRO BK LATCH"tÖ STA 5 09:02 LOC SD SET 1" LGLV BK LATCH @ 3805' SLM STA 5 POOH 09:25 OOH WIO LGLV STA 5 09:30 RIH WI 41/2 OK-6 1" OGLV 20/64" PORTS BK LATCH STA 3 10:03 LOC SD SET 1" OGL V BK LATCH @ 4682' SLM ST A 3 POOH , 1'0':30 OOH W/o'OGLV'STÄ 3 . , . ,., , , 10:~i"í=u'R'.wT3 1i? GR ( STEEL pTN L , .", . 11 :03 SD LATCH 3 1/2 RHC-M PLUG BODY @ 7532' SLM PUH HANG UP @ 4899' SLM POOH 11 :30 OOH WI RHC-M PLUG BODY , . 11 :35 CIO TOOL STRING TO 5' 2 1/8 STEM OJ KJ SSS 11 :45 RIH WI KJ 2 1/2 DG TEL SB ( 182" OAL) 12:06 LOC TTL @ 7544' SLM + 16' = 7560' CORR TO MD 12:18 TAG TD @ 8179' SLM + 16' = 8195' CORR TO MD POOH 12:31 OOH WI TOOLS I SAND IN SB 13:00 TRAVEL TO H-20 Final Tbg, lA, OA -> I 480 I 400 I 350 I ,,,,, "...., . I FLUID SUMMARY PUMP 1 BBL DIESEL FOR PRESSURE TEST. I SAFETY NOTES OIL SHEENS SPOTTED IN FRONT OF WELLS L-104 & L-106. REPORTED TO DSO. NOTED ON HSE SAFETY SHEET. http://apps-alaska.bpweb.bp .com! ss t- drilling- wells/well- events_query Iwellevent_a w gs. asp... 9/23/2002 ) SERVICE COMPANY - SERVICE BP COBURN MACHINE HALLIBURTON UN KNO-WN'A I -^-~^ -' AlA "'Þ'EÁ'k V VV V V VWWV.W/- '''''..hl.'''.......N. ^ V V V V \.1'''''''.., "" ^ ^ ...-' V V.I t, Vw..\\.''''' .vË"'ëõ-'- "'^"WV'VW/- WhVW-flNUn.. UnIN^^#A"tnllfl.^^ ^ 'oW V ,-,W"''''''''''W/II --, flM'AV^"""'AflINlIfI'^"'...,- N V WW ,,,,'''''WtlA V -W-""'fll"^,^'^ Vo.^ ioN """"WnlNNM/Un,M 1M scRLÚrV1'BEÄGER ' , . "n "^"M" , ,." " W, WAREHoUSEm LITTLE RED I............... ,"....n............,.,.................. ......................................................... ............. -' . ...,." TOTAL FIELD ESTIMATE: ) DAILY COST $42 $186 $3,944 $0' '$Õ "''',"^''W''''''''''N'" MM"Mmm" m" M $C)' """^"'. . $Ôw_, $0 $0 ..$4:17:~r ..... Page 2 of2 CUMUL TOTAL $42' $186 $6,233 , '$25 ,^ $260' ""m^,,, N'''N' '^ M ^ '''$2';S6ãw "$7)55' . $320 $613 .""..$.fä,:2'94... http://apps-alaska.bpweb.bp .com! S5 t- drilling- wells/well- events_query /wellevent_a w gs. asp... 9/23/2002 ') ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 8/3/2002 AFE BR D5M4087 JOB SCOPE NEW WELL POST DAILY WORK LEAK DETECTION LOG KEY PERSON VEC-PINKSTON MIN ID 0 " I DEPTH 0 FT UNIT UNKNOWN DAY SUPV YEAGER NIGHT SUPV TTL SIZE 0" I DAILY SUMMARY LEAK DETECTION LOG MAINTAIN' 2500 psi on TBG. Init Tb~, lA, OA -> I 250 I 160 I 350 I TIME COMMENT 14:41 T/I/O = 25'0/16Ô/350 Leak'detect Lôg. Pump 'meoh'down TBG and pressure up tô 2500 psi: lAP came' up toM 410 psi, start logging and maintain 2000 psi to 2500 psi on TBG during logging. lAP stayed @ 410 psi during logging, while the OAP slowly came up from 350 to 390 psi during the logging Pumped a total volume of 8 bbls of meoh down TBG. Final WHp1s = 250/230/350 ---_.' Ffñã'i TbQ, IA;()A ->'1 -- 250 I 2230 ,-' 350T''''''-''..'.'._-_on m'- ...----- ""........" ~..,,""" .- I FLUID SUMMARY SERVICE COMPANY - SERVICE VECO .. WAREHOUSE' 'Ü-ÑKNÖWN "",,-, .. W'p'EAtr" , , 'sCHLUMBERGtR ' HALilBURTÒN LITTLE RED '.n...........................,.............................. DAILY COST ww ,,,,,wN1Nnn. MANA -, W v ",,\W\\""""",^WNlnlnh,",A"'h" ,10. 1M IN AV '''''''''''WMI''^^ ^ V\W/^,'MVW. .M 'A W ,,'W-,- 'liMA'" $720 '$320 '.M , $0"''''''"'' ","W, 'MM , W ,,,,,"'"M' " ""M"'$OM'''''' "'WNmM , """''" 'W", . "'-'$0 $0 $0 . $1;04Ö" CUMUL TOTAL on $2;860 : $320 "". . $25" ",w"$2'60'" $7,755 $2,289 $613 ....$1'4: f22." .on"fofALÞIeLï:fEsffMATE.:. .".on. http://apps-alaska.bpweb. bp.comlsst_drilling- wells/well_events_query /wellevent_awgs.asp... 9/23/2002 ') ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 8/3/2002 AFE BR D5M4087 JOB SCOPE NEW WELL POST DAILY WORK LEAK DETECTION LOG KEY PERSON SWS-REILL Y MINID 2.813 " I DEPTH 7489 FT UNIT SWS 2150 DAY SUPV SHUMWAY NIGHT SUPV TTL SIZE 3.5 " DAILY SUMMARY LDL. LOG BASELÎNE PASS DOWN FROM SURFACE AT 120 FPM. PUMPING METH DOWN TUBING AT 2000 psi - 2500' PSI USING TRIPLEX (PLUG IN TUBING AT 7500') TO LOOK FOR 2.5 GPM LEAK. LOG UP AT 120 FPM FROM 7500' TO SURFACE. LOCATED TEMPERATURE ANOMALY NEAR PACKER AT 4769'. ANOMALY REPEATED. LOG OUT OF HOLE. 8 BBL METH TOTAL PUMPED OVER 2 HOURS = LEAK RATE OF 2.8 GPM. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. Init TbQ, lA, OA -> I 250 I 150 I TIME COMMENT 08:00 ARRIVE ON LOCATION SWS 2150. SIGN IN AT RIG CAMP. SPOT EQUIPMENT. PJSM. 08:30 RU ELINE. PU FULLBORE TURBINE SPINNER - CONTINUOUS SPINNER - GRADÎO - PRESSrrEMP/GR/CCL- WEIGHTS - SWIVEL - HEAD. 09:30 SAFETY MEETING. CHECK TOOL~! TRIPLEX OPERATOR ARRIVED ON LOCATION. 10:00 RIG UP TO PUMP DOWN TUBING WITH TRIPLEX. PREP FOR PT. 10: 1 0 PT 500 PSI 1 3000 PSI MAX. . 10:30 BEGIN LOGG¡'NG DOWN FRÖM SURFÄCE At"1^20 FPM. v 11 :40^-' TAG PLVÜG^:/~pO^~""BEGfN'-PO'MpING ME'THANvöL~'FRdrvr/TFfïÞLvEx:vv250'ô ^ps^1. v vvv"~,,... ~ ^ W-I. N 1'2A:'ÕÕ' "'PRËssü'ì=fE'5'''ü'P:''Þ'Ë'FiFO'R"ivf STop"cMðUNï~"AŠ^ÕVË"prOG"AT^75'õ2ï'Tð" E'Ñ sù FfË"'ÑôTËÃ'K'TH'ËFfË:'WW^''''WN'^^ W "AN^' "W^'W 1.¿:f2^' ^LOG UP FÄorv17S0Ô'.' . ,. ^ "^'^ ^ .'MM M m'M"^^ ,.,v,m",,,^ ^ . ".".VU^ , ,,^^ , '^"VA U' . "N.' , .M'M 1S:00 PERFORM UP/DOWN PASSES AT '80 FPM & STOP COUNTS ABOVE ANÓ BELOW ANOMALY NEAR PACKER AT 4769'. , '1v3:'1"'5 'CONTÎt,,iUË..'LOGGINÖ'.Up"fo^SURFA.CË AT 1.20 FPtvfwHILÊ PUMPïÑG: "M .M^f4:ó^Ô AT sURFACE: CEASEN'PUM'PÎNG. RÕ^^Êi.JNÈ.'." , ,.,.",,, ''^^ .."" , ^ ,'^ 15:00' MO SWS 2150. GO TO D-PAD FOR STATIC SURVEY. "'..........."."..Fïïîiiï..Th~i~...ï.Ä.;...ÖA.'=; .r."'..2àöo.1 ..'..'.".220..1. ......"'."'.350'1 ........................ ..... ............... 01 FLUID SUMMARY "1,w'S'ï3^L ÔIESÈL "pf"LÜBE. 8 BBL METHANOL LDL FLUID PUMPED DOWN TUBING. SERVICE COMPANY - SERVICE PEAK SCHLUMBERGER UNKNOWN VEGO HALLIBURTON WAREHOUSE LITTLE RED DAILY COST CUMULTOTAL .. .. ...... m............... TOTAL FIELD ESTIMATE: $260 $7,755 $0 $0 $0 $0 $0 $8,015 $260 $7,755 $25 $2,860 $2,289' $320 $613 ."'$14,122. http://apps-alaska.bpweb.bp.com/sst_drilling- wells/well_events_query Iwellevent_awgs.asp... 9/23/2002 ') ) WELL SERVICE REPORT WELL L-108 DATE 8/1/2002 AFE BRD5M4087 JOB SCOPE NEW WELL POST DAILY WORK AC-MITT KEY PERSON VEC-PINKSTON MIN ID 0" UNIT UNKNOWN DAY SUPV YEAGER NIGHT SUPV TTL SIZE 0" DEPTH 0 FT Page 1 of 1 DAILY SUMMARY MIT T (INCONCLUSIVE). LEAK RATE LESS THAN 2.2 GPM @ 2500 PSI. POSSIBLE TTP LEAKING. No' INDICATION OF T X IA COMMUNICATION DURING PUMPING OPERATIONS. Init TbQ, lA, OA -> I 200 I 160 I 350 I TIME COMMENT 15:06 T/I/O = 200/160/350 MIT T FAILED Initial TBG FL near surface. Pumped 2 bbls of meoh down tbg and pressured tbg to 2500 psi, lAP came up to 400 psi and the OAP came up to 380 psi, TBG lost 1300 psi in 10 mins, pump TBG back up to 2500 psi pressure is falling pump back up to 2500 psi and start LLRT. LLRT-T Pressure TBG up to 2500 psi could not continuously pump with tri-plex, pumped every 35 seconds for 60 mins. Pumped 3.15 bbls or 132 gals of meoh down the TBG with a leak rate of 2.2 gpm. Pumped a total of 6.5 bbls ,- ...~. FinZ; ~~:,1~:tÃ ~:Ih d~;~ te ~:~I. Fi~;Jtf~~'?,=.~~q!~,.~2!~.?9.,....~..._......_...._.........._..",...-'."..-.-..-....,..--.--...-....---..-,.... I FLUID SUMMARY SERVICE COMPANY - SERVICE VEca 'UNKNoWN HALLlBU RTÒÑ.. ..LïTTLË REÖ...'.. DAILY COST -, w"""."~.,, .. ~ v vv'"',""",........ , $880 ......w...." .. $Õ"^" $Õ"m ^ N.... $0." ^ ..$aäo. CUMUL TOTAL $2,140 .. .. '" m. '$~Ú5 " '^..... $2;289 ., $E51""3M ...$5~ OBi. . ." .......................... ".. ................. .............................................. TOTAL FIELD ESTIMATE: http://apps-alaska.bpweb. bp.com/sst_drilling- wells/well_events_query Iwellevent_awgs.asp... 9/23/2002 ) ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 7/31 12002 AFE BRD5M4087 JOB SCOPE NEW WELL POST DAILY WORK AC-CMIT TXIA; AC-MITT KEY PERSON VEC-PINKSTON MIN ID 0" I DEPTH 0 FT UNIT UNKNOWN DAY SUPV YEAGER NIGHT SUPV TTL SIZE 0" I DAILY SUMMARY CMIT TxlA MIT T COTINUE ON WSR 08/01/02 ' Init TbQ, lA, OA -> I 220 I 200 I 350 I TIME COMMENT 16:51 T/I/O = 22Ô/200/350 Initial T FL near surface; IA'^FL @ surfâce. Pumped f.5^bbls'of diesel down TBG, rBG pressured up to 2500 psi in 15 mins, lAP came up to 400 psi, TP fell to 2000 psi in less than 5 mins, start pumping back down TBG, in 5 mins TBG pressure did not change, ran out of diesel monitor TBG and IA for 15 mins, in 15 'm . Fin;i~b;~~, fd~ ~~ b~c~2ÒtI220 fõõ-r'~-~'~~6'r~SE~.9..k ~!'~QQ. p~i. Final WHp1s~ 220/209!.~.5.2 .".. ...... '" ...-.- I FLUID SUMMARY SERVICE COMPANY - SERVICE DA!L.Y COST VEca' .. $780 UNKNOWN $Ó '.HÃLLfBURTON^ w, '" "'^., .. v ^ 'm^N w", ^ ^ n ,",,",m "".^N "N.N , "....M" m $ÕM"M ^ ""[il-tCE "FfËEf ^^^.^ ^ V""WU.' ". ^ ^ "w . ""'W W "'^^ " ^. , r "'^^ ^ """"'^ ^ ^,,'W ,,' ^ N ^ """w'"^ ^ W"W '^"' ^'^' . W"'"W ^ , WW"W ""WMW'^"^ ^ ,,^ ""'$c)^' w m^ ,..... ............ . .... .." ."'...ToTAL.'.ï=fEL'[)"'E.sTïMAf.E:....-"'.... "'.$iaõ..A............. CUMUL TOTAL ,. ^ $1 ¡2?p^ $25 "". ^ "$.2¡2,w^'?9M^.' -, 10. "'''VWII, I ^. . , " $613 ."'...$~(1' 87 http://apps-alaska.bpweb.bp .comlsst_drilling- wells/well- events_query Iwelleven t_awgs. asp... 9/23/2002 . .. ') ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 7/30/2002 AFE BR D5M4020 JOB SCOPE NEW WELL POST DAILY WORK DRIFTrrAG; GAS LlFT--FOR RATE KEY PERSON HES-SPAULDING MIN ID 2.75" I DEPTH 7548 FT UNIT HES 78598 DAY SUPV ROMBERG NIGHT SUPV BOYLES TTL SIZE 3.5" DAILY SUMMARY PULL STA# 5,1" DGLV BK ---- SET STA# 5 LGLV,( 1/4" 16SÖ# )--- SET STA# 3 OGLV (5/16) ---- CONTINUE TO 07-31- 02 WSR Init TbQ, lA, OA -> I 200 I 100 I 300 I TIME COMMENT 19:00 ARRIVE ON LOCATION, MAKE CREW CHANGE OUT WITH NIGHT CREW, SIGN IN ÃT RIG CAMP, ROUND UP SLOP TANK 19:3Ö MIRU# 78598, TGSM, INSPECT LOCATION, RIG SCAFFÓLlNG ;':125 WIRE, 17/8" X 8', OJ, NK-JT, SSPANGS, 20:30 STROKED SSV .. .",,,,,',."w",,^',,, .. "._'''M , W^" ...'M^,' M ,-"",,,,, ,.",,,.'w,,, "........ .~,," ", .'w,,,, ,.w^', w", . "21:30' PTLóW'3ÕÕ#THIG~rTÖÕO#opï~N'šWAB' , "'" .^,W""'''^'' .." ^' . ,"^ ,...." 21 :44 RIH W/4 1/2" OK-6, 1 1/4" JD TO STA# 5 @ 3806' SLM, LOCATE, LATCH, TAP 8 TIMES POH WI DGLV 22:37 RIH W/SAME WI 1" BK LATCH DOME 1/4" PORT, 1650# TO STA# 5 @ 3806' SLM, LOCATE, SIT DOWN TAP, SHEAR, POOH 23:3Cf "'Àü=rw7^411¿" OK-6"WI 51 1ifÖG[v BK LÃTCR'TO S"fA# 3 @ ,,^', " 23:59 CONTINUE TO 07-31-02 WSR ....... mï=lniiï ..thg~.Ü~'~ .ÓÄ ~;.I......m.............m'Tm...m..m.r...ml..... I,,~!g~,~ ~~~~~,~t .'mN' , v v "'''''''U,,,,'vA ,. W \\. """... V V\ ""..m V V ,w,,,, ,... V "M.m' v,-" h. ,1'1;, " I, ~~~,~~~~g&~~SS vv "".,' \. ..v ~ VIA'''' , \. \1. ." 'm'" V. SERVICE COMPANY - SERVICE /-ÍALL¡BU)~TON ,mm"'..N N ,. . 'N , M .. v v "v>'w"'...N DAILY COST CUMUL TOTAL mN " """'''$1 :635w " '.' w,'" $3,59'7 $'1 ;'635"" . $3;"5"9Y- ....--- - ....-.''''''-- .~. -~-~...."- _.~_.._. ....,_.~.... --'-~'---"'~~"""""""'----"._,,"' ._n --,,, TOTAL FIELD ESTIMATE: http://apps-alaska.bpweb.bp .com! sst- drilling- wells/well- events_query Iwelleven t_a w gs. asp... 9/23/2002 ) ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 7/26/2002 AFE BRD5M4087 JOB SCOPE NEW WELL POST DAILY WORK MIT-IA; MIT-T KEY PERSON LRS-WIGHT MIN ID 0" DEPTH 0 FT UNIT LRS 60 DAY SUPV JACKSON NIGHT SUPV TTL SIZE 0" I DAILY SUMMARY MIT Combo Tubing/IA Init-> Vac BPM B^BLs F:bUII?,.., TEMP, v TB,G, 0 IA TII\II,I; 10:15 '"^ 11':00'" " .^ w^ ^ 1''1^ :'2'1 M v'v"''''^",,, m^ '0"'" "v, v". "" ."Õ~'V""''''^V5õí50''. .,.,,,, ""7Õ^VF". ., r .,,"~, "^ Õ' .Æ ^ 0 '^ 1'1:26'''v '0 fff"^^ M M. v'" "..2500 .." 2500. 12:02 12:09 , 12:25 0 0 325 OA COMMENTS M ",.,.,'Öper PerÎTI,~' ~^ sPq~,".,:, ,~,. . ""v Arr Loc MIRU PGSM PT Surface Lines '^ 3?QÖp~~^tölÃ ~ëa~Q'Pü:m~p!~9^ ""~~" :":~'~:,MW'N"V 320 @ Test Pressures, Shut Down and Monitor Start Bleeding Down--Combo Test Passed 325 Finished Bleeding, Shut in well Start Rig Down Leave Loc. Move to W-37 325'" ... ..............,......,..........,............."."'. .....A...... "...'''.....FïrÏaï:;.~...'..'.-o''..... 0 IM~~~!~~.~~~~r~Õ75Õ.vMëth.intô^ IÄ,n".,,, ',V"M^ ^ "^",,,,'W,"'^^^, ".'''''MM"."""mm ^ "Y'nM~ "",\N\".." """'WllI" M...../." v V VVV\\."'.."... ".... W'''''''''^ "'^",, '"'' SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL I.if'TLËM'ÃËÖ,,,,,,,,,,.,,,,,,,^,^,,,wm, """w^",m^,,,^ "M"'^." "".'^,''',"',"W''N''''''^, "'Mmv^W"".","WMM w "v^ ""'^ ",.,,,,,W"^"'^"""W"WNN^^ ^^ ^ .. ..."VM "...W.vM"M^ ^ ,,,,,^,,,,,,wM$613. W""""^...'..H .,^'. "......" '''''$EFf§m UN^KNOWN .....~ '^ '^' . '$25 ' uW$2S" VEca . $0 $480 . TOT Áï~"'Fï'E"['tj""E'S'T"ïM'Ä T'E':""~" ......." .. ""$63'£f' . ""'$1'~1'''f8'' http://apps-alaska.bpweb.bp.comlsst_drilling- wells/well_events_query /wellevent_awgs.asp... 9/23/2002 ') ) Page 1 of 1 WELL SERVICE REPORT WELL L-108 DATE 7/26/2002 AFE BRD5M4087 JOB SCOPE NEW WELL POST DAILY WORK AC-CMIT TXIA KEY PERSON VEC-REA MINID 0 " I DEPTH 0 FT UNIT UNKNOWN DAY SUPV YEAGER NIGHT SUPV TTL SIZE 0 " I DAILY SUMMARY CMIT T X IA to 2500 psi PASSED. (Possible Packer Leak). Init Tbç¡, lA, OA -> I V AC I TIME COMMENT , 12:30 T/lï6'=VAC/Ò+/320. CMIT T X IA to 2500 ps¡wPA'Š.SED. (Possible Packer Leãk). Initial TBG FL near surlace. ÎA FL near surlace. RU LRS to IA. PT line to 3000 psi. Pressured TBG and IA to 2510/2500 psi with 1.8 bbls of 50/50 methanol. TBG lost 50 psi and IA lost 50 psi in first 15 minutes and TBG lost 10 psi and IA lost 10 psi in second 15 Fin~i.f~:~ï"~\5Ã~::11 ~f T~~.IO P~~~160 £s61~-~9_.~!~.~!~~:..~le_q_!,,?G ~n.9,..I~_Þ.~.9.~..!~.Q~.£?i. Fi.~~.y'vHp1s=:=_~+/0~~~29.~_..- 0+ I 320 I I FLUID SUMMARY Pumped 1.8 bbls of methanol down IA. SERVICE COMPANY - SERVICE VEca UNKNOWN UTTLE RED ..." . DAILY COST CUMULTOTAL ... . ..m.......... ....... . .... ....~.... TOTAL FIELD ESTIMATE: $480 $0 $0 $480 $480 $25 $613 m$1,118 http://apps-alaska.bpweb.bp.com/sst_drilling- wells/well_events_query /wellevent_awgs.asp... 9/23/2002 BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294,0 (ft) Casing Size: 7,000 (in) Costs in: USD Est. TVD: 7,040.0 (ft) Casing (MD): 8,279.0 (ft) Daily Mud: 1,140 Progress: (ft) Next Casing Size: (in) Cum, Mud: 209,119 Auth Depth: 8,366,0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 270,154 Hole Size: 8.750 (in) Next Casing (TVD):7,037.0 (ft) Cum. Well: 2,637,160 DOUDFSlTarget: 16.90116,45115,50 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Current Status: 24hr Summary: 24hr Forecast: Comments: t~ FRANKS MASKELUABBOTT Days Since Last DAFWC: 1323 Last Csg Test Press,: 3,500 (psi) Last BOP Press. Test: 612912002 Next BOP Press, Test: 71612002 Last Divertor Drill (D3): 511412002 No. Stop Cards: FIRE: TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min,: RPM DH: Torq, on Bottom: Torq, off Bottom: r~ Type: TimelLoc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: 71312002 (ft) 12.25 (ppg) (psi) (psi) (ppg) (bbl) WATERlBRINE : 1 8,294,0 (ft) CF) 9,10 (ppg) 28 (slqt) (ppg) (cp) (lbl10OO2) From-To Hrs Phase Task Op. Depth (hr) 00:00-02:00 2.00 COMP WHSU 8,294 02:00-03:30 1,50 COMP WHSU 8,294 Last Envir. Incident: Last Accum. Drill (D4): 6/2312002 Last Spill Drill: 714/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)612412oo2 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O,OO (hr) Cum. Bit Hrs: Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ, Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 33 (hr) Drilling Fluid (lbl100ft2) Ca: (lbl100ft2) K +: (ccl30min) CaCI2: (OF) NaCI: (ccI30min) CI-: (132") Sand: (ppb) HGS: (ppb) LGS: (mL) PflMf: Ann, Vel. Riser: (fUmin) Ann. Vel. DC: (fUmin) Ann. Vel. DP: (fUmin) 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity Operations Summary Code NPT CIR WAIT N DFAL Page 1 of 2 Report: 18 Date: 7/412002 Rig Accept: 01 :30 611812002 Rig Release: 7/412002 Spud Date: 611812002 WX Date: Elev Ref: KB Elev: 78,40 (ft) Tot. Personnel: 31 Cost Ahead 25 USD, Days Ahead -1.00 CLEAR 42 DEG, WIND 10 MPH Non-compliance Issued: N SEA LEVEL 71412002---- 71112002 71412002 Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate pressureO Stroke Rate PressureO Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 000 0 (mglL) (mglL) (%) (%) 74,000 (mg/L) (%) (ppb) (ppb) 1 (mUmL) ES: Solids: Oil: Water: OilfWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: Program: Weather: RELEASED RIG @2400 HRS, 7-4-02, MOVE TO L-105i. PULL RP SHEAR FREEZE PROTECT. RID RR 2400 HRS MO. MO RU & SPUD L-105, NO INCIDENTS, NO INJURIES, NO SPILLS. HSE & Well Control All Free Days: 17 3116/2001- -Cá"sTH2S-Dnfl:- Last Trip Drill (D1): Last Safety Meeting: PULLED TWC. HAD 700 PSI ON IT. BLED TBG TO O. NO PRESSURE ON ANNULUS, RlU & CIRC DOWN ANNULUS & UP TBG, OK. SWITCHED TO PUMP DOWN TBG & OUT ANNULUS. STARTED TO CIRCULATE, THEN PRESSURED UP, RP SHEAR APPEARS TO GO BACK ON SEAT & ACT AS A CHECK VALVE. PJSM. RID CIRC LINES. DRAIN UP PUMP & EQUIP.. SUCK OUT FLUID IN MUD PITS. WAIT ON SLlCKLlNE Operation (mV) (%) (%) 94,0 (%) 1 (bbl) (bbl) (bbl) (bbl) Printed: 7/512002 6:34:39 AM Activity BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL+COMPLETE Well Type: DEVELOPMENT Operations Summary Code NPT Page 2 of2 Report: 18 Date: 7/4/2002 Operator. BP EXPLORATION Well: L-108 Field: BOREALIS RlU TO PULL RP SHEAR VALVE, RIH & ATTEMP TO RECOVER, MISS-RUN. POOH. DPRB M/U NEW TOOL, RIH & PULL RP SHEAR VALVE. POOH WI SAME. RID SLlCKLlNE EQUIP. RlU HOT OILER. TEST LINES TO 3000 PSI, OK. PUMP 87 BBLS DIESEL DOWN ANNULUS FOR FREEZE PROTECTION. SID & RlU & ALLOW DIESEL TO U-TUBE.. RID CIRC LINES. RlU DSM & INSTALL BPV IN TBG HANGER. TEST SAME TO 1000 PSI,OK. SECURE TREE & CLEAN UP CELLAR AREA.. MOVE OUT PIT COMPLEX AWAY FROM RIG FOR ACCESS TO L-106. RID RIG. DO MAINTAINANCE ON EQUIP. REMOVE ROTARY TABLE & INSPECT TRACTION ON TD, CHECK BEARING ETC, PRESSURE WASH DERRICK. RlU & WIRELlNE ON L-106 PRIOR TO MOVE ON, SET PLUG IN "X" NIPPLE. BLOW DOWN WELL TO LINE PRESSURE, RELEASE RIG @ 2400 HRS, 7-4-02. MOVE OFF TO L-105, MOVE OFF L-108. MOVE TO L-105, RIG RELEASED@ 2400 HRS, 7-4-02. Mud Log Information I Form, Top MD. (ft) I Bkgrnd Gas Conn. Gas Materials I Consumption Usage On Hand Item 0 4968 BARITE 0 494 Personnel No. Hours Company No. Hours Company 2 12.00 BAROID 2 12.00 NABORS 23 12.00 ANADRILL SCHLUMBERGER 2 Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total From-To Op. Depth 03:30-08:30 8,294 08:30-10:00 8,294 10:00-12:30 8,294 12:30-14:00 8,294 .- 14:00-15:00 8,294 15:00-16:00 8,294 16:00-00:00 8,294 Formation MILUVICH Uthology DIESEL BARITE BP NABORS -, Phase PRE SURF PROD1 COMP TOTALS Operation Hrs Phase Task (hr) 5.00 COMP WHSU CMPSTG N DFAL PJSM, RIU SLlCKLlNE EQUIP. RIH & CATCHER@4741'. POOH. 1.50 COMP WHSU CMPSTG N 2,50 COMP WHSU CMPSTG N 1,50 COMP WHSU FREEZE P 1.00 COMP WHSU XTREIN P 1.00 COMP WHSU XTREIN P 8.00 COMP SANDO P (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) Item Units GAL SACKS Usage On Hand 0 5 Units TON Company No. ¡ Hours 2' 12,00 Prod % Total 3,50 100,0% 69.33 66.7% 132.00 100.0% 129.50 76.9% 334.33 81.9% Total Hours 3.50 104.00 132.00 168.50 408.00 Total Cost USD 30,215.00 692,935,26 736,463.25 1,135,471.9 2,595,085.4 34,67 33.3% 39.00 23.1% 73.67 18.1% 0.00 0.0% 0.00 0.0% Remarks 0.00 0,0% 0.00 0.0% Printed: 7/5f2oo2 6:34:39 AM , BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294,0 (ft) Casing Size: 7,000 (in) Costs in: USD Est. TVD: 7,040,0 (ft) Casing (MD): 8,279.0 (ft) Daily Mud: 3.466 Progress: (ft) Next Casing Size: (in) Cum. Mud: 207,979 Auth Depth: 8,366,0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 288.400 Hole Size: 8.750 (in) Next Casing (TVD):7,037.0 (ft) Cum, Well: 2,367,006 DOUDFSlTarget 15,90/15A5/15.50 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Current Status: 24hr Summary: 24hr Forecast: Comments: FRANKS MASKELUABBOTT Program: Weather: PULL TWC HUNT LEAK IN COMPLETION - NO GO. NO, NU. FP PULL RP SHEAR. FREEZE PROTECT. RDMO. NO INCIDENTS. NO INJURIES. NO SPILLS. HSE & Well Control All Free Days: 3/16/2001 .--- Days Since Last DAFWC: 1322 -Last Csg Test Press,: 3,500 (psi) Last BOP Press. Test: 6/29/2002 Next BOP Press, Test: 7/612002 Last Divertor Drill (D3): 5/14/2002 No. Stop Cards: FIRE: TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min,: RPM DH: Torq, on Bottom: Torq. off Bottom: -- Type: Time/Loc: Depth: Temp: Density: Funnel Visc,: ECD: PV: YP: pH: (ft) 12.25 (ppg) (psi) (psi) (ppg) (bbl) WATER/BRINE 23:00/ 8,294.0 (ft) ("F) 9.10 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) Last Envir. Incident: 7/3/2002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 7/312002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)6/24/2oo2 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Rotating Weight: Pick Up Wt.: Slack Off WI.: Circ, Rate Riser: Circ, Rate Hole: Circ. Off Bottom: Circ, On Bottom: Jar Hrs since Inspect: 33 (hr) Drillin9 Fluid (lb/100ft2) Ca: (lb/10OO2) K +: (cc/30min) CaCI2: ("F) NaCI: (ccI30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: From-To Hrs Phase Task Activity - Op. Depth (hr) 00:00-02:00 2,00 COMP RUNCO CMPSTG 8,294 02:00-05:30 3,50 COMP RUNCO CMPSTG 8,294 05:30-06:00 0,50 COMP RUNCO TSTPRS 8,294 06:00-07:00 1,00 COMP RUNCO CMPSTG 8,294 RUN #2 MlU "XX" PLUG, RIH TO 7527' & ATTEMPT TO SET. PLUG PARTIALLY SHEARED. (MISS RUN) POOH WI PLUG. RUN #3 INSPECT & REDRESS PLUG. RIH & SET IN "X" NIPPLE @ 7527'. POOH, PRESSURE UP ON TBG & ATTEMPT TO TEST, PRESSURE BLED OFF FROM 4000 PSI TO 1000 PSI IN 10 MIN. RUN #4 RIH ON SLlCKLlNE & SET CATCHER @ 5441' Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O,OO (hr) Cum. Bit Hrs: Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vel. DP: (ftImin) Operations Summary Code NPT N DFAL N DFAL N DFAL N DFAL Page 1 of 3 Report: 17 Date: 7/3/2002 Rig Accept: 01 :30 6/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL KB Elev: 78AO (ft) Tot. Personnel: 31 Cost Ahead 0 USD, Days Ahead -1.00 CLEAR 35 DEG, WIND 5 MPH 16 --~--- ---- ---~~ Last Trip Drill (D1): Last Safety Meeting: 7/1/2002 7/3/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 (mg/L) (mg/L) (%) (%) 74,000 (mg/L) (%) (ppb) (ppb) I (mUmL) (mV) 6.00 (%) (%) 94.0 (%) I (bbl) (bbl) (bbl) (bbl) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Suñace: Operation Prinled: 7/412002 6:47:15 AM Activity BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL+COMPLETE Well Type: DEVELOPMENT Operations Summary Code NPT Page 2 of 3 Report: 17 Date: 7/3/2002 Operator: BP EXPLORATION Well: L-108 Field: BOREALIS -.:~ 19:30-20:00 0,50 COMP RUNCO TSTPRS P 8,294 20:00-21 :30 1.50 COMP BOPSU NO P 8,294 21 :30-23:00 1,50 COMP WHSU NU P 8,294 23:00-00:00 1,00 COMP WHSU INSTAL P 8,294 From-To Hrs Phase Task Op, Depth (hr) 00:00- 0,00 COMP WHSU BLEED OFF TBG PRESSURE & CHECK SHEAR VALVE BY PUMPING IN BOTH DIRECTIONS, SHEAR VALVE MALFUNCTION, ACTING LIKE CHECK VALVE. RlU SLlCKLlNE TO PULL RP SHEAR. Mud Log Information Form, Top MD. (ft) Bkgmd Gas Conn. Gas Materials ¡Consumption Usage On Hand Item 1299 4968 BARITE 0 494 Personnel No. Hours Company No. Hours Company 2 12,00 BAROID 2 12.00 NABORS 23 12,00 ANADRILL SCHLUMBERGER 2 Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total From-To Op. Depth 07:00-08:30 8,294 08:30-09:30 8,294 09:30-10:30 8,294 10:30-11:00 8,294 11 :00-19:30 8,294 Formation MILUVICH Uthology DIESEL BARITE .~- BP NABORS Phase PRE SURF PROD1 COMP TOTALS Hrs Phase Task (hr) 1,50 COMP RUNCO CMPSTG Operation N DFAL RUN #5 RIH & RETRIEVE UPPER DUMMY VALVE @ 4825', POOH, CHANGE OUT DUMMY VALVE. RUN #6 RIH & ATTEMPT TO INSTALL DUMMY (MISS RUN). POOH. CHANGE OUT DUMMY VALVE RUN #7, RIH & SET DUMMY IN UPPER GLM @ 4825'. PRESSURE UP ON TBG & ATTEMPT TO TEST TO 4000 PSI. NO GOOD BLED OFF AS BEFORE. RUN #8 RIH & RETRIEVE DUMMY VALVE @ 4867', POOH, CHANGE OUT DUMMY VALVE, RIH & SET DUMMY @ 4867', ATTEMPT TO TEST TBG TO 4000 PSI, NO GOOD, RIH & RECOVER CATCHER. M/U 41/2" "XX" PLUG RIH & SET IN "X" NIPPLE @ 4758', PRESSURE UP ON TBG & TEST TO 4000 PSI, 10 MIN OK. POOH & RID SLlCKLlNE EQUIP. PER DISCUSSION WITH ANCH OFFICE & NSPE'S, WILL MOVE OFF FOR PE GROUP TO RUN ADDITIONAL DIAGNOSTICS FOR LEAK DETECTION, INSTALL TWC VALVE & PRESSURE TEST TO 2800 PSI, OK. 1,00 COMP RUNCO CMPSTG 1,00 COMP RUNCO CMPSTG 0.50 COMP RUNCO TSTPRS 8,50 COMP RUNCO CMPSTG N DFAL N DFAL N DFAL N DFAL N/D & SET BACK BOPE. N/U & TEST ADAPTER FLANGE & XMAS TREE, TEST TO 5000 PSI -OK. RlU DSM & PULL TWC, (700 PSI ON TBG) Activity 06:00 Update NPT Operation Code (ppm) ¡Trip Gas (ppm) Pore. Press (ppm) (ppg) Item Units GAL SACKS Usage On Hand 0 5 Units TON Company No, : Hours 2, 12.00 Prod % Total 3,50 100,0% 69.33 66,7% 132,00 100,0% 118,00 80,5% 322,83 83,6% Total Total Cost Hours USD 3,50 30,215,00 104,00 692,935.26 132.00 736,216.25 146,50 865,564,90 386,00 2,324,931,4 34,67 33.3% 28,50 19,5% 63.17 16,4% 0,00 0.0% 0,00 0,0% Remarks 0,00 0,0% 0.00 0,0% Printed: 7/412002 8:47:15 AM Operator: BP EXPLORATION Well: L-108 Field: BOREALIS BP EXPLORATION Dai Iy Operations Report Rig: NABORS 9ES 9-ES Event DRILL +COMPLETE Well Type: DEVELOPMENT Remarks '~I -- Page 3 of 3 Report: 17 Date: 7/3f2002 Ponted: 7/412002 8:47:15 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL+COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294,0 (ft) Casing Size: 7.000 (in) Costs in: USD Est. lVD: 7,040.0 (ft) Casing (MD): 8,279,0 (ft) Daily Mud: 1,140 Progress: (ft) Next Casing Size: (in) Cum. Mud: 204.513 Auth Depth: 8,366,0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 61,225 Hole Size: 8.750 (in) Next Casing (TVD):7,037.0 (ft) Cum, Well: 2,076,280 DOUDFSlTarget: 14,90/14,45/15,50 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-108 Field: BOREALIS FRANKS MASKELUABBOTT Program: Weather: Page 1 of 2 Report: 16 Date: 7/2/2002 Rig Accept: 01:306/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL KB Elev: 78,40 (ft) Tot. Personnel: 29 Cost Ahead 50,000 USD, Days Ahead 0,00 CLEAR 35 DEG, WIND 5 MPH Current Status: POH WITH ROD & BALL 24hr Summary: RUN COMPLETION, SET PKRS. NO TEST. R/U SLlCKLlNE PULL ROD/BALL 24hr Forecast: SET PLUG, ATTEMPT TO ISOLATE LEAK. Comments: NO INCIDENTS, NO INJURIES. NO SPILLS, HSE & Well Control All Free Days: 15 3/16/2001 Days Since Last DAFWC: 1321 Last Csg Test Press,: 3,500 (psi) Last BOP Press, Test: 6/29/2002 Next BOP Press, Test: 7/6/2002 Last Divertor Drill (03): 5/14/2002 No, Stop Cards: FIRE: TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq, off Bottom: -~ Type: Time/Loc: Depth: Temp: Density: Funnel Visc,: ECD: PV: YP: pH: 7/2/2002 (ft) 12.25 (ppg) (psi) (psi) (ppg) (bbl) WATER/BRINE 22:00/ 8,294,0 (ft) (OF) 9.10 (ppg) 28 (s/qt) (ppg) (cp) (lb/100ft2) Last Envir. Incident: Last Accum, Drill (04): 6/23/2002 Last Spill Drill: 7/212002 Regulatory Agency Insp: N KICK WHILE DRILL (02)6/24/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO / Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum, Bit Hrs: Rotating Weight: Pick Up Wt.: Slack Off Wt: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 33 (hr) Drilling Fluid (lb/100ft2) Ca: (lb/100ft2) K +: (cc/30min) CaCI2: ("F) NaCI: (ccI30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: Ann, Vel. Riser: (fUmin) Ann. Vel. DC: (fUmin) Ann. Vel. DP: (fUmin) 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity Operations Summary Code NPT From-To Hrs Phase Task Op. Depth (hr) 00:00-13:00 13.00 COMP RUNCO CMPSTG 8,294 Last Trip Drill (01): Last Safety Meeting: 7/1/2002 7/212002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureD Pump Status - Drilling and Riser Pump Type Eff, Strokes Liner Size Circ, Rate 0 0 0 0 (mg/L) (mg/L) (%) (%) 74,000 (mg/L) (%) (ppb) (ppb) 1 (mUmL) (mV) 6,00 (%) (%) 94,0 (%) 1 (bbl) (bbl) (bbl) (bbl) ES: Solids: Oil: Water: Oil/Water: Daily Cuttings: Cum, Cuttings: Lost Downhole: Lost Surface: Operation MIU TAIL PIPE ASSY & RIH, RIH W/3 1/2" 9.2" & 41/2" 12.6# L-80 TCII TBG,RAN 88 JTS 31/2" & 119 JTS 41/2" TBG, MIU @ 2200 & 2900 FT/LBS TORQUE RESPECTIVELY, SEE TBG DETAIL REPORT, MIU TBG HANGER ON LANDING JT. R/U CIRCULATING LINES, RUN IN & VERIFY HANGER SEAT. PIU ABOVE TABLE. P 13:00-14:00 1.00 COMP RUNCO LANDTH 8,294 P i'" '// ~- Printed; 7/312002 5;55;10 AM Hrs Phase Task (hr) 1.50 COMP RUNCO BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL+COMPLETE Well Type: DEVELOPMENT Operations Summary Code NPT Page 2 of 2 Report: 16 Date: 7f2f2002 Operator: BP EXPLORATION Well: L-108 Field: BOREALIS From-To Op, Depth 14:00-15:30 8,294 15:30-16:00 8,294 16:00-20:00 8,294 Activity Operation CIR P REVERSE CIRCULATE CLEAN 9.1 PPG KCL WI COREXIT @ 3 BPM, 3200 PSI. LAND TBG HANGER RILDS, 0,50 COMP RUNCO LANDTH P L.~ 20:00-00:00 4.00 COMP RUNCO CMPSTG 8,294 DROP BALL & ROD, RID CIRC LINES, BACK OUT LANDING JT. PRESSURE UP TO 4200 PSI TO SET PACKERS. TBG LEAKING OFF. ATTEMPT TO FIND LEAK - NO SURFACE LEAKS OR FLUID FROM IA. RE-PRESSURE TUBING TO 4200 PSI AND MAINTAN PRESSURE WITH RIG PUMP TO ENSURE BOTH PACKERS SET. . HAVING TO PUMP 2-3 SPM TO MAINTAIN APPROX~2oo PSI FOR c 10-15MIN. POSS INJ MÁNDREL LEAKING. PRESSURE UP-ON BACKSIDE & TEST ANNULUS TO 1500 PSI. HELD 30 MIN - OK, VERIFIES PREMIER PACKER SET, CALL FOR SLlCKLlNE EQUIP, WAlTON EQUIP. HOLD PJSM, RlU HALLIBURTON SLlCKLlNE EQUIP, RIH WI OIS TO RETRIEVE BALUROD. ROD ON DEPTH @ 7548', POOH WI SAME, RECOVER BALUROD, MIU "X" NIPPLE PLUG & RIH TO SET, WOULD NOT SHEAR (MISS RUN) POOH & INSPECT SAME. RE-RUN & SET SAME IN X NIPPLE - OK. N DFAL 4,00 COMP RUNCO PKRST N DFAL DIESEL BARITE Units GAL SACKS Mud Log Information I Form. Top MD, (ft) I Bkgrnd Gas Conn, Gas Materials I Consumption Usage On Hand Item 1143 6267 BARITE ° 494 Personnel Company (ppm) TriP Gas (ppm) Pore. Press (ppm) (ppg) Formation MILUVICH Lithology Item Units TON Usage On Hand 0 5 Company No. Hours 2 12,00 BAROID 23 12.00 No. Hours Company 2 12,00 NABORS No. Hours 2 12,00 BP NABORS Phase PRE SURF PROD1 COMP TOTALS Prod % Total 3,50 100,0% 69.33 66.7% 132,00 100,0% 113.50 92,7% 318.33 87,9% Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0,00 0,0% Total Hours 3.50 104,00 132,00 122.50 362.00 Total Cost USD . 30,215.00 692,935.26 719,700,25 608,842.90 2,051,693.4 34,67 33,3% 9.00 7.3% 43,67 12,1% 0,00 0,0% 0,00 0.0% Remarks 0,00 0,0% -- Printed: 7/312002 5:55:10 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8.294.0 (ft) Casing Size: 7,000 (in) Costs in: USD Est. TVD: 7,040,0 (ft) Casing (MD): 8,279,0 (ft) Daily Mud: 1,140 Progress: (ft) Next Casing Size: (in) Cum, Mud: 204,513 Auth Depth: 8,366,0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 61,225 Hole Size: 8.750 (in) Next Casing (TVD):7,037.0 (ft) Cum, Well: 2,076,280 DOUDFSfTarget: 14.90/14,45/15.50 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-108 Field: BOREALIS FRANKS MASKELUABBOTT Page 1 of2 Report: 16 Date: 7/2/2002 Rig Accept: 01:306/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 78,40 (ft) Tot. Personnel: 29 Cost Ahead 50,000 USD, Days Ahead 0.00 CLEAR 35 DEG, WIND 5 MPH Current Status: POH WITH ROD & BALL 24hr Summary: RUN COMPLETION, SET PKRS, NO TEST, R/U SLlCKLlNE PULL ROD/BALL 24hr Forecast: SET PLUG, ATTEMPT TO ISOLATE LEAK. Comments: NO INCIDENTS. NO INJURIES. NO SPILLS. HSE & Well Control All Free Days: 15 3/16/2001 Days Since Last DAFWC: 1321 Last Csg Test Press.: 3,500 (psi) Last BOP Press. Test: 6/29/2002 Next BOP Press. Test: 7/6/2002 Last Divertor Dñll (03): 5/14/2002 No, Stop Cards: FIRE: ~- TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq, oft Bottom: Type: Time/Loc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: (ft) 12.25 (ppg) (psi) (psi) (ppg) (bbl) WATER/BRINE 22:00/ 8,294,0 (ft) (OF) 9,10 (ppg) 28 (s/qt) (ppg) (cp) (lb/100ft2) Last Envir. Incident: Last Trip Drill (01): Last Safety Meeting: 7/1/2002 7/212002 7/212002 Last Accum. Drill (04): 6/23/2002 Last Spill Drill: 7/212002 Regulatory Agency Insp: N KICK WHILE DRILL (02)6/24/2002 Pump Slow Pump Rates (Circ) Stroke Rate Pressure() Non-compliance Issued: N Rotating Weight: Pick Up WI.: Slack Off Wt.: Circ, Rate Riser: Circ. Rate Hole: Circ, Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 33 (hr) Drilling Fluid (lb/100ft» Ca: (lb/100ft2) K+: (ccl30min) CaCI2: ("F) NaC!: (ccl30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: From-To Hrs Phase Task Op, Depth (hr) 00:00-13:00 13,00 COMP RUNCO CMPSTG 8,294 Activity 13:00-14:00 1.00 COMP RUNCO LANDTH 8,294 Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate Pressure() Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum, Bit Hrs: Pump Status - Drilling and Riser Pump Type Eft, Strokes Liner Size Circ, Rate 0 0 0 0 Ann, Vel. Riser: (fUmin) Ann, Vel. DC: (fUmin) Ann. Vel. DP: (fUmin) (mg/L) (mg/L) (%) (%) 74,000 (mglL) (%) (ppb) (ppb) 1 (mUmL) (mV) 6,00 (%) (%) 94,0 (%) / (bbl) (bbl) (bb!) (bbl) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum, Cuttings: Lost Downhole: Lost Surface: Operations Summary Code NPT Operation P MIU TAIL PIPE ASSY & RIH, RIH W/3 1/2" 9,2" & 41/2"12,6# L-80 TCII TBG,RAN 88 JTS 31/2" & 119 JTS 41/2" TBG, M/U @ 2200 & 2900 FT/LBS TORQUE RESPECTIVELY, SEE TBG DETAIL REPORT. MIU TBG HANGER ON LANDING JT. R/U CIRCULATING LINES. RUN IN & VERIFY HANGER SEAT. P/U ABOVE TABLE. P Printed: 7/312002 5:55:10 AM Hrs Phase Task (hr) 1.50 COMP RUNCO BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Operations Summary Code NPT Page 2 of 2 Report: 16 Date: 7{2/Z00Z Operator: BP EXPLORATION Well: L-108 Field: BOREALIS From-To Op, Depth 14:00-15:30 8,294 15:30-16:00 8,294 16:00-20:00 8,294 Activity Operation CIR P REVERSE CIRCULATE CLEAN 9.1 PPG KCL WI COREXIT @ 3 BPM, 3200 PSI. LAND TBG HANGER RILDS. 0.50 COMP RUNCO LANDTH P ~- 20:00-00:00 4,00 COMP RUNCO CMPSTG 8,294 DFAL DROP BALL & ROD, RID CIRC LINES, BACK OUT LANDING JT, PRESSURE UP TO 4200 PSI TO SET PACKERS. TBG LEAKING OFF. ATTEMPT TO FIND LEAK- NO SURFACE LEAKS OR FLUID FROM IA. RE-PRESSURE TUBING TO 4200 PSI AND MAINTAN PRESSURE WITH RIG PUMP TO ENSURE BOTH PACKERS SET. HAVING TO PUMP 2-3 SPM TO MAINTAIN APPROX 4200 PSI FOR 10-15 MIN, POSS INJ MANDREL LEAKING. PRESSURE UP ON BACKSIDE & TEST ANNULUS TO 1500 PSI. HELD 30 MIN - OK. VERIFIES PREMIER PACKER SET. CALL FOR SLlCKLlNE EQUIP. WAIT ON EQUIP, DFAL HOLD PJSM. RlU HALLIBURTON SLlCKLlNE EQUIP, RIH WI OIS TO RETRIEVE BALUROD, ROD ON DEPTH @ 7548', POOH WI SAME. RECOVER BALUROD. MIU "X" NIPPLE PLUG & RIH TO SET, WOULD NOT SHEAR (MISS RUN) POOH & INSPECT SAME. RE-RUN & SET SAME IN X NIPPLE - OK. N 4,00 CaMP RUNCO PKRST N DIESEL BARITE Units GAL SACKS Mud Log Information Form, Top MD. (ft) Bkgmd Gas Conn, Gas Materials / Consumption Usage On Hand Item 1143 6267 BARITE 0 494 Personnel Company (ppm) ¡Trip Gas (ppm) Pore. Press (ppm) (ppg) Formation MILUVICH Uthology Item Units TON Usage On Hand ° 5 Company No. Hours 2 12.00 BAROID 23 12.00 No, Hours Company 2 12,00 NABORS No. ¡ Hours 2 ¡ 12.00 BP NABORS Phase PRE SURF PROD1 COMP TOTALS Prod % Total 3,50 100,0% 69.33 66.7% 132,00 100.0% 113.50 92.7% 318,33 87,9% Cumulative. Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0,00 0,0% Total Total Cost Hours USD 3.50 30,215,00- 104.00 692,935,26 132,00 719,700.25 122.50 608,842.90 362.00 2,051,693,4 34,67 33,3% 9.00 7.3% 43.67 12.1% 0,00 0.0% 0.00 0.0% Remarks 0,00 0.0% ~--' Printed: 7/312002 5:55:10 AM ~ BPEXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL+COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294.0 (ft) Casing Size: 7,000 (in) Costs in: USD Est TVD: 7,040.0 (ft) Casing (MD): 8,279.0 (ft) Daily Mud: 14,808 Progress: (ft) Next Casing Size: (in) Cum, Mud: 203,373 Auth Depth: 8,366.0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 177,299 Hole Size: 8,750 (in) Next Casing (TVD):7,037.0 (ft) Cum, Well: 2,015,055 DOUDFSlTarget: 13.90/13.45/15.50 Geologist: STEARNS/BICKER Engineer: FRANKS Supervisor: DECKER/ABBOTT Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Current Status: 24hr Summary: 24hr Forecast: Comments: Page 1 of 3 Report: 15 Date: 7I1f2002 Rig Accept: 01 :30 6/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 78.40 (ft) Tot Personnel: 29 Cost Ahead 0 USD, Days Ahead 0,50 RAIN/SNOW 35 DEG, WIND 25 MPH RUNNING COMPLETION PERFORATE, MAKE CLEAN OUT RUN, POH & UD DRILL STRING, RUN COMPLETION, RUN & LAND COMPLETION, N/D,N/U , FREEZE PROTECT, RDMO, NO ACCIDENTS, NO INCIDENTS, NO SPILLS HSE & Well Control All Free Days: 14 3/16/2001 Days Since Last DAFWC: 1320 Last Csg Test Press,: 3,500 (psi) Last BOP Press, Test: 6/29/2002 Next BOP Press, Test: 7/6/2002 Last Divertor Drill (D3): 5/14/2002 No, Stop Cards: FIRE: ~ TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min,: RPM DH: Torq. on Bottom: Torq, off Bottom: -~ Bit Run # 6 5 Cum Prog(ft) (ft) 12.25 (ppg) (psi) (psi) (ppg) (bbl) 6/30/2002 Last Envir. Incident: Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 6/29/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)6/24/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Rotating Weight: Pick Up Wt: Slack Off Wt: Circ. Rate Riser: Circ, Rate Hole: Circ. Off Bottom: Circ, On Bottom: Jar Hrs since Inspect: 33 (hr) Re-Run Size (in) Manuf. Y 6,125 Hughes Y 6,125 Hughes RPM MiniMax WOB MiniMax / / / / Type AT J-4 ATJ-4 Daily Hrs Bha No: 6 Depth In: 8,194.0 Bha Type: CLEAN OUT Depth Out: 8,194.0 Component Component Detail Jts BIT SUB SUB MILL SUB COLlAR SUB HWDP JAR HWDP BIT JUNK BASKET JUNK BASKET MILL - WATER MELON BIT SUB DRILL COLlAR XO HWDP JAR HWDP 3 18 Last Trip Drill (D1): Last Safety Meeting: 7/1/2002 7/1/2002 Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Non-compliance Issued: N Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum, Bit Hrs: Ann, Vel. Riser: (fUmin) Ann. Vel. DC: (fUmin) Ann. Vel. DP: (fUmin) Bits Serial # G82JL i G82JL Cum Hrs ¡ Nozzles ¡ /1/1/1 I 18/18/18/1/1 Cum ROP Length (ft) 0,60 4.51 4.51 3,35 2,94 274.91 1,37 92,08 29.94 552,50 BHA Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 0,60 6,125 5,11 5.000 1,500 9.62 5,000 1,500 12,97 6.125 1,250 15.91 4.750 290,82 4.750 2,250 292,19 4,750 2,380 384.27 4,000 2,620 414.21 4.750 2,250 966.71 4,000 2.620 Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 ~ I ~ I TFA (in2) Depth In (ft) 8,294,0 0.746 8,194,0 Condition I I Depth Out (ft) 8,294.0 8,194,0 Blade OD Bend Angle (in) n Connection Size (in) Type P/B Printed: 7/212002 9:01:08 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Drilling Fluid (lb/100fF) Ca: (lb/100ft2) K +: (ccl30min) CaCI2: ("F) NaCI: (ccl30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: Page 2 of 3 Report: 15 Date: 7{1(2002 Operator: BP EXPLORATION Well: L-108 Field: BOREALIS (mg/L) (mglL) (%) (%) (mglL) (%) (ppb) (ppb) I (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum, Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) (%) I (bbl) (bbl) (bbl) (bbl) 1° see gels: 1 ° min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Type: Time/Lac: Depth: Temp: Density: Funnel Vise,: ECD: PV: YP: pH: : I 8,294,0 (ft) ("F) (ppg) (s/qt) (ppg) (ep) (lb/100ft') Operations Summary Code NPT Operation Activity Hrs Phase Task (hr) 1,00 COMP PERF From-To Op, Depth 00:00-01 :00 8,294 01 :00-03:00 8,294 CON'TTO RIH WI PERF GUN ASSY @ 1 STAND/MIN. P RIH PJSM, RlU SCHLUMBERGER RIH WI GRlCCL & CORRELATE DEPTH WI PERF GUNS, PERFORATE 4958-5006', 5042-5080', 5096-5116',5167-5184',5235-5276', ALL @ 5 SPF, 4 5/8" GUN. MlU TOP DRIVE- FILL LINES. TEST SURFACE EQUIP TO 3000 PSI, OK. PRESSURE UP TBG & ANNULUS TO 2500 PSI, BLEED OFF PRESSURE & MONITOR GUNS FIRED ON SOUND RECORDER 1 BBL LOSS. MONITOR WELL WELL STATIC & HOLE FULL. PIU 137K, S/O 98K. REVERSE CIRCULATE THRU BYPASS, NO LOSSES & NO GAS TO SURFACE-MONITOR WELL, WELL DEAD. BLOW DOWN LINES, POOH WI DP TO 1000' MONITOR WELL,OK. LOG P 2,00 COMP PERF ~ P PERF 03:00-04:00 1.00 COMP PERF 8,294 04:00-05:00 1,00 COMP PERF CIR P 8,294 05:00-07:00 2,00 COMP PERF POH P 8,294 07:00-09:30 2.50 COMP PERF BHPULD P 8,294 09:30-10:00 0.50 COMP PERF CLNRIG P 8,294 10:00-11 :30 1.50 COMP PERF BHPULD P 8,294 11 :30-14:00 2,50 COMP PERF RIH P 8,294 14:00-15:30 1,50 COMP PERF DISPL P 8,294 15:30-19:30 4,00 COMP PERF LD P 8,294 19:30-20:30 1.00 COMP RUNCO RIGSER P 8,294 ~- 20:30-21 :30 1,00 COMP RUNCO BHAHDL P 8,294 21 :30-22:30 1.00 COMP RUNCO WEAR P 8,294 22:30-00:00 1.50 COMP RUNCO RU P 8,294 RUNNING COMPLETION PJSM, UD PERF GUNS, ALL SHOTS FIRED. CLEAN & CLEAR FLOOR RID ALL PERF EQUIP. MlU BHA WI BIT & SCRAPER FOR CLEAN OUT RUN, RIH WI DC & HWDP, RIH 4" DP, LC 8194', BREAK CIRC, WORK BOOT BASKETS DISPLACE HOLE WI 9,1 PPG CLEAN BRINE @ 9 BPM, 1850 PSI, 70 RPM, TORQ 8AK. MONITOR WELL,OK. POH & UD DRILL STRING. (CONDUCTED LOT OA. EMW 12.67 PPG, INJECTED 40 BBL OF 10.1 PPG MUD & 66 BBLS OF DEAD CRUDE @ 3 BPM, 600 PSI., AS FREEZE PROTECTION, CUT & SLIP 50' DRILLING LINE STAND BACK HWDP. UD DCS. CLEAN OUT BOOT BASKETS, (RECOVER 11/2 GAL METAL SHAVINGS & CMT) PULLWEAR BUSHING, PIU JANDING JT & MAKE DUMMY RUN. CHANGE BAILS, RlU COMPLETION RUNNING TOOLS & EQUIP. Mud Log Information I Fenn. Top MD. (ft) I Bkgmd Gas Conn. Gas Materials I Consumption Usage On Hand Item 1400 5760 BARITE ° 494 Personnel I No, I Hours Company I No, I Hours Company 2 12,00 BAROID 2 12,00 NABORS (ppm) TriP Gas (ppm) Pore, Press (ppm) (ppg) Fonnation MILUVICH Lithology Usage On Hand 0 5 Units TON Units GAL SACKS Item DIESEL BARITE I No. ! Hours 2: 12.00 Company BP Printed: 71212002 9:01 :08 AM { Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Company NABORS Phase PRE SURF PROD1 COMP TOTALS -.--- '--:~ Prod % Total 3,50 100,0% 69.33 66,7% 132,00 100.0% 97,50 99,0% 302.33 89.4% I No, I Hours I 23 12.00 Planned NPT % Total 34.67 33.3% 1.00 1,0% 35.67 10.6% BP EXPLORATION Daily Operations. Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPlETE Well Type: DEVELOPMENT Personnel Company I No. I Hours I Cumulative Phase Breakdown Change of Scope WOW % Total Prod % Total NPT % Total 0.00 0.0% 0.00 0.0% Remarks 0,00 0,0% Company WOW % Total 0.00 0.0% Page 3 of 3 Report: 15 Date: 7f1(ZOOZ I No. i Hours Total Hours 3.50 104.00 132,00 98,50 338.00 Total Cost USD 30.215.00 692.935,26 719.700,25 547,617.90 1.990,468.4 Printed: 7/212002 9:01:08 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294,0 (ft) Casing Size: 7.000 (in) Costs in: USD Est TVD: 7,040,0 (ft) Casing (MD): 8,279.0 (ft) Daily Mud: 13,648 Progress: (ft) Next Casing Size: 7,000 (in) Cum, Mud: 188,565 Auth Depth: 8,366.0 (ft) Next Casing (MD): 8,279.0 (ft) Daily Well: 67,890 Hole Size: 8.750 (in) Next Casing (TVD):7,037.0 (ft) Cum, Well: 1,837,756 DOUDFSlTarget: 12,90/12,45/15,50 Geologist: STEARNS/BICKER Engineer: FRANKS Supervisor: DECKER/ABBOTT Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Page 1 of 3 Report: 14 Date: 6/30/2002 Rig Accept: 01 :30 6/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 78,40 (ft) Tot Personnel: 29 Cost Ahead 200,000 USD, Days Ahead 0,50 RAIN 45 DEG, WIND 5 MPH Current Status: 24hr Summary: 24hr Forecast: Comments: RIH W/ PERF GUNS RIH & CLEAN OUT 7". CIRC & SPOT PILLS, POH. RUN US IT. P/U PERF GUNS & RIH, PERFORATE, CIRC & POH. P/U SCRAPER, RIH, CIRC POH & UD DP. NO ACCIDENTS, NO INCIDENTS, NO SPILLS HSE & Well Control All Free Days: 13 3/16/2001 -- Days Since Last DAFWC: 1319 Last Csg Test Press.: 3,500 (psi) Last BOP Press, Test: 6/29/2002 Next BOP Press. Test: 7/6/2002 Last Divertor Drill (D3): 5/14/2002 No, Stop Cards: FIRE: TVD: 2,621.0 (ft) EMW: 12,25 (ppg) MAASSP:. 292 (psi) Test Pressure: 374 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min.: RPM DH: Torq, on Bottom:8 (ft-Ibf) Torq. off Bottom: (ft-Ibf) Last Envir. Incident: 6/30/2002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 6/29/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)6/24/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Last Trip Drill (D1): Last Safety Meeting: 6/30/2002 6/30/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Operational Parameters Rotating Weight: 143 (Ibs) Daily Bit Hrs: (hr) Pick Up Wt: 203 (Ibs) Daily Sliding Hrs:O,OO (hr) Slack Off Wt: 117 (Ibs) Cum, Bit Hrs: Circ. Rate Riser: Circ, Rate Hole: Ann, Vel. Riser: (fUmin) Circ, Off Bottom: (psi) Ann. Vel. DC: (fUmin) Circ, On Bottom:2,690 (psi) Ann. Vel. DP: (fUmin) Jar Hrs since Inspect: 33 (hr) Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ, Rate 000 0 1 1 9 1 3 1 18 Length (ft) 0.60 2,94 274,91 1.37 92.08 29,94 552.45 Bits Serial # j G82JL Cum Hrs I BHA Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 0.60 6,125 3.54 4.750 1,940 278,45 4,750 2,440 279,82 5.000 2.500 371.90 4,000 2,940 401,84 4,750 2.310 954.29 4,000 2,940 PtB ~ Bit Run # IRe-Run I Size (in) I Manuf. I Type 5 6,125 Hughes ATJ-4 Cum Prog(ft) I RPM MiniMax ¡WOB MinlMax Daily Hrs I 60/ 8/13 0,00 Nozzles 18/18/18/1/1 Cum ROP I 0 I 0 I Bha No: 5 Depth In: 0,0 Bha Type: CLEAN OUT Depth Out: 8,194,0 Component Component Detail Jts BIT SUB COLLAR SUB HWDP JAR HWDP BIT BIT SUB DRILL COLLAR XO HWDP JAR HWDP I TFA (in") IDepth In (ft) Depth Out (ft) 0.746 8,294.0 8,294.0 Condition I I 0 Blade OD Bend Angle (in) n Connection Size (in) Type Pñnted: 7/112002 6:17:59 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Drillin9 Fluid (lb/100ft2) Ca: (lb/100ft2) K+: (ccI30min) CaCI2: ("F) NaCI: (cc/30min) CI-: (132") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Type: Time/Loc: Depth: Temp: Density: Funnel Vise,: ECD: PV: YP: pH: KCL 22:00/SUC 8,294.0 (ft) (OF) 9.10 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Page 2 of 3 Report: 14 Date: 6(30(2002 (mg/L) (mg/L) (%) (%) 74,000 (mg/L) (%) (ppb) (ppb) I (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) 94,0 (%) I (bbl) (bbl) (bbl) (bbl) Hrs Phase Task (hr) 0.50 COMP CASE RIGSER P Operations Summary Code NPT FINISH SERVICING RIG & TOP DRIVE. 20:00-21 :00 1,00 COMP CASE TSTPRS 8,294 21:00-22:00 1,00 COMP PERF 8,294 22:00-00:00 2,00 COMP PERF 8,294 RIH WI PERF GUNS. RIU GR & CORRELATE DEPTH, PERFORATE 4958 TO 5276' (GROSS) INTERVAL GOT INDICATION OF FIRING, MONITOR WELL, WELL DEAD, NO DROP IN FL REV CIRC, POOH, Mud Log Information /FOffil. Top MD, (ft) Bkgmd Gas Conn. Gas ~ From-To Op, Depth 00:00-00:30 8,294 00:30-02:30 8,294 02:30-04:30 8,294 P Activity 2.00 COMP CASE RIH P 2,00 COMP CASE CLNWB 04:30-05:00 0.50 COMP CASE CIR P 8,294 05:00-06:30 1.50 COMP CASE RIH P 8,294 06:30-08:30 2.00 COMP CASE CIR P 8,294 08:30-09:00 0,50 COMP CASE CLNRIG P 8,294 09:00-10:00 1.00 COMP CASE DISPL P 8,294 10:00-11 :30 1,50 COMP CASE POH P 8,294 11 :30-12:00 0,50 COMP CASE CIR P 8,294 12:00-13:00 1,00 COMP CASE POH P 8,294 13:00-14:00 1.00 COMP CASE BHPULD P 8,294 14:00-15:30 1.50 COMP EVAL LOG P 8,294 15:30-16:30 1,00 COMP EVAL LOG N 8,294 16:30-20:00 3,50 COMP EVAL lOG P 8,294 P PERF P RIH P FOffilation MILUVICH Lithology , Operation RIH TO 5450 WI 4" DP, FILL PIPE@ 2800'. MIU TOP DRIVE. FILL DP, WASH 2 STANDS TO BOTTOM, NO FILL TAG UP ES CEMENTER @ 5629', DRILL UP CEMENT PLUG, 250 GPM, 925 PSI,60 RPM, 8-13K WOB, 4.5-5 TORO, ROT 114K, P/U 150K, S/O 99K. CIRCULATE HI-VIS SWEEP. 400 GPM, 2250 PSI, 60 RPM, RIH WI 4" DP TO 7955'. M/U TOP DRIVE, FILL PIPE & WASH DOWN TO LANDING COLLAR @8194', P/U & CIRCULATE HI-VIS SWEEP, 420 GPM, 2690 PSI, 60 RPM, 8K TORO,P/U 203K, S/O 117K, ROT 143K. FOlOW SWEEP WI SEAWATER CLEAN POSSUM BELLY & SHAKER AREA. FLUSH PUMPS & ALL LINES WI SEAWATER DISPLACE WELL WI 9,1 PPG KCI BRINE @ 10 BPM, 2080 PSI, 60 RPM, 7K TORO, ROT 150K. POOH TO 5400', SPOT PERF PilL ACROSS SCHRADER, FROM 5400' TO 2700', POH WI 4" DP, UD BIT & BHA EOUIP, STAND BACK DC & HWDP, PJSM, RIU SCHLUMBERGER RIH TO 150', USITTOOL NOT WORKING CORRECTLY, DFAL POOH & UD& CHANGE OUT LOGGING HEAD, RIH TO 8173' & lOG WI USIT TOOL TOC IN KUPARUK @ +1- 7210', TOC IN SCHRADER @ +/-4350' POOH & UD LOGGING TOOLS, RIU &TEST 7" PRODUCTION CASING. TEST TO 4000 PSI, 30 MIN, TEST,OK. CHARTED SAME, PJSM. M/U PERFGUNS & FIRING HEAD. RIH ON 1 STAND OF HWDP. RIH WI HWDP + 4" DP @ 1 MIN/STAND, (ppm) TriP Gas (ppm) Pore, Press (ppm) (ppg ) Printed: 1/112002 6:17:59 AM Operator: BP EXPLORATION Well; L-108 Field: BOREALIS DIESEL BARITE BP NABORS Phase PRE SURF PROD1 COMP TOTALS ..~~ -~-- Item Company Prod % Total 3,50 100,0% 69,33 66,7% 132,00 100.0% 73,50 98,7% 278,33 88.6% Units GAL SACKS BP EXPLORATION Daily Operations Report Rig; NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Materials I Consumption Usage On Hand Item 1333 5760 BARITE 0 494 Personnel Company Units TON No. Hours 2 12.00 BAROID 23 12,00 No. Hours Company 2 12.00 NABORS Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 34,67 33,3% 1,00 1.3% 35,67 11,4% 0,00 0.0% 0,00 0,0% Remarks 0,00 0.0% 0,00 0.0% Total Hours 3.50 104.00 132,00 74,50 314.00 Page 3 of 3 Report 14 Date: 6/30/2002 Usage On Hand 0 5 No, ! Hours 2 i 12.00 i Total Cost USD 30,215,00 692,935,26 719,700.25 370,318.90 1,813,169,4 Printed: 7/112002 6:17:59 AM BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Depth MD: 8,294.0 (ft) Casing Size: 7.000 (in) Costs in: USD Est. TVD: 7,040.0 (ft) Casing (MD): 8,279,0 (ft) Daily Mud: 2,121 Progress: (ft) Next Casing Size: 7,000 (in) Cum, Mud: 174,918 Auth Depth: 8,366,0 (ft) Next Casing (MD): 8,279,0 (ft) Daily Well: 240,815 Hole Size: 8.750 (in) Next Casing (TVD):7,037,O (ft) Cum, Well: 1,769,867 DOUDFSfTarget: 11.90/11.45/15.50 Geologist: STEARNSIBICKER Engineer. FRANKS Supervisor. DECKERlABBOn Operator. BP EXPLORATION Well: L-10B Field: BOREALIS Current Status: 24hr Summary: 24hr Forecast: Comments: Page 1 of 3 Report: 13 Date: 6/29/2002 Rig Accept: 01:306/18/2002 Rig Release: Spud Date: 6/18/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 78.40 (ft) Tot. Personnel: 29 Cost Ahead 200,000 USD, Days Ahead 0.50 CLEAR 45 DEG, WIND 5 MPH CUT & SLIP DRILLING LINE FINISH RUNNING CSG. CIRC & CMT. TEST BOPE. P/U BHA, CUT & SLIP LINE. DRILL OUT ES, CIRC & DISPLACE SPOT PILLS, POH & RUN USIT NO ACCIDENTS, NO INCIDENTS, NO SPILLS HSE & Well Control All Free Days: 12 3/16/2001 .,- Days Since Last DAFWC: 1318 Last Csg Test Press.: 3,500 (psi) Last BOP Press, Test: 6/29/2002 Next BOP Press. Test: 7/6/2002 Last Divertor Drill (03): 5/14/2002 No. Stop Cards: FIRE: TVD: EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: 2,621,0 (ft) 12.25 (ppg) 292 (psi) 374 (psi) (ppg) (bbl) ROP Daily: ROP Cum,: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq, oft Bottom: Last Envir. Incident: 6/28/2002 Last Accum, Drill (04): 6/23/2002 Last Spill Drill: 6/29/2002 Regulatory Agency Insp: N KICK WHILE DRILL (02)6/24/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Last Trip Drill (01): Last Safety Meeting: 6/29/2002 6/29/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Stroke Rate PressureO Slow Pump Rates (Kill) Stroke Rate PressureO Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum, Bit Hrs: Rotating Weight: Pick Up Wt: Slack Off Wt.: Circ, Rate Riser: Circ, Rate Hole: Circ. Off Bottom: Circ, On Bottom: Jar Hrs since Inspect: 33 (hr) Pump Status - Drilling and Riser Pump Type Eft, Strokes Liner Size Circ, Rate 0 0 0 0 Ann. Vel. Riser: (fUmin) Ann. Vel. DC: (fUmin) Ann. Vel. DP: (fUmin) Bits Bit Run # I Re-Run I Size (in) I Manuf. I Type Serial # Nozzles I TFA (in2) ¡DePth In (ft)1 Depth Out (ft) 5 6.125 Hughes AT J-4 I G82JL 18/18/18/1/1 0.746 8,294,0 Cum Prog(ft) I RPM ~inlMaX /WOB ~inlMaxl Daily Hrs I Cum Hrs I Cum ROP I Condition -- ° I ° I I I BHA Bha No: 5 Depth In: 0.0 Bha Weight: Bha Type: CLEAN OUT Depth Out: Wt Below Jars: Component Component Detail Jts Length Cum Length 00 10 Blade 00 Bend Angle Connection PIB (ft) (ft) (in) (in) (in) (°) Size (in) Type BIT BIT 1 0,60 0.60 6,125 SUB BIT SUB 1 2,94 3,54 4,750 1.940 COLLAR DRILL COLLAR 9 274,91 278.45 4.750 2.440 SUB XO 1 1.37 279.82 5,000 2,500 HWDP HWDP 3 92,08 371.90 4.000 2,940 JAR JAR 1 29,94 401,84 4,750 2.310 HWDP HWDP 18 552,45 954.29 4.000 2.940 Printed: 613012002 6:14:54 AM 14:00-14:30 0,50 PROD1 CASE 8,294 14:30-15:30 1,00 PROD1 CASE LANDTH 8,294 15:30-16:30 1.00 PROD1 CASE 8,294 16:30-17:30 1.00 PROD1 CASE INSTAL 8,294 17:30-18:00 0,50 PROD1 CASE 8,294 18:00-21 :00 3,00 PROD1 CASE TSTPRS 8,294 21:00-21:30 0.50 PROD1 CASE 8,294 21:30-23:00 1.50 PROD1 CASE BHPULD 8,294 23:00-00:00 1.00 PROD1 CASE RIGSER 8,294 FINISH CUT & SLIP LINE RIH & TAG ES CEMENTER @ 5629' DRILL OUT PLUG CIRC & RIH TO BOTTOM, Mud Log Information I Form, Top MD, (ft) I Bkgmd Gas Conn, Gas Operator: BP EXPLORATION Well: L-108 Field: BOREALIS Type: Time/Loc: Depth: Temp: Density: Funnel Vise,: ECD: PV: YP: pH: POLYMER 19:00/SUC 8,294,0 (ft) ("F) 10,20 (ppg) 47 (s/qt) (ppg) 11 (cp) 16 (lb/10OO2) 8,4 From-To Hrs Phase Task Op. Depth (hr) 00:00-05:30 5,50 PROD1 CASE 8,294 '~. 05:30-06:00 0,50 PROD1 CASE 8,294 06:00-08:30 2.50 PROD1 CASE 8,294 08:30-11:00 2.50 PROD1 CASE 8,294 11:00-12:30 1,50 PROD1 CASE 8,294 12:30-14:00 1.50 PROD1 CASE 8,294 ~ Formation MILUVICH Lithology , . BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRlll+COMPlETE Well Type: DEVELOPMENT Drilling fluid 5 (lb/10OO2) Ca: 7 (lb/100ft2) K+: 4,4 (cc/30min) CaCI2: 200 ("F) NaCI: 9.4 (cc/30min) CI-: 2 (/32") Sand: 12.00 (ppb) HGS: (ppb) lGS: (mL) Pf/Mf: Page 2 of 3 Report: 13 Date: 6(29(2002 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: 80 (mg/L) (mg/L) (%) (%) 600 (mg/L) (%) 80,18 (ppb) 30.22 (ppb) 0.05/0.4 (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum, Cuttings: Lost Downhole: Lost Surface: (mV) 8,80 (%) 2,0 (%) 89,0 (%) I (bbl) (bbl) (bbl) (bbl) Activity Operations Summary Code NPT Operation RUN P FINISH RUNNING 7" PRODUCTION CASING, RAN 202 JTS. SET @ 8278.83' FLOAT @ 8235, LANDING COLLAR @ 8194', RA MKR JT #1 @ 8051', RA MKR JT #2 @ 7624'. ES CEMENTER @ 5629'. LAND CASING @ 8279', RID FRANKS TOOL. BLEED DOWN TOP DRIVE MIU CEMENTING HEAD & CIRCULATING LINES. BREAK CIRCULATION SLOWLY & INCREASE TO 6.5 BPM @ 752 PSI. RECIPROCATE CASING 20' STROKES, 1/MIN, CIRCULATE & CONDITION MUD PRIOR TO CEMENTING, HELD PJSM, CEMENT 1st STAGE AS FOLLOWS:PUMP 5 BBLS WATER, TEST LINES RO 4000 PSI, PUMP 5 BBLS WATER, MIX & PUMP 35 BBLS OF ALPHA SPACER @ 6 BPM, 460#. BATCH MIX & PUMP 43.9 BBLS OF PREMIUM "G" LEAD CEMENT WI ,35% CFR-2, 1% GEL, 2 GPS LATEX 2000, ,36 GPS 434-8. YLD 1,19 CF/SX, WT 15.6 PPG. APR 6,5 BPM, APP 500#, DROP PLUG & DISPLACE W/315 BBLS OF 10,1 PPG MUD, BP WI 1200 PSI, FLOAT HELD. PRESSURE UP TO 2900 PSI & SHIFT OPEN ES-TOOL. CIRCULATE 2 ANNULAR VOLUMES, CEMENT 2nd STAGE AS FOLLOWS:PUMP 10 BBLS WATER, MIX & PUMP 35 BBLS ALPHA SPACER @ 5,5 BPM, 320 PSI. BATCH MIX & PUMP 61.5 BBLS PREMIUM "G" TAIL SLURRY WI 2% CAL-SEAL, 3% KCL,.5% LAP-1. YLD 1.22 CF/SX, WT 15,6 PPG APR 7 BPM, APP 525 PSI. DROP PLUG & DISPLACE W/210 BBLS OF 10.1 PPG MUD, BP TO 2100 PSI & SHIFT ES CEMENTER. CLOSED, PLUG HELD, OK. CMT IN PLACE @ 1400 HRS 6-29-02, RID CEMENTING EQUIP. BREAK OUT LANDING JT. LANDTH P CIR P CMT P CIR P CMT P RD P P MIU RUNNING TooL& PACK-OFF, INSTALL & RILDS, TEST PACK-OFF TO 5000 PSI, OK RID CASING TOOLS, CLEAR FLOOR & CHANGE BAILS, RD P P INSTALL 3 1/2" X 6" UPPER VARIABLE RAMS. RU P RlU EQUIP FOR BOP TEST, P PRESSURE TEST BOPE TEST WITNESSING WAIVED BY JEFF JONES WI AOGCC. HP 4000 PSI, LP 250 PSI. ANNULAR 3500 PSI. RID TESTING EQUIP & BID LINES, RD P P MIU BHA #5 & RIH, P CUT & SLIP 80' DRILLING LINE (ppm) ¡Trip Gas (ppm) Pore. Press (ppm) (ppg) Printed: 613012002 6:14:54 AM Operator: BP EXPLORATION Well: L-108 Field: BOREALIS DIESEL BARITE BP NABORS Phase PRE SURF PROD1 COMP TOTALS "-,,,- ..- Item Units GAL SACKS BP EXPLORATION Daily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Materials / Consumption Usage On Hand Item 1296 4968 BARITE 0 494 Personnel Company Units TON Company No, Hours 2 12,00 BAROID 23 12,00 No, Hours Company 2 12,00 NABORS Prod % Total 3.50 100,0% 69.33 66,7% 181.50 100,0% 1.00 100,0% 255,33 88.0% Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 34,67 33,3% 34,67 12.0% 0.00 0.0% 0,00 0.0% Remarks 0.00 0,0% 0,00 0,0% Page 30f 3 Report: 13 Date: 6/29/2002 Usage On Hand 0 5 No, ¡Hours 21 12.00 Total Hours 3,50 104.00 181.50 1.00 290,00 Total Cost USD 30.215,00 692,935.26 719,700.25 302,429,38 1,745.279,8 Printed: 6!3012oo2 6:14:54 AM :::jO~'\oÙx ~ å ~~ 3 ~8.5-5>§ ~~~mffil 0 0 5 Q 3 0. ~ ;.- ãjI 0 3 £ -" g. g: :J~g CD CD en 3 ~~. 5' CD;;;~ c:: C' 3' (Q (J) Ñ' CD ()m~'f3~~or;-~~~l~ ;D~(IÈ"...,o=-g:-~1\) d: .E:Zo(Q o.IÞ C'õ'¡:" 0 G) 'CD =- 3 -. =- =- -. Cf)JJ_~(Q ;:;::J ::J :r:m " c:F:E ~-<c: :E a » :r: - -< 0 m CD » -<- en (.) 0 3 ~ ~ 5: ~. ~ 5- ~ ¡.f Y"" ",:1.. ~ Field: CD ()ï::¡:~(Q o'¡' .:;- ?ñ ~ '< ,,(Q:( ¡ (Q Location: - ~ ë: 5" If '!, J" a Z c: íjj«t"'¡ I: '(I) ~ Well: G) :CI"'(I) ~ -i:?', C :tš è!. ;t, tJ Company: OJ CD:¡ .g Z ,- Cf (j) 1 ~ I ;!1 , I ~ ì' g ~ ~,: rp ëi) I\) CD '1]0)(. (;)CDOc.>!~ JJ ..,¡ a _.. ..... Z r g~o~~~~ml ~ c: =- ~r ;t =- , ~ I, 8 a: I\) " 'I ï c: 6 Cf) ....... a ~ ~., OS3: OS4: OS5: REMARKS: RUN NUMBER 1 Log correlated Tubing Tally dated 26.JUN-2002, ~ 2 ~ =- 3 c5 ~ § ~ ~ ~ ¡¡¡ ã; a C c. III m " Ë ~ Ò ~ -. 3 ~ .. Sfi Sfi ~ r- f{) ~ ~l Q :J .....í ~cn ::r is' .....b? --':J m(Q CD . I. -, . .... . ...... m : ~ ;:;' .. IIIOOG};:'\ g =- :-n ¡- !II < CD "tI CD ~ 0 » ë 3 BOREALIS 2412' FSL & 1691 .6' FWL L-1OBi BP EXPLORATION (ALASKA),I LOCATION m ~ ~~CP-C~ (f)"'" :> :J] C:~Cm ~ ~ Ci) (f.) ^ ~ ~ r\) ~(f.) 0 ¡B°-.m ..... ° m -i q¡ I\:) š: m ~ ~ìJ ~.. (j)r- ~8 0 p (f.) -C Z Z I ~ I ...... .þ. 0) CD :¡:,. (0 =- ;:t OS4: OS5: REMARKS: RUN NUMBER 2 , . , . , . Logged baseline pass down from surface to 7500', F~g in tubing tail at 7502'. Pumped Methanol down tubing at 2.8 GPM, 2000 psi - ~~500 psi, Performed stop count above tail plug to check for leak at plug, ~ogged up at 120 fpm from 7500' to surface while pumping, Pump,i!d total of 8 bbl Met 1anol while logging for about two hours, Located temperapa anomaly near packer at 4769', Perlormed repeat pass over anomaly at 8°¡!e:m and stop count; above and below anomaly, r- I Crew: Chapman & Finley, / AFE #: BRD5M4087 V SERVICE ORDER #: PROGRAM VERSION: FLUID LEVEL: LOGGED INTERV.AJL I ¡- --:--. RUN 1 H- k-I- r~- / START i' I I. 9. tI, 25969 1 OCO-306 I ,!£: ,STOP .,1: ~ 1- RUN 2 SERVICE ORDER #: PROGRAM VERSION: FLUID LEVEL: LOGGED INTERVAL STAAT STOP PËRFš I"".t. ) -(RPiS) . .M,~~''''-_.' ...) 20 ~ I;' , '~..... ~........ ......... f!~!t!~ ~~I!!~y .~p!~!1.~r.1. ('!PJ1).........:.............. (¡ (RPS) 40 , - - -.£able S~~JfL -- . -200 (F/MN) 200 I I J I ~ I ~ ,) I 1 <-( I ~ c;- I : I : I ~ I l! ¡ 1 ~GLM~ I I! 4700; - I I 1 I I ~!! : I t Ii, I 1 ~ . : ~ I ¡ f : ~ I j 'ii' , I .:> 1 ~ !' : : ~ I ¡ 'Ii, 1 ~,'..- .. ¡ \ I c' ~ ~ : . i= :\ \ i / I ~ ;:;1 . 'í=--=. \ \ I :> I .¡ ,iili, E : \ TI:Mr :1 ( I : ~ X NIP ~j:'ii ;!= ~. \ ANOMALY 11 \ ~ \ t ') I ;- t- "\ ~ 11 VI " ~ f -----. PACKE ~\ ' . ~ ~ I 1 II.... I "- <1: -; \ : "" I~ I :r..J ' \ \¿ ~I i ~, 1 l I li11: /f¿ ~ 4J~.\. : ~ t I; r ~ I I"-~, I ,~, , I ,/, l r: I I J... ~ I, , : ~ ~ ;. ¡, t ". : : :?: I .J. xo ¡; ~ '.; : ( I ,. t " r I L I I L ;, , I l-.o ':' I ~ I, I ~" I \ : I ", I ........... : I r/ . ~ J "" - - ~a~ S~~SL - ~.......................~!~!t!~~~I!!~.t!P!~~rJJ~~l~)........--...--...--.... -200 (F/MN) 200~0 (RPS) 40 Computed CCL (CCLC) OP~ Filtered Main ~plnMr (SP+H) M ÆR~ ~ ~~ - ..... -... -. .. - - - .- ,,- . . < .19 (V) ¡.19 I I \0 I . . . . . . . . . ~~I! f.~~!I!!'. ~ft~l- - - . . - . . . 0 (PSIA) 4000 - I I I I I I I I I I \ ¡ ; j' I I I J I I \ ) \ \ ) I ( t t I /' ,. . , , I I ' i \ \ : \ ) I i I : I ; I ~ I: \,( ~¡ 1\ l' : \ .. I \ , ..... ) "I J , ) \ ) ) -) ) I I ) ( ) ) \ I "- '\". -... <..... ..... ".. - ¿ -.... ? / I ) , I l l \ ) \ J ( '\ ... 20 Tel18lo11 (TENS) f - - - - - - - - - - - \y!1!J~.e.e!!t~~1. - - - - - - - - - - 100 (LBF; 0 (DEGF) 20 4000 () , - - - - - - Well Fluid DensJ!l (!!ED.§L - - - - -- 0 ~~ 2 Gamma Ray (GR) (GAPI) - - - ~e!!. T.!.mp.!.a~r.!. ~~ - - - 20 (DEGF) 220 \ ~ \ \ , ì - _D~4!!.e!!!l!! !!I!!P!!~!! ~G~>- - -0.5 (DF/F) 0.5 PIP SUMMARY ~.. .,!:. ,.Ii. I.)_~...":;:':.~ -¡ \ 1,,~ J,.,)- ~ II, I OJ........... --..... ..... \ 8 GLM fJ 1". '~~:--- .'..'..! \ {\ ~ 4 ),.1:1 .~~...~~~~;~~ f: :~ ~\ \ E3 ~. --..... . :. { \ ~I. :--;} ~ s \ : i 430.:~I~ ...,::~;t:::::::L,,:::::: :::~:",..... t \ ~ <", r . . \ 1d 4:;\ ,"') ~ ~ \ ... I' .....- ) q. 44 ' \:-., t ." \ \ ~ r==:': ~. '. .~.:&:':-._----,--,--", -.. ...f........-,........¡....._~... ...\..", ' ~¡ ':¡ -'''.'''''.''':.:~_._--- ---.---.--- --1"" ..., ---, -..:::--...-........ " ~¡;! 1 ~.~...:_-.'-::=~~~'-' 1 t \ I :.) 45~, .~' ....:'-,.:') : \ I----i.¡ ~. I. '...... ,\ ~., ...... > , ~ i i ~..~ '{ t ¡ I ~ ; Ii.,! ~\~::::::::::: I \ j ---:: J 1. ~!'¡, \\ i, ~ ¡ l' .~ GLM #~ ! .( ~ ~ I - =if l 47~) j , :\ ~ ~ ~- I 1 ~- .' ~ PACKE~...I ..":.\~~;~~.~~:::::"",, ...~ :~:~--., I ... ~ '1 ' .. .1. I ~ - J I --.~ 481 'I' ~.'I' I ~ ~ . 1:Iõ ----..-: i.1 "'---'-"--6.' , ; ') l --:: ---=r:. I., . ;';J~.r .ss:; '-fl I I ....J }h~'''''''''''''''-- =~. - CABLE SPEED UP PA5.§JC!L - OPEN I ' ..,................Ç~~"!I~H9~t?t?~I~~.E;t;I.J~~rf.~~.~~'!U~.P.t1).............. -200 (F/MN) 200 PERFS :.0 (R~8) 40 I_- I .s. I ~ , - I-:-~ I - -=:;' I~ I - ,--- I ...- ~ r-.- ~ -' ,." - ---- -- ~ < ~ ~ ---::- -19 Computed CCl (CCLC) (V) Tension ., (TENS),¡ :, 1 (lBF) ,:. . -20 4000 :õ) '- - - - - - - ~MP..:! ~ fPM ~ jV!!I~f.U~~~ J.W..!E.fL - - - - - - 0 (DEGF) 20 FULLBORE SPINN~R ~~FPM UP PASS ,(SPIN) (RPS) 0 Gamma Ray (GR) (GAP I) 100 . - - - - - - - - ~~I! ~~~~!J!!t- ~~~~} - - - - - - - - - 0 (PSI A) 4000 - - - ~e!!.. T..!n:!I?8!.a~r.!. ~.É~ - - - 20 (DEGF) 220 .- - - - - - Well Fluld..Q!.n!!,!l ~D.§L - - - - -- 0 ~~ 2 TEMP 120 FPM DOWN BASELINE (WTEP REP) (DEGF) ,0 - "p.!!!!!.e,!!!l!! !!'!!P!!'l!!.U!! ~G!!L - -0.5 (DF/F) 0.5 PIP SUMMARY :8 Time Mark Every 60 S Parameters DLlS Name Descriptio~ Value PFCS-A: PSP Flow and caliper Tool, Spinner Filter A'/eraglng Mode Average AngulÐr t,'evlatJon of Borehole from Normal Spinner Depth COI,1atant Filter Auxiliary Splm...r' Flowmeter Sonde Main Spinner FI.,,,,;meter Sonde CFS-X: PSP Contlnous Flowmeter Sorade. typtJ X AMOD Spinner Filter A~etag}ng Mode SDCF Spinner Depth C~'nt Filter SPI1 Auxiliary Splm~r. Flowmeter Sonde SPIN Main Spinner FPO\\m8t¡u Sonde PGMC-A/B: PSP Gradlomanometer MeI8~rernent Module GCPG Gradlo Surf.Cal DI 'tPr8. Gain GCPO Gradlo Surf.Cal DI.'f.PI'M Offset PDSH Gradlo Correct¡~'t,iD.nslty Shift PSPT.A/B: PSP BASIC TOOL ' GDEV Average Angulat ..eviatlon of Borehole from Normal System and Miscellaneous ¡ DORl Depth Offset for; Rlpeat Analv-I. -6.0 FT Format: LDl_OVERLAY_120_S1 Vertical Scale~ ',,8 per 100' GraphlC8 File Created: 03-Aug-200213:16 OP ~tstem V~.f.IIlon: 1OCÐ-306 AMOD GDEV SDCF SPI1 SPIN LINEAR AVERAGE - 0 DEG 6 CFS-X PFCS-A- TURB LINEAR AVERAGE - 6 CFS-X PFCS-A- TURB 1 0 PSIA 0 G/C3 0 DEG 20 20 ~ /' ,'h""'" . ,¡~;:::::"""""""",-";:,:,»,,,",,,,,,,,,,,,,,,;,,;,,;,;.,:,:,-,<;,,.,.(,:,:;.M':'¡':""""";'¡';'i"<;~';¡'...';,I,:;"../,j,'.' .. .,)"""'''',"'¡''-'*''''ðl'''''':'''..~:':u....", , " ;,.,:_..,~ ::1;.: ; \ 1 : .\1 I " - -P~4!!.e~l!! !!'.!!P.!!'I!!.U!! !Yi!.G1!L - ," II .' -0.5 (DF/F) 0.5 ,.:.i.!,--,¡ TEMP 120 FPM DOWN BASELINE (WTEP _REP) ,.9 ., ' (DEGF) 20 I'it:' L - - - - Well ~d Den.!!!l ~D.§L - - - - -- ¡' ,¡ (G/C3) 2 ,,' . ~ - - - - - ~~P J ~ E.P~ ~ .!V!!I~ !U~~~ .!.W-!E.!L - - - - - - , .,0 (DEGF) 20 I;' :;.\ Tension \¡!¡ (TENS) .Ii.,! FULLBORE SPINNER_!.~!~FPM UP ~'.AS$ ~SPN) . 1 (LBF)!, ,,20 (APiS) 20 4000 p: - CABLE SPEE~P PAS~C~ - OPEN I, "1...............Ç!?~TI"~~Q~~"~p'I~~"t;~.!~~f'-M~.!'~~~i!5'-t1)....".."........ .200 : (F/: -~ ~~ PERFS r \ \ ) (APS) < -\ 40 I L I!. - ,~; ~ " I .., ,. 1. f { ~ ~ l -=- ~ GL~-;EI .', \- 5 ~ ~- ø I ~ "I ~ ---4- ~ '* 1 ~~ ~ )i ~~. { : \ I -<. ¡; ~ '! ¡ ~ '- ~ ~,r- PACKE4L.~.., :~~~~I y ~..~ - .-J -: - - -.. ',. rc= - b=::?" 48CJ:' .., ~r:r: / ~ ;, i-~ {~,' ::M#~~~:P~T ":,f( 1. \~ I' ~ 490Q': ^\ J ' I ~I ~, , Z. I 1---:' WFM #1'" ;.," ; , ~ ~- t i ~ ¡":, Ei ~'; ) r f I B it t oS ~ L~ -~ R I ~ ; i t : ~ ~=r ..~ t"\ ~ ~ 51C{j: l ~ ~ ê 1,- " S I I ..;.to- ( , ~ !'. ~ I ~ . C, '\ ~,- ~ \ ¿ I . . I ~ ~ ). , I ~ ß ¡..I==' (' \ ~ <. I -,: 52("<: ~= €. \ . : ~ H :~- r. \L ~ I ç- It 1c- . \l\- \I~-- ~ ~('i '~ f\\ 1 ! ~ ~ ¡ i 5400 : .~ ; \\ 1 \ .~:~ . . -~ .! ~\ I ~ ~ J,\ - n - - -.. - I . -- -. , - ~";:',.7.:.. ~L.:(-';':':"':;'f'<;';~:;:";;"::.-.':; .'. . -,~.. " '.':'.;';':0.;. .., ;..,c,:,,",;.,,:\;::~,:,.. . , :.11 Time Mark Every 60 S - - - ~e!!.. T.!"!P!L~r.!. ~.Ê~ - - - 20 (DEGF) 220 . -- - - - - - -~~I!~r:.4!~!I!~_m~!!¡;l___- ----- 0 (PSIA) 4000 0 Gamma Ray (GR) (GAP I) 100 .19 Computed CCl (CCLC) M j.-""\ . ' \ ' ¡,' ~~,~:::)~ . ScblumbepgBP Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ,- Well L-105 aO~-05~ L-109 d"OJ"aO i L-108 t:510::s- 09 L-108 I L-108 .jI --.. Job# Log Description 22343 CET/USIT 22341 USIT 22315 OH MWD GR 22315 MD VISION GR 22315 TVD VISION GR Date 07/16/02 06/14/02 06/27102 06/27/02 06/27/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 .AJ~aka OH & Gas Coos. Commission Anchorage NO. 2324 8/16/2002 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Receiv~r Á BL CD 1 1 1 Cbo~ Schlum~el'ger NO. 2313 8/15/2002 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis --. Well Job# Log Description Date Color Sepia L-105 dni~05 \tf 22342 CET/USIT 07/15/02 2 L-105 . 22344 USIT 07/19/02 2 L-109 ~(J /-~() J 22340 USIT (2) & SCMT 0719&10/02 6 ~ L-108 ~Od.- J09 22314 OH PEXlAIT/BHC 06/27/02 L-1 09 ' 22314 PEX-AIT 06/27/02 ~-lCfð L-110 22314 BHC 06/27/02 L-111 22314 PEX-NEUTRONIDENSITY 06/27/02 LD?f L-112 22314 PEX-QUAD COMBO 06/27/02 L-113 22314 PEX-SSTVD 06/27/02 L-114 V 22314 PEX-HCAL 06/27/02 ,- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECE\VED AUG 1 6 2002 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Date Delivered: Received by: Alaska O~ & Gas Cons.. C.omfT1ißion Anchorage BL CD 1 1 1 1 1 1 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~:~~~:g:~~~l~? 34, T12N, R11E, UM L~~.?~~ .~~~~~ 8~?'t~~bj;~~9' SEL, SEC. 34, T12N, R11E, UM :..,~~1p I,..... .. _. .: ~.'r~:"..~'r ~-'~~'; 10. Well Number 764' SNL, 1486' WEL, SEC. 03, T11N, R11E, UM I ,~~,~ ""'''ì,,~,;-,..h 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.4' ADL 028241 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 6/18/2002 6/26/2002 7/4/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8294 7039 FT 8194 6954 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC Sonic, USIT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 108' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 2720' 12-1/4" 555 sx Articset Lite, 249 sx Class 'G' 7" 26# L-80 25' 8279' 8-3/4" 490 sx Class 'G' Classification of Service Well Water & Gas Injector 7. Permit Number 202-109 8. API Number 50- 029-23090-00 9. Unit or Lease Name Prudhoe Bay Unit L-108i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2237' MD 1900' (Approx.) TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 4825' 3-1/2",9.2#, L-80 7560' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 87 Bbls Diesel 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf MD TVD 4958' - 5006' 4350' - 4386' 5042' - 5080' 4414' - 4443' 5096' - 5116' 4455' - 4470' 5167' - 5184' 4509' - 4523' 5235' - 5276' 4562' - 4594' 25. MD TVD 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR Oll-BBl TEST PERIOD GAs-McF WATER-BBl Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF WATER-BBl AMOUNT PUllED PACKER SET (MD) 4769' 7502' CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) ?8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips:;:\ ~.,' . .co¿~ 0 R ¡ G ! N /\ L RODMS OF L All 19 2002 Submit In Duplicate No core samples were taken. Form 10-407 Rev. 07-01-80 \.I, - - ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Schrader Bluff N Sands Schrader Bluff 0 Sands Base Schrader I Top Colville CM1 HRZ Kalubik Kuparuk D Kuparuk C4 Kuparuk C3 Kuparuk C2 Kuparuk C1 LCU / Top Kuparuk B Kuparuk A Miluveach 4746' 4958' 54291 6694' 7292' 7540' 7666' 7685' 7703' 7756' 7820' 7879' 8037' 8132' 4192' 4350' 4715' 5704' 6180' 6392' 6502' 6518' 6534' 6580' 6635' 6686' 6821' 6902' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~).J\iß, ~Title Technical Assistant L-108i 202-109 Well Number Permit No. / Approval No. Date C8~ {S.O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. , i l " l Form 10-407 Rev. 07-01-80 Legal Name: L-108 Common Name: L-108 Test Date 6/23/2002 Test Type LOT Test Depth (TMD) 2,720.0 (ft) BPEXPLORA'-ION Lèak-OffTestSul11rnary Test Depth (TVD) 2,621.0 (ft) AMW 9.50 (ppg) SLJrfacePresslire 374 (psi) Leak Off Pressure (BHP) 1,667 (psi) EMW 12.25 (ppg) .~/ ~ Printed: 7/10/2002 12:21:06 PM ) ') ~... .. BP EXPLORATION Operations. Summary Report . Page.t of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-108 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From- To Hours Task Code NPT Phase Description of Operations 6/17/2002 22:00 - 00:00 2,00 MOB P PRE RD & back off well L-1 09i. 6/18/2002 00:00 - 01 :30 1.50 MOB P PRE MIRU on L-108i. Accept rig on L-108i at 01 :30 hrs on 06/18/2002. 01 :30 - 06:00 4.50 DRILL P SURF Install riser. Rig up floor. Spot cuttings tank, Put BHA in pipe shed, Mix spud mud. 06:00 - 07:30 1,50 DRILL P SURF P/U BHA #1 and stand back in derrick. 07:30 - 08:30 1.00 DRILL P SURF Rig up Schlumberger f/ gyro surveys, 08:30 - 09:30 1.00 DRILL P SURF Fill conductor w/ water and check for leaks. 09:30 - 10:30 1,00 DRILL P SURF M/U Anadrill UBHO and align toolfaces, 10:30 - 11 :00 0.50 DRILL P SURF Pre-spud meeting. 11 :00 - 12:00 1,00 DRILL P SURF RIH tag at 95'. 12:00 - 12:45 0.75 DRILL P SURF Drill cement to 108' formation to 170', '" 12:45 - 13:20 0,58 DRILL P SURF Run gyro survey. 13:20 - 14:00 0.67 DRILL P SURF Drill f/170' to 262'. Drilling w/ max wob, 70 rpm (topdrive), 650 gpm, Sliding 30-50' rotating remainder of stand. 14:00 - 15:05 1.08 DRILL P SURF Run gyro survey, 15:05 - 16:20 1.25 DRILL P SURF Drill f/ 262' to 448'. 16:20 - 16:50 0.50 DRILL P SURF Run gyro survey. 16:50 - 18:40 1.83 DRILL P SURF Drill f/ 448' to 633'. 18:40 - 19:25 0.75 DRILL P SURF Run gyro survey. 19:25 - 21 :00 1,58 DRILL P SURF Drill f/633' to 909'. 30-35k wob, 80 rpm, 650 gpm 21 :00 - 21 :35 0.58 DRILL P SURF Run gyro survey. 21 :35 - 00:00 2,42 DRILL P SURF Drill f/ 909' to 1095' 6/19/2002 00:00 - 03:40 3.67 DRILL P SURF Directionally drill w/ surveys f/1095' 1406' 30 -35k wOb, slide 30' rotate remainder. 1450 spp 650 gpm 80-100' rop. 03:40 - 04:50 1.17 DRILL N SFAL SURF Lost 500 psi standpipe pressure. Isolate pumps. Suction screens appear plugged off. Clean out suctions, not much found. Still problems. 04:50 - 07:00 2,17 DRILL P SURF TOH for new bit (planned event close to this depth). Watching for washout. Same time teardown suctions on pumps 07:00 - 07:30 0.50 DRILL P SURF Change out bit. Found main upstream suction line packed off during inspection of surface equipment. 07:30 - 08:30 1.00 DRILL P SURF RIH w/ new bit. 08:30 - 16:30 8.00 DRILL P SURF Directionally drill f/1406' to 1670' w/30-35k wob, 650 gpm 5,5 Tq on bottom 3k off, Started drilling hydrates, slow pump down to 500 gpm continue drilling ahead increasing gpm back to 650. Drill to 2722' csg pt. Up wt 97k, Dn wt 82k, RT wt 95k. 2650 psi on bottom, 2430 psi off. Actual on bottom drlg rate: Sliding 3.23 hrs 720' @ 219'/hr Rotate 1.97 hrs. 612' @ 311'/hr 16:30 - 17:00 0.50 DRILL P SURF CBU, monitor well. 17:00 - 19:45 2,75 DRILL P SURF Wiper trip to HWDP. 19:45 - 20:00 0.25 DRILL P SURF Drill an additional 6' rathole to 2728'. 20:00 - 21 :00 1.00 DRILL P SURF CBU pump low vis 50 bbl13 ppg sweep CBU. 21 :00 - 22:00 1.00 DRILL P SURF TOH f/ 9 5/8" surface csg. 22:00 - 00:00 2.00 DRILL P SURF UD BHA #2. Layout Daily Hyd jars, chocked and would not open. 6/20/2002 00:00 - 01 :00 1,00 DRILL P SURF Finish UD BHA #2. 01 :00 - 01 :30 0.50 DRILL P SURF Clear floor. 01 :30 - 02:00 0.50 CASE P SURF P/U FMC 9 5/8" hanger and make dummy run. 02:00 - 04:20 2.33 CASE P SURF RIU Frank's tool, csg tongs etc. 04:20 - 04:55 0.58 CASE P SURF PJSM. Review csg running plans and procedures, equipment Printed: 7/10/2002 12:21:15 PM ') ') BP EXPLORATION Operations Summary Report Page 2of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -1 08 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From - To Hours Task Code NPT Phase Description. of Operations 6/20/2002 04:20 - 04:55 0,58 CASE P SURF (hyd tongs) operation. Apply STOP principles. 04:55 - 06:30 1,58 CASE P SURF Make a minor adjustment to skate that was brought up in safety meeting. PIU shoe track and check floats -ok. Run 9 5/8" 40# L-80 casing. 06:30 - 07:00 0.50 CASE P SURF Hold safety meeting wI Jim Denny of Nabors. 07:00 - 12:00 5.00 CASE P SURF Continue running casing. Stopped at 2662' , 66' off bottom. Base of SV1 @ 2666'. Confer with town group. Need to work pipe closer to bottom. 12:00 - 15:30 3.50 CASE N DPRB SURF Attempt to work casing to bottom. Set down no pump pressure increase, could be hanging up on ledge. Pump "lube" pill and continue working pipe, Not able to work lower than 2662'. 15:30 - 16:00 0.50 CASE N DPRB SURF Make preparations to lId casing, 16:00 - 18:15 2.25 CASE N DPRB SURF W/O side door elevators to facilitate lId of casing. Continue circulate and moving pipe, 18:15 - 18:30 0,25 CASE N DPRB SURF RIU side door elevators. LID stabbing board. 18:30 - 19:00 0,50 CASE N DPRB SURF PJSM. Review procedures and hazards laying down casing. 19:00 - 00:00 5,00 CASE N DPRB SURF Laydown 9 5/8" casing. 38 jts down of 65 total. 6/21/2002 00:00 - 00:15 0.25 CASE N DPRB SURF Crew change. PJSM covering laydown operations. 00:15 - 02:00 1.75 CASE N DPRB SURF Continue laying down 9 5/8" surface casing to shoe track. 02:00 - 04:15 2,25 CASE N DPRB SURF Check LEL's. Heat jt #3 and break out. Unable to break out jt#' 1-2. Check LEL's. Cut csg above float collar and lId. All centralizers recovered. 04: 15 - 06:00 1.75 CASE N DPRB SURF Clear floor. Change out 15' bales. Set BHA #3 in pipe shed. 06:00 - 07:30 1.50 CASE N DPRB SURF PIU BHA #3 surface test MWD, 07:30 - 09:30 2.00 CASE N DPRB SURF RIH tagged up at 2657'. Unable to enter old hole, oriented high right and drilled to 2728' TD. 09:30 - 11 :30 2,00 CASE N DPRB SURF Circulate and condition at 690 bpm 110 rpm. Backream 70'. Orient to highside, pump sweep around. 11 :30 - 13:30 2.00 CASE N DPRB SURF TOH stand back HWDP, jars and 1 std dc's. 13:30 - 15:00 1.50 CASE N DPRB SURF LID BHA and clean rig floor. 15:00 - 17:00 2.00 CASE N DPRB SURF RIU casing tools. 17:00 -17:15 0.25 CASE N DPRB SURF PJSM review csg running procedures. 17: 15 - 21 : 30 4,25 CASE N DPRB SURF Run 65 jts 9 5/8" 40# L-80 surface casing. PIU landing jt land at 2720'. 21 :30 - 22:00 0.50 CASE P SURF LID Frank's tool. M/U Howco cmthead and lines. 22:00 - 00:00 2.00 CASE P SURF Establish circulation. CirclCond mud and hole at 10 BPM. Reduce gels/YP. Reciprocate pipe. RlU Howco surface equipment and lines. 6/22/2002 00:00 - 01 :30 1.50 CASE P SURF Continue circlcond mud and hole. Reciprocate pipe 140k up 118k dwn 10 bpm 980 psi. 01 :30 - 02:00 0,50 CASE P SURF PJSM Review outline of cementing procedures, job assignments and safety awareness. 02:00 - 05: 15 3.25 CASE P SURF Test Howco lines to 3500 psi. Pump 75 bbl Alpha Spacer, follow by 450 bbl1 0.7 ppg Permafrost L, then 51 bb115.8 ppg Premium cement. Displ wI 200 mud with rig pump. Plug down at 0500 hrs 6-22-2002. Floats held. Good returns throughout job. Circulated +1- 100 bbl1 0.7 ppg cement to surface. Reciprocated 8-10' until last 45 bbls of displacement. 05:15 - 06:30 1.25 CASE P SURF RID Howco and cement lines floor. 06:30 - 09:00 2.50 WHSUR P PROD1 NID riser and surface equipment in cellar. 09:00 - 11 :00 2.00 WHSUR P PROD1 Install FMC 11" x 5k Unihead and tbg spool. Test metal-metal seal to 1000 psi/10 min 11 :00 - 14:00 3.00 BOPSUIP PROD1 N/U 13 5/8" x 5k BOP stack. Printed: 7/10/2002 12:21: 15 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') BP EXPLORATION Operations Summary Report Page 3 of9 L-108 L -1 08 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From - To Hours Task Code NPT Phase Description of Operations 6/22/2002 14:00 -18:00 4.00 BOPSUR P PROD1 Test BOPE to 250 psi/5 min 4000 psi/5 min. Annular 3500 psi. Witnessing of test wavied by AOGCC Rep, John Crisp 18:00 - 19:30 1.50 BOPSUR P PROD1 Pull test plug, Hanging up 8-10" from seat. Work upldwn finally pull w/40k. No major scarring on test plug, Some metal shavings around seal could possibly have come from drilling EZSV's from previous well and from within the BOP ram cavities. 19:30 - 20:00 0.50 BOPSUR P PROD1 P/U ported sub and flush stack with freshwater. 20:00 - 20:15 0,25 BOPSUR P PROD1 Install wear bushing. 20:15 - 21:00 0.75 DRILL P PROD1 Service topdrive and crown. 21 :00 - 00:00 3.00 DRILL P SURF Pick-up 4" dp and stand in derrick. 6/23/2002 00:00 - 04:00 4,00 DRILL P PROD1 Continue plu DP and stand back in derrick. Total 40 stands, 04:00 - 06:00 2,00 DRILL P PROD1 P/U BHA #4 and 4 jts dp. 06:00 - 06:30 0.50 DRILL P PROD1 Fill pipe. Close annular and test TAM collar to 1000 psi - ok. Bit depth 1054', TAM 1018'. 06:30 - 07:30 1.00 DRILL P PROD1 Cut and slip drilling line. Check brakes. 07:30 - 08:30 1,00 DRILL P PROD1 Pick-up 48 jts DP while RIH. 08:30 - 09:30 1,00 DRILL P PROD1 Perform "kill drill" wI toolpusher and co-rep. All hands operated choke. 09:30 - 10:30 1.00 DRILL P PROD1 RIU test equipment and test casing to 3500 psi f/30 min. Test OK. 10:30 - 11 :00 0,50 DRILL P PROD1 RIH tagged up on hard cement at 2590'. 11 :00 - 12:30 1.50 DRILL P PROD1 Drill cement and shoe track. FC @ 2634' FS @ 2719', Cleanout rathole to 2728'. Drill new formation to m2748'. 104k up 871 dwn 94k rt 500 gpm @ 1720 psi. Tq off 2500 on 3200, 12:30 - 13:00 0,50 DRILL P PROD1 Pump spacer and follow with new 9.5 ppg LSND mud. Circulate to surface. 13:00 - 13:30 0.50 DRILL P PROD1 Pull up into surface csg. Perform LOT to 12.2ppg EMW, 13:30 - 14:00 0.50 DRILL P PROD1 Finsih cleaning mud pits for new mud. 14:00 - 14:30 0,50 DRILL P PROD1 Circulate. Obtain SP rates, baseline ECD of 10.0ppg 14:30 - 20:00 5.50 DRILL P PROD1 Directionally drill fl 2748' to 3917'. Backreaming each stand. Pumping sweep every 200'. wob 4-18k, 600 gpm @ 2200 psi ECD's 10,5-7, TD rpm 80 on bottom 380. Tq 4500 on bottom, 3200 off. PU wt 115k, dwn 92k, rt 100k. Rotating time: 2.60 hr Sliding time: .1 hr 20:00 - 21 :00 1.00 DRILL P PROD1 Circulate sweep reduce ECD's to 10.4ppg. 21 :00 - 21 :30 0.50 DRILL P PROD1 Wiper trip to shoe, TOH to 3624' pulling progressively tighter, 20-30k over. 21 :30 - 00:00 2.50 DRILL P PROD1 M/U topdrive backream fl 3654' to 2850', Varying pumps rates watching ECD's. 6/24/2002 00:00 - 00:15 0.25 DRILL P PROD1 Continue to backream to surface csg at2720', High ECD reduce pump to 380 gpm through most backreaming. 00:15 - 00:45 0.50 DRILL P PROD1 Circulate sweep to surface. 00:45 - 01 :15 0.50 DRILL P PROD1 Service topdrive 01:15 - 02:00 0.75 DRILL P PROD1 TIH wash last stand to bottom, No fill. 02:00 - 12:30 10.50 DRILL P PROD1 Directionally drill f/3917' to 5596'. Backreaming each stand, Pumping sweep every 200'. wob 5-10k, 600 gpm @ 2950 psi-off 3250 psi on bottom, ECD's 10,5, TD rpm 80-100 on bottom 380-400. Tq 6600 on bottom, 3200 off, PU wt 120k, dwn 94k, rt 101 k. Sliding time: 1.0 Rotating time: 4,18 I Printed: 7/10/2002 12:21:15 PM ) ) BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-108 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From- To Hours Task Code NPT Phase Description of Operations 6/24/2002 12:30 -14:00 1.50 DRILL P PROD1 Circulate high-low-high vis sweeps at 600 gpm, 14:00 -18:30 4.50 DRILL P PROD1 Wiper trip to 3450'. Pulled first 9 stds then backreamed remainder. Able to pump at 600 gpm with a max of 11.7 ECD seen. No problems back in the hole, Pumped hi-vis sweep at bottom. 18:30 - 00:00 5,50 DRILL P PROD1 Directionally drill fl 5596' to 6446'. Backreaming each stand. Pumping sweep every 200', wob 15-20k, 600 gpm @ 3130 psi-off 3500 psi on bottom, ECD's 11.0, TD rpm 100 on bottom 400. Tq 8.5-1 Ok on bottom, 6.7,2k off, PU wt 161 k, dwn 11 Ok, rot 131k, Sliding time: .4 Rotating time: 2.3 6/25/2002 00:00 - 08:00 8.00 DRILL P PROD1 Directionally drill f/6446' to 7182'. Backreaming each stand. Pumping sweep every 200'. wob 15-20k, 550 gpm @ 3130 psi-off 3500 psi on bottom, ECD's 11,0, TD rpm 100 on bottom 400. Tq 6.5k on bottom, 5k off, PU wt 163k, dwn 123k, rot 142k, Reducing mud vol at 6900' to make way for addition of new weighted mud. Raise to 10.1 by 7200', 08:00 - 09:30 1.50 DRILL P PROD1 Circulate & pump hi-Io sweeps around @ 600 gpm, 100 RPMs, 3430 psi, rotate & reciprocate string. Calc. ECD 10.73, actual ECD 11.04. 09:30 - 12:00 2.50 DRILL P PROD1 POOH from 7182 to 6155'. Pulling 10/15K over & swabbing, Work pipe to get correct displacement. Backream from 6155 to 5500'. 12:00 - 14:00 2,00 DRILL P PROD1 Circulate & pump Hi-Lo sweeps @ 5500'. 445 gpm, 1925 psi, 100 rpms, reciprocate pipe & lower ECDs, getting full returns. Calc ECD 10.73, actual ECD 11.04. 14:00 - 14:30 0.50 DRILL P PROD1 POOH dry to 5100'. Started swabbing & pulling tight. 14:30 - 18:30 4.00 DRILL P PROD1 Attempt to break circulation, no good. RIH to 5500', break circulation full returns. ECD 11,32. Begin backreaming out of hole from 5500' to shoe monitoring ECDs & returns. OK. 530 gpm, 2200 psi, 100 rpms. Sytarted to pack-off. Reduced pump rate & establish returns. Con't to POOH to shoe. 18:30 - 19:00 0.50 DRILL P PROD1 Pump Hi-Lo sweeps @ shoe. 650 gpm, 2700 psi, 110 rpms. Recoverd abundance of cuttings. Monitor well, OK. 19:00 - 19:30 0.50 DRILL P PROD1 Service topdrive. 19:30 - 22:00 2.50 DRILL P PROD1 Change out liners & swabs to 5" in both mud pumps. Test, OK. 22:00 - 00:00 2.00 DRILL P PROD1 PIU WT 100K, SIO WT 90K @ Shoe. RIH to 5000' fill pipe & break circulation. Full returns. Con't RIH to 7090'. 6/26/2002 00:00 - 00:30 0.50 DRILL P PROD1 CON'T TO TIH TO 7088' M/U TD & FILL PIPE. BREAK CIRCULATION SLOWLY. 00:30 - 02:00 1.50 DRILL P PROD1 CIRCULATE HI-LO SWEEP AROUND & CLEAN UP HOLE. ECD 10.62 580 GPM, 3200 PSI, PIU 176K, SIO 122K, ROT 134K. 02:00 - 20:00 18.00 DRILL P PROD1 DIRECTIONAL Y DRILL FROM 7182 TO 8294'. BACKREAMED EVERY STAND & PUMPED SWEEPS EVERY 200'. WOB 10-13K, 580-600 GPM, @ 3270 PSI OFF BOTTOM & 3450 PSI ON BOTTOM. ECDs 10.7 TO 10,7, TD RPM 110, TORO ON BOTTOM 9K, OFF 8K. P/U 195K, SIO 131K, ROT WT 160K. CALC ECD 10,62, ACTUAL 10.65, Printed: 7/10/2002 12:21:15 PM ) ) Page 5 or9 BPEXPLORATION OpetationsSummäry Repo.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-108 L -1 08 DRILL +COMPLETE NABORS NABORS 9ES Date From- To Hours Task Code NPT Phase 6/26/2002 20:00 - 21 :00 1.00 DRILL P 21 :00 - 00:00 3,00 DRILL P 00:00 - 00:30 0.50 DRILL P 00:30 - 01 :00 0,50 DRILL P 01 :00 - 03:30 2.50 DRILL P 03:30 - 05:00 1.50 DRILL P PROD1 PROD1 6/27/2002 PROD1 PROD1 PROD1 PROD1 05:00 - 07:00 2.00 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 10:30 2.50 DRILL P 10:30 - 12:30 2.00 DRILL P 12:30 - 13:00 0.50 DRILL P 13:00 - 21 :30 8.50 EVAL P 21 :30 - 22:30 1.00 CASE P 22:30 - 23:00 0.50 P 23:00 - 00:00 1.00 CASE P 6/28/2002 00:00 - 01 :30 1.50 CASE P 01 :30 - 02:00 0,50 CASE P 02:00 - 04:00 2.00 CASE P 04:00 - 04:30 0.50 CASE P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP 04:30 - 00:00 19.50 CASE P COMP 6/29/2002 5.50 CASE P COMP 00:00 - 05:30 05:30 - 06:00 0.50 CASE P COMP 06:00 - 08:30 2.50 CASE P COMP 08:30 - 11 :00 2.50 CASE P COMP Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Description of Operations CIRCULATE & PUMP HI-LO SWEEPS @ 600 GPM & CLEAN HOLE. MONITOR WELL, PULL 10 STANDS, HOLE CLEAN. PUMP PILL & CON'T POOH FOR WIPER TRIP TO SHOE. CON'T TO POOH TO SHOE. (60 STDS) MONITOR WELL, OK. SERVICE TOP DRIVE & CROWN. TRIP BACK IN HOLE TO 8294'. FILL PIPE, BRING ON PUMP SLOWLY UP TO FULL CIRCULATING RATE. PUMP HI-LO SWEEP. SPOT EZ-GLlDE PILL ON BOTTOM FI LOGGING, PULL OUT OF HOLE FROM 8294 TO 5500'. SPOT STEEL SEAL PILL, MONITOR WELL, OK. PUMP DRY JOB. CON'T TO PULL OUT OF HOLE TO CSG SHOE.MONITOR WELL, OK, CON'T TO PULL OUT TO BHA. STAND BACK HWDP & LID BHA #4, CLEAN & CLEAR RIG FLOOR. PJSM, RIU SCHUM BERGER. MIU LOGGING TOOLS. RIH & LOG AS PER PROGRAM. RID LOGGERS, PULL WEAR BUSHING & MAKE DUMMY RUN WI LANDING JT & HANGER. STACK FILL OF CLAY. MIU PORTED SUB & WASH OUT CLAY IN BOP STACK. INSTALL TEST PLUG. CHANGE OUT UPPER RAMS TO 7" FOR CASING JOB. FINISH CHANGING UPPER RAMS FOR 7" CSG. TEST DOOR SEALS TO 3500 PSI LID JARS & 5" HWDP, RIU CSG EQUIP. & HOLD PJSM. M/U SHOE TRACK & INSTALL BAFFLE ON TOP OF FLOAT COLLAR. MIU LANDING COLLAR ASSY. RIU FRANKS TOOL. CIRCULATE THRU SHOE TRACK & CHECK FLOATS. OK. RUN 7" PRODUCTION CASING. FILL EVERY JT & BREAK CIRCULATION EVERY 3 JTS. CIRCULATE BOTTOMS UP EVERY 1000'. FINISH RUNNING 7" PRODUCTION CASING. RAN 202 JTS. SET @ 8278.83' FLOAT @ 8235, LANDING COLLAR @ 8194'. RA MKR JT #1 @ 8051'. RA MKR JT #2 @ 7624'. ES CEMENTER @ 5629'. LAND CASING @ 8279'. RID FRANKS TOOL. BLEED DOWN TOP DRIVE. M/U CEMENTING HEAD & CIRCULATING LINES, BREAK CIRCULATION SLOWLY & INCREASE TO 6.5 BPM @ 752 PSI. RECIPROCATE CASING 20 ' STROKES. 1/MIN. CIRCULATE & CONDITION MUD PRIOR TO CEMENTING. HELD PJSM, CEMENT 1st STAGE AS FOLLOWS:PUMP 5 BBLS WATER, TEST LINES RO 4000 PSI, PUMP 5 BBLS WATER, MIX & PUMP 35 BBLS OF ALPHA SPACER @ 6 BPM, 460#. BATCH MIX & PUMP 43.9 BBLS OF PREMIUM "G" LEAD CEMENT WI ,35% CFR-2, 1% GEL, 2 GPS LATEX 2000, .36 GPS 434-B. YLD 1.19 CFISX, WT 15.6 PPG, APR 6,5 BPM, APP Printed: 7/10/2002 12:21:15 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ") BP EXPLORATION Operations Summary Report Page 6of9 L -1 08 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From.;.To Hours Task Code NPT Phase Description of Operations. 6/29/2002 08:30 - 11 :00 2.50 CASE P COMP 500#. DROP PLUG & DISPLACE W/315 BBLS OF 10.1 PPG MUD, BP WI 1200 PSI, FLOAT HELD. 11 :00 - 12:30 1.50 CASE P COMP PRESSURE UP TO 2900 PSI & SHIFT OPEN ES-TOOL. CIRCULATE 2 ANNULAR VOLUMES. 12:30 - 14:00 1.50 CASE P COMP CEMENT 2nd STAGE AS FOLLOWS:PUMP 10 BBLS WATER, MIX & PUMP 35 BBLS ALPHA SPACER @ 5.5 BPM, 320 PSI. BATCH MIX & PUMP 61.5 BBLS PREMIUM "G" TAIL SLURRY WI 2% CAL-SEAL, 3% KCL,.5% LAP-1. YLD 1.22 CFISX, WT 15.6 PPG APR 7 BPM, APP 525 PSI. DROP PLUG & DISPLACE W/210 BBLS OF 10.1 PPG MUD. BP TO 2100 PSI & SHIFT ES CEMENTER CLOSED. PLUG HELD, OK. CMT IN PLACE @ 1400 HRS 6-29-02. 14:00 - 14:30 0.50 CASE P COMP RID CEMENTING EQUIP. BREAK OUT LANDING JT. 14:30 -15:30 1.00 CASE P COMP MIU RUNNING TOOL& PACK-OFF. INSTALL & RILDS, TEST PACK-OFF TO 5000 PSI, OK. 15:30 - 16:30 1,00 CASE P COMP RID CASING TOOLS, CLEAR FLOOR & CHANGE BAILS. 16:30 -17:30 1.00 CASE P COMP INSTALL 31/2" X 6" UPPER VARIABLE RAMS, 17:30 - 18:00 0.50 CASE P COMP RIU EQUIP FOR BOP TEST. 18:00 - 21 :00 3.00 CASE P COMP PRESSURE TEST BOPE. TEST WITNESSING WAIVED BY JEFF JONES WI AOGCC, HP 4000 PSI, LP 250 PSI. ANNULAR 3500 PSI. 21 :00 - 21 :30 0.50 CASE P COMP RID TESTING EQUIP & BID LINES. 21 :30 - 23:00 1.50 CASE P COMP MIU BHA #5 & RIH. 23:00 - 00:00 1,00 CASE P COMP CUT & SLIP 80' DRILLING LINE 6/30/2002 00:00 - 00:30 0,50 CASE P COMP FINISH SERVICING RIG & TOP DRIVE. 00:30 - 02:30 2.00 CASE P COMP RIH TO 5450 WI 4" DP. FILL PIPE@ 2800', 02:30 - 04:30 2.00 CASE P COMP MIU TOP DRIVE. FILL DP, WASH 2 STANDS TO BOTTOM, NO FILL. TAG UP ES CEMENTER @ 5629', DRILL UP CEMENT PLUG. 250 GPM, 925 PSI,60 RPM, 8-13K WOB, 4.5-5 TORQ, ROT 114K, PIU 150K, SIO 99K. 04:30 - 05:00 0.50 CASE P COMP CIRCULATE HI-VIS SWEEP. 400 GPM, 2250 PSI, 60 RPM. 05:00 - 06:30 1 ,50 CASE P COMP RIH WI 4" DP TO 7955'. 06:30 - 08:30 2.00 CASE P COMP M/U TOP DRIVE, FILL PIPE & WASH DOWN TO LANDING COLLAR @ 8194', PIU & CIRCULATE HI-VIS SWEEP. 420 GPM, 2690 PSI, 60 RPM, 8K TORQ,PIU 203K, SIO 117K, ROT 143K. FOLOW SWEEP WI SEAWATER. 08:30 - 09:00 0.50 CASE P COMP CLEAN POSSUM BELLY & SHAKER AREA. FLUSH PUMPS & ALL LINES WI SEAWATER. 09:00 - 10:00 1,00 CASE P COMP DISPLACE WELL WI 9.1 PPG KCI BRINE @ 10 BPM, 2080 PSI, 60 RPM, 7K TORQ, ROT 150K, 10:00 - 11 :30 1,50 CASE P COMP POOH TO 5400'. 11 :30 - 12:00 0,50 CASE P COMP SPOT PERF PILL ACROSS SCHRADER, FROM 5400' TO 2700', 12:00 - 13:00 1.00 CASE P COMP POH WI 4" DP. 13:00 - 14:00 1.00 CASE P COMP UD BIT & BHA EQUIP. STAND BACK DC & HWDP, 14:00 - 15:30 1,50 EVAL P COMP PJSM, RIU SCHLUMBERGER. RIH TO 150', USIT TOOL NOT WORKING CORRECTLY, 15:30 - 16:30 1,00 EVAL N DFAL COMP POOH & UD& CHANGE OUT LOGGING HEAD. 16:30 - 20:00 3,50 EVAL P COMP RIH TO 8173' & LOG WI USIT TOOL. TOC IN KUPARUK @ +1-7210'. TOC IN SCHRADER@ +/-4350' POOH & UD LOGGING TOOLS. 20:00 - 21 :00 1.00 CASE P COMP RIU &TEST 7" PRODUCTION CASING. TEST TO 4000 PSI, 30 MIN, TEST,OK. CHARTED SAME. Printed: 7/10/2002 12:21:15 PM ) ) BP EXPLORATION Operations Surnmary Report Page 7 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-108 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From- To Hours Task Code NPT Phase Descri ption of Operations 6/30/2002 21 :00 - 22:00 1.00 PERF P COMP PJSM, MIU PERFGUNS & FIRING HEAD, RIH ON 1 STAND OF HWDP. 22:00 - 00:00 2.00 PERF P COMP RIH WI HWDP + 4" DP @ 1 MIN/STAND. 7/1/2002 00:00 - 01 :00 1.00 PERF P COMP CON'T TO RIH WI PERF GUN ASSY @ 1 STAND/MIN. 01 :00 - 03:00 2.00 PERF P COMP PJSM. RIU SCHLUMBERGER. RIH WI GRICCL & CORRELATE DEPTH WI PERF GUNS, PERFORATE 4958-5006',5042-5080',5096-5116', 5167-5184', 5235-5276', ALL @ 5 SPF, 4 5/8" GUN, 03:00 - 04:00 1.00 PERF P COMP M/U TOP DRIVE. FILL LINES, TEST SURFACE EQUIP TO 3000 PSI, OK, PRESSURE UP TBG & ANNULUS TO 2500 PSI, BLEED OFF PRESSURE & MONITOR. GUNS FIRED ON SOUND RECORDER. 1 BBL LOSS. MONITOR WELL. WELL STATIC & HOLE FULL. PIU 137K, SIO 98K. 04:00 - 05:00 1.00 PERF P COMP REVERSE CIRCULATE THRU BYPASS, NO LOSSES & NO GAS TO SURFACE.MONITOR WELL, WELL DEAD. 05:00 - 07:00 2.00 PERF P COMP BLOW DOWN LINES. POOH WI DP TO 1000' MONITOR WELL,OK. 07:00 - 09:30 2,50 PERF P COMP PJSM. LID PERF GUNS, ALL SHOTS FIRED, ..-r 09:30 - 10:00 0,50 PERF P COMP CLEAN & CLEAR FLOOR. RID ALL PERF EQUIP, 10:00 - 11 :30 1.50 PERF P COMP MIU BHA WI BIT & SCRAPER FOR CLEAN OUT RUN, RIH WI DC & HWDP. 11 :30 - 14:00 2.50 PERF P COMP RIH 4" DP, LC 8194', BREAK CIRC, WORK BOOT BASKETS 14:00 - 15:30 1.50 PERF P COMP DISPLACE HOLE WI 9.1 PPG CLEAN BRINE @ 9 BPM, 1850 PSI, 70 RPM, TORQ 8.4K. MONITOR WELL,OK. 15:30 - 19:30 4,00 PERF P COMP POH & LID DRILL STRING. (CONDUCTED LOT OA. EMW 12.67 PPG, INJECTED 40 BBL OF 10,1 PPG MUD & 66 BBLS OF DEAD CRUDE @ 3 BPM, 600 PSI., AS FREEZE PROTECTION. 19:30 - 20:30 1,00 RUNCOI\tP COMP CUT & SLIP 50' DRILLING LINE 20:30 - 21 :30 1.00 RUNCOI\tP COMP STAND BACK HWDP, LID DCS. CLEAN OUT BOOT BASKETS. (RECOVER 1 1/2 GAL METAL SHAVINGS & CMT) 21 :30 - 22:30 1.00 RUNCOI\tP COMP PULLWEAR BUSHING. PIU JANDING JT & MAKE DUMMY RUN. CHANGE BAILS. 22:30 - 00:00 1,50 RUNCOI\tP COMP RlU COMPLETION RUNNING TOOLS & EQUIP, 7/2/2002 00:00 - 13:00 13.00 RUNCOI\tP COMP MIU TAIL PIPE ASSY & RIH. RIH W/31/2" 9,2" & 4 1/2" 12.6# L-80 TCII TBG. RAN 88 JTS 3 1/2" & 119 JTS 4 1/2" TBG. MIU @ 2200 & 2900 FTILBS TORQUE RESPECTIVELY. SEE TBG DETAIL REPORT 13:00 - 14:00 1.00 RUNCOI\tP COMP MIU TBG HANGER ON LANDING JT RlU CIRCULATING LINES, RUN IN & VERIFY HANGER SEAT PIU ABOVE TABLE. 14:00 - 15:30 1.50 RUNCOI\tP COMP REVERSE CIRCULATE CLEAN 9.1 PPG KCL WI COREXIT @ 3 BPM, 3200 PSI. 15:30 - 16:00 0.50 RUNCOI\tP COMP LAND TBG HANGER RILDS. 16:00 - 20:00 4.00 RUNCOIVN DFAL COMP DROP BALL & ROD. RID CIRC LINES, BACK OUT LANDING JT PRESSURE UP TO 4200 PSI TO SET PACKERS. TBG LEAKING OFF. ATTEMPT TO FIND LEAK - NO SURFACE LEAKS OR FLUID FROM IA. RE-PRESSURE TUBING TO 4200 PSI AND MAINTAN PRESSURE WITH RIG PUMP TO ENSURE BOTH PACKERS SET HAVING TO PUMP 2-3 SPM TO MAINTAIN APPROX 4200 PSI FOR 10-15 MIN, POSS INJ MANDREL LEAKING, PRESSURE UP ON BACKSIDE & TEST ANNULUS TO 1500 PSI. HELD 30 MIN - OK. Printed: 7/10/2002 12:21:15 PM ) ) BP EXPLORATION Operations Summary ..Report Page 8 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-108 L -1 08 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 Date From- To Hours Task Code NPT Phase Description of Operations 7/2/2002 16:00 - 20:00 4.00 RUNCOIVN DFAL COMP VERIFIES PREMIER PACKER SET. CALL FOR SLlCKLlNE EQUIP. WAIT ON EQUIP. 20:00 - 00:00 4,00 RUNCOIVN DFAL COMP HOLD PJSM. RIU HALLIBURTON SLlCKLlNE EQUIP. RIH WI OIS TO RETRIEVE BALL/ROD. ROD ON DEPTH @ 7548'. POOH WI SAME. 7/3/2002 00:00 - 02:00 2,00 RUNCOIVN DFAL COMP RUN #2 MIU "XX" PLUG. RIH TO 7527' & ATTEMPT TO SET. PLUG PARTIALLY SHEARED, (MISS RUN) POOH WI PLUG, 02:00 - 05:30 3.50 RUNCOIVN DFAL COMP RUN #3 INSPECT & REDRESS PLUG. RIH & SET IN "X" NIPPLE @ 7527'. POOH. 05:30 - 06:00 0,50 RUNCOIVN DFAL COMP PRESSURE UP ON TBG & ATTEMPT TO TEST. PRESSURE BLED OFF FROM 4000 PSI TO 1000 PSI IN 10 MIN, 06:00 - 07:00 1,00 RUNCOIVN DFAL COMP RUN #4 RIH ON SLlCKLlNE & SET CATCHER @ 5441' 07:00 - 08:30 1.50 RUNCOIVN DFAL COMP RUN #5 RIH & RETRIEVE UPPER DUMMY VALVE @ 4825', POOH. 08:30 - 09:30 1.00 RUNCOIVN DFAL COMP CHANGE OUT DUMMY VALVE. RUN #6 RIH & ATTEMPT TO INSTALL DUMMY (MISS RUN). POOH. 09:30 - 10:30 1,00 RUNCOIVN DFAL COMP CHANGE OUT DUMMY VALVE RUN #7. RIH & SET DUMMY IN UPPER GLM @ 4825'. 10:30 - 11 :00 0.50 RUNCOIVN DFAL COMP PRESSURE UP ON TBG & ATTEMPT TO TEST TO 4000 PSI. NO GOOD BLED OFF AS BEFORE. 11 :00 - 19:30 8,50 RUNCOIVN DFAL COMP RUN #8 RIH & RETRIEVE DUMMY VALVE @ 4867', POOH, CHANGE OUT DUMMY VALVE. RIH & SET DUMMY @ 4867'. ATTEMPT TO TEST TBG TO 4000 PSI, NO GOOD. RIH & RECOVER CATCHER. MIU 41/2""XX" PLUG RIH & SET IN "X" NIPPLE @ 4758'. PRESSURE UP ON TBG & TEST TO 4000 PSI, 10 MIN OK. POOH & RID SLlCKLlNE EQUIP. PER DISCUSSION WITH ANCH OFFICE & NSPE'S, WILL MOVE OFF FOR PE GROUP TO RUN ADDITIONAL DIAGNOSTICS FOR LEAK DETECTION. 19:30 - 20:00 0.50 RUNCOrvP COMP INSTALL TWC VALVE & PRESSURE TEST TO 2800 PSI, OK. 20:00 - 21 :30 1.50 BOPSUR P COMP NID & SET BACK BOPE. 21 :30 - 23:00 1,50 WHSUR P COMP NIU & TEST ADAPTER FLANGE & XMAS TREE. TEST TO 5000 PSI - OK. 23:00 - 00:00 1.00 WHSUR P COMP RlU DSM & PULL TWC. (700 PSI ON TBG) 7/4/2002 00:00 - 02:00 2.00 WHSUR COMP PULLED TWC. HAD 700 PSI ON IT. BLED TBG TO O. NO PRESSURE ON ANNULUS. RIU & CIRC DOWN ANNULUS & UP TBG, OK. SWITCHED TO PUMP DOWN TBG & OUT ANNULUS. STARTED TO CIRCULATE, THEN PRESSURED UP. RP SHEAR APPEARS TO GO BACK ON SEAT & ACT AS A CHECK VALVE. 02:00 - 03:30 1.50 WHSUR N DFAL COMP PJSM. RID CIRC LINES. DRAIN UP PUMP & EQUIP.. SUCK OUT FLUID IN MUD PITS. WAIT ON SLlCKLlNE 03:30 - 08:30 5.00 WHSUR N DFAL COMP PJSM. RlU SLlCKLlNE EQUIP. RIH & CATCHER @4741'. POOH. 08:30 - 10:00 1.50 WHSUR N COMP RlU TO PULL RP SHEAR VALVE. RIH & ATTEMP TO RECOVER, MISS-RUN. POOH. 10:00 - 12:30 2.50 WHSUR N DPRB COMP MIU NEW TOOL, RIH & PULL RP SHEAR VALVE. POOH WI SAME. RID SLlCKLlNE EQUIP. 12:30 - 14:00 1.50 WHSUR P COMP RlU HOT OILER. TEST LINES TO 3000 PSI, OK. PUMP 87 BBLS DIESEL DOWN ANNULUS FOR FREEZE PROTECTION. SID & RIU & ALLOW DIESEL TO U-TUBE.. RID CIRC LINES, Printed: 7/10/2002 12:21:15 PM ) ') BP EXPLORATION Operations Summary Rep.ort Page 90f 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L-108 L-108 DRILL +COMPLETE NABORS NABORS 9ES Start: 6/17/2002 Rig Release: 7/4/2002 Rig Number: 9-ES Spud Date: 6/18/2002 End: 4/5/2002 7/4/2002 From - To Hours Task Code NPT Phase 14:00 - 15:00 1.00 WHSUR P CaMP 15:00 - 16:00 1.00 WHSUR P CaMP 16:00 - 00:00 8,00 SANDOJ\ P CaMP Description of Operations RIU DSM & INSTALL BPV IN TBG HANGER. TEST SAME TO 1000 PSI, OK. SECURE TREE & CLEAN UP CELLAR AREA.. MOVE OUT PIT COMPLEX AWAY FROM RIG FOR ACCESS TO L-106. RID RIG. DO MAINTAINANCE ON EQUIP. REMOVE ROTARY TABLE & INSPECT TRACTION ON TD. CHECK BEARING ETC. PRESSURE WASH DERRICK. RIU & WIRELlNE ON L-106 PRIOR TO MOVE ON. SET PLUG IN "X" NIPPLE. BLOW DOWN WELL TO LINE PRESSURE. RELEASE RIG @ 2400 HRS, 7-4-02. MOVE OFF TO L-105, Printed: 7/10/2002 12:21:15 PM ) ) Well: Field: API: Permit: L-108i Prudhoe Bay Unit 50-029-23090-00 202-109 Rig Accept: 06/18/02 Rig Spud: 06/18/02 Rig Release: 07/04/02 Drilling Rig: Nabors 9ES POST RIG WORK 07/26/02 MIT COMBO TUBING/IA. CMIT T X IA TO 2500 PSI PASSED. 07/30102 PULL STA# 5,111 DGLV BK ---- SET STA# 5 LGLV,( 1/411 1650# )--- SET STA# 3 OGLV (5/16). 07/31/02 FINISH SETTING STA# 3 OGLV--- PULL 4 1/211 WHIDDON C-SUB--- EQUALIZE & PULL 41/211 XX PLUG FROM 4758' --- RMDO---- LEAVE WELL SHUT IN--- POST RIG--NOTIFY AND HANG TAG THAT TWO PLUGS STILL IN HOLE @ 7527' & 7548'. CMIT TXIA MIT T. 08/01/02 MIT T (INCONCLUSIVE). LEAK RATE LESS THAN 2.2 GPM @ 2500 PSI. POSSIBLE TTP LEAKING. NO INDICATION OF T X IA COMMUNICATION DURING PUMPING OPERATIONS. 08/03/02 LDL. LOG BASELINE PASS DOWN FROM SURFACE AT 120 FPM. PUMPING METH DOWN TUBING AT 2000 PSI - 2500 PSI USING TRIPLEX (PLUG IN TUBING AT 7500') TO LOOK FOR 2.5 GPM LEAK. LOG UP AT 120 FPM FROM 7500' TO SURFACE. LOCATED TEMPERATURE ANOMALY NEAR PACKER AT 4769'. ANOMALY REPEATED. LOG OUT OF HOLE. 8 BBL METH TOTAL PUMPED OVER 2 HOURS = LEAK RATE OF 2.8 GPM. NOTIFY PAD OP OF WELL STATUS: LEFT SHUT IN. LEAK DETECTION LOG MAINTAIN 2500 PSI ON TBG. 08/06/02 (WELL SHUT IN ON ARRIVAL) DRIFT, PULL 31/2 XX PLUG @ 7492' SLM, PULL OGLV STA 3, PULL LGLV STA 5, SET GENERIC GAS LIFT DESIGN, PULL 31/2 RHC-M PLUG, DfT W/ 21/211 X 10' DG TEL SB TAG TD @ 8195' CORR TO MD SAND IN SB RDMO ( WELL SHUT IN ). ANADRILL SCHLUMBERGER Survey report Client. . . . . . . . . . . . . . . . . . .: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: L-108i API number...............: 50-029-23090-00 Engineer.................: St. Amour COUNTY:................ ..: Nabors 9ES STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference. . . . . . . . . .: Drill Floor GL above permanent.......: 49.90 ft KB above permanent.......: N/A DF above permanent.......: 78.40 ft ----- Vertical section origin---------------- Latitude (+N/S-)..... ....: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.35023011 Departure (+E/W-)........: W 149.3234688 Azimuth from rotary table to target: 146.30 degrees 27-Jun-2002 05:51:49 Spud date.. ...... .... ....: Last survey date. ..... ...: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 18-Jun-02 27-Jun-02 93 0.00 ft 8294.00 ft ---- ----- Geomagnetic data ---------------------- Magnetic model... .... ....: BGGM version 2001 Magnetic date. ....... ....: 18-Jun-2002 Magnetic field strength..: 1149.53 HCNT Magnetic dec (+E/W-) .....: 25.99 degrees Magnetic dip... ....... ...: 80.77 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H.. . . . . . . . . . : 0 f Dip........ . : Criteria --------- 1002.68 mGal 1149.53 HCNT 80.77 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees - ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.89 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N).. ......: No degree: 0.00 -------- -------- Seq Measured # depth (ft) -------- -------- 1 2 3 4 5 0.00 50.00 100.00 150.00 173.00 6 7 8 9 10 265.00 355.00 448.00 540.00 634.00 11 12 13 14 15 725.00 820.00 944.31 1037.08 1128.87 16 17 18 19 20 1223.97 1317.67 1410.58 1505.08 1599.27 21 22 23 24 25 1692.13 1783.36 1877.85 1971.03 2064.47 26 27 28 29 30 2157.29 2251.09 2344.81 2438.48 2532.26 ------ ------ Incl angle (deg) ------ ------ 0.00 0.16 0.38 0.28 0.32 1.01 1.82 2.84 3.10 3.71 3.43 2.29 1.60 1.90 4.14 5.29 6.47 7.29 8.70 8.96 10.03 10.89 11.94 13.44 15.01 18.30 22.45 26.21 31.23 35.39 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 0.00 337.62 303.00 280.06 287.17 321.27 318.89 330.16 328.83 334.74 339.81 352.52 25.56 101.22 128.86 137.51 141.39 147.12 148.58 148.03 148.90 150.43 149.49 152.13 149.01 147.70 148.23 147.15 148.94 151.28 ------ ------ 0.00 50.00 50.00 50.00 23.00 92.00 90.00 93.00 92.00 94.00 91.00 95.00 124.31 92.77 91.79 95.10 93.70 92.91 94.50 94.19 92.86 91.23 94.49 93.18 93.44 92.82 93.80 93.72 93.67 93.78 -------- -------- TVD depth (ft) -------- -------- 0.00 50.00 100.00 150.00 173.00 264.99 354.96 447.89 539.76 633.60 724.42 819.30 943.54 1036.28 1127.94 1222.72 1315.92 1408.17 1501.74 1594.82 1686.40 1776.12 1868.74 1959.64 2050.21 2139.13 2227.04 2312.42 2394.54 2472.90 -------- -------- Vertical section (ft) -------- -------- 0.00 -0.07 -0.29 -0.53 -0.61 -1.62 -3.83 -7.59 -12.35 -17.90 -23.46 -27.92 -31.04 -30.62 -26.38 -18.77 -9.24 1.87 15.00 29.45 44.76 61.29 79.95 100.35 123.24 149.83 182.46 221.05 266.02 317.39 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) --------~------- --------~------- 0.00 0.06 0.22 0.33 0.36 1.07 2.76 5.88 9.98 14.91 20.12 24.67 28.70 29.57 27.19 21.81 14.50 5.46 -5.68 -17.98 -31.04 -45.34 -61.52 -79.40 -99.37 -122.00 -149.69 -182.30 -220.50 -265.17 0.00 -0.03 -0.19 -0.45 -0.57 -1.32 -2.76 -4.87 -7.30 -9.91 -12.11 -13.33 -12.91 -10.84 -6.77 -1.13 5.08 11.55 18.53 26.12 34.13 42.49 51.85 61.81 73.12 87.10 104.40 125.06 148.82 174.43 --------------- --------------- Total displ (ft) At Azirn (deg) --------------- --------------- 0.00 0.07 0.29 0.56 0.67 1.70 3.90 7.63 12.36 ,17.90 23.48 28.05 31.47 31.49 28.02 21.84 15.36 12.77 19.38 31.71 46.13 62.13 80.46 100.62 123.3'8 149.90 182.50 221.07 266.03 317.39 0.00 337.62 318.78 306.25 302.34 308.96 315.07 320.32 323.83 326.38 328.97 331.61 335.78 339.87 346.03 357.03 19.31 64.71 107.04 124.54 132.28 136.86 139.87 142.10 143.65 144.48 145.11 145.55 145.98 146.66 DLS (deg/ 100f) ----- 0.00 0.32 0.53 0.33 0.24 0.83 0.90 1.20 0.29 0.75 0.46 1.37 1.04 2.33 2.84 1.42 1.33 1.15 1.51 0.29 1.16 0.99 1.13 1.73 1.87 3.57 4.43 4.04 5.44 4.64 ------ ------ Srvy tool type Tool qual type ----- ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR ~ GYR GYR MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA -' MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA [(c)2002 Anadrill IDEAL ID6_1C_10] ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 31 32 33 34 35 2626.14 2666.77 2710.75 2803.98 2897.30 36 37 38 39 40 2992.24 3085.75 3179.23 3273.01 3366.84 41 42 43 44 45 3458.98 3551.21 3644.31 3737.60 3830.73 46 47 48 49 50 3923.76 4016.70 4110.18 4203.70 4296.41 51 52 53 54 55 4389.66 4485.11 4577.44 4671.74 4764.12 56 57 4858.37 4951.51 ------ ------ Incl angle (deg) ------ ------ 38.43 37.65 37.64 37.50 37.28 37.50 37.17 36.96 37.32 37.33 37.99 39.64 39.59 39.03 38.57 38.54 38.42 38.88 39.54 40.28 41.15 41.98 42.74 43.42 42.17 ------- ------- ------ ------ Azimuth Course angle length ( deg ) ( f t ) ------- ------- 150.52 150.01 150.02 150.04 150.12 149.43 149.76 149.48 149.03 148.82 149.20 149.28 149.68 148.95 148.66 148.82 148.84 148.91 150.12 149.55 149.64 149.19 148.62 148.01 147.83 41.81 147.19 40.86 145.06 ------ ------ 93.88 40.63 43.98 93.23 93.32 94.94 93.51 93.48 93.78 93.83 92.14 92.23 93.10 93.29 93.13 93.03 92.94 93.48 93.52 92.71 93.25 95.45 92.33 94.30 92.38 94.25 93.14 -------- -------- TVD depth (ft) -------- -------- 2547.96 2579.96 2614.78 2688.68 2762.82 2838.25 2912.60 2987.20 3061.95 3136.57 3209.51 3281.37 3353.09 3425.27 3497.85 3570.60 3643.36 3716.36 3788.83 3859.94 3930.62 4002.03 4070.26 4139.14 4206.92 4276.97 4346.91 27-Jun-2002 05:51:49 -------- -------- Vertical section (ft) -------- -------- 373.58 398.56 425.36 482.09 538.63 596.17 652.79 709.04 765.58 822.42 878.65 936.38 995.65 1054.67 1112.97 1170.90 1228.67 1287.00 1346.02 1405.39 1466.12 1529.35 1591.49 1655.86 1718.60 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) ---------------- ---------------- -314.42 -336.16 -359.42 -408.67 -457.78 -507.59 -556.51 -605.11 -653.77 -702.50 -750.76 -800.44 -851.58 -902.40 -952.32 -1001.88 -1051.37 -1101.35 -1152.29 -1203.72 -1256.18 -1310.69 -1363.96 -1418.77 -1471.95 1781.64 -1525.13 1843.14 -1576.21 201.86 214.27 227.70 256.09 284.36 313.38 342.08 370.58 399.52 428.89 457.87 487.44 517.59 547.74 577.97 608.06 637.99 668.17 698.16 728.05 758.83 791.05 823.18 857.02 890.35 At Azim (deg) ---------------- --------------- 373.64 398.64 425.48 482.28 538.91 596.54 653.24 709.57 766.19 823.08 879.37 937.18 996.53 1055.63 1113.98 1171.97 1229.80 1288.18 1347.29 1406.76 1467.59 1530.91 1593.12 1657.52 1720.28 147.30 147.49 147.65 147.93 148.15 148.31 148.42 148.52 148.57 148.60 148.62 148.66 148.71 148.74 148.75 148.75 148.75 148.76 148.79 148.83 148.86 148.89 148.89 148.87 148.83 924.21 1783.31 148.78 958.49 1844.76 148.70 3 of 5 ----- DLS (deg/ 100f) 3.27 2.07 0.03 0.15 0.24 0.50 0.41 0.29 0.48 0.14 0.76 1.79 0.28 0.78 0.53 0.11 0.13 0.49 1.08 0.89 0.94 0.92 0.92 0.85 1.36 ------ ------ Srvy tool type Tool qual type ----- ------ ------ MWD_IFR_MSA MWD_6_Axis MWD_Inc_Only MWD_IFR_MSA MWD_IF~MSA -- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA - MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA 0.59 MWD_IFR_MSA 1.82 MWD_IFR_MSA 58 59 60 5044.72 5138.63 5231.93 40.89 144.72 39.42 144.72 39.07 144.14 93.21 93.91 93.30 [(c)2002 Anadrill IDEAL ID6_1C_10J ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 -------- -------- 5323.34 5416.98 5510.08 5603.10 5696.52 5790.64 5883.57 5976.83 6071.67 6165.37 6259.29 6350.89 6445.52 6537.23 6631.48 6726.36 6818.19 6910.88 7004.55 7096.75 7191.83 7284.49 7377.44 ------ ------ Incl angle (deg) ------ ------ 37.44 37.75 38.15 38.78 39.18 39.27 38.40 38.40 38.50 38.85 38.80 38.76 38.97 38.18 37.93 37.70 37.77 37.73 37.48 37.39 ------- ------- ------ ------ Azimuth Course angle length (deg) (ft) ------- ------- 143.68 143.99 144.30 143.84 143.87 144.01 143.10 142.95 142.83 142.59 142.96 142.89 142.78 143.80 144.43 144.39 145.28 145.12 145.02 144.55 36.56 143.19 34.73 143.81 32.40 143.79 ------ ------ 91.41 93.64 93.10 93.02 93.42 94.12 92.93 93.26 94.84 93.70 93.92 91.60 94.63 91.71 94.25 94.88 91.83 92.69 93.67 92.20 95.08 92.66 92.95 4417.39 4489.17 4561.42 -------- -------- TVD depth (ft) -------- -------- 4633.20 4707.40 4780.81 4853.64 4926.26 4999.18 5071.56 5144.65 5218.93 5292.08 5365.25 5436.65 5510.33 5582.03 5656.25 5731.20 5803.83 5877.12 5951.32 6024.54 6100.50 6175.79 6253.24 1904.12 -1626.10 993.57 1905.62 148.57 1964.66 -1675.54 1028.55 1966.05 148.46 2023.65 -1723.55 1062.88 2024.93 148.34 27-Jun-2002 05:51:49 -------- -------- Vertical section (ft) -------- -------- 2080.19 2137.27 2194.48 2252.30 2311.01 2370.48 2428.69 2486.52 2545.39 2603.83 2662.60 2719.87 2779.14 2836.24 2894.30 2952.44 3008.62 3065.36 3122.50 3178.53 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) ---------------- ---------------- -1769.29 -1815.41 -1861.81 -1908.66 -1956.12 -2004.23 -2051.11 -2097.39 -2144.42 -2191.00 -2237.89 -2283.66 -2330.98 -2376.82 -2423.89 -2471.20 -2517.14 -2563.74 -2610.60 -2656.39 1096.22 1129.93 1163.46 1197.42 1232.08 1267.11 1301.72 1336.57 1372.15 1407.62 1443.24 1477.83 1513.70 1547.89 1581.94 1615.80 1648.17 1680.55 1713.28 1745.60 At Az im (deg) --------------- --------------- 2081.36 2138.33 2195.45 2253.18 2311.80 2371.19 2429.31 2487.06 2545.85 2604.21 2662.91 2720.13 2779.35 2836.41 2894.44 2952.56 3008.73 3065.45 3122.59 3178.60 148.22 148.10 148.00 147.90 147.79 147.70 147.60 147.49 147.39 147.28 147.18 147.09 147.00 146.93 146.87 146.82 146.78 146.75 146.72 146.69 3235.66 -2702.58 1779.31 3235.72 146.64 3289.59 -2745.98 1811.43 3289.63 146.59 3340.93 -2787.45 1841.78 3340.96 146.55 0.24 MWD_IFR_MSA 1.57 MWD_IFR_MSA 0.54 MWD_IFR_MSA 4 of 5 DLS (deg/ 100f) 1.81 0.39 0.48 0.74 0.43 0.13 1.12 0.10 0.13 0.41 0.25 0.06 0.23 1.11 0.49 0.24 0.60 0.11 0.27 0.32 ------ ------ Srvy tool type Tool qual type -- ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA .--- MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA 1.23 MWD_IFR_MSA 2.01 MWD_IFR_MSA 2.51 MWD_IFR_MSA 84 7472.40 29.52 146:48 94.96 6334.66 3389.75 -2827.49 1869.74 3389.78 146.52 3.36 MWD_IFR_MSA 85 7566.08 29.46 146.06 93.68 6416.21 3435.87 -2865.84 1895.34 3435.89 146.52 0.23 MWD_IFR_MSA 86 7658.41 29.30 145.60 92.33 6496.66 3481.16 -2903.32 1920.78 3481.19 146.51 0.30 MWD_IFR_MSA 87 7753.63 30.17 145.35 95.22 6579.34 3528.39 -2942.23 1947.55 3528.41 146.50 0.92 MWD_IFR_MSA 88 7845.83 30.65 145.27 92.20 6658.86 3575.05 -2980.60 1974.11 3575.07 146.48 0.52 MWD_IFR_MSA 89 7940.64 31.26 145.85 94.81 6740.17 3623.81 -3020.82 2001.69 3623.83 146.47 0.72 MWD_IFR_MSA 90 8033.46 31.51 145.69 92.82 6819.40 3672.15 -3060.79 2028.88 3672.16 146.46 0.28 MWD_IFR_MSA [(c)2002 Anadrill IDEAL ID6_1C_10J ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) -------- -------- 91 92 8126.12 8209.82 Projected to TD 93 8294.00 ------ ------- ------- ------ ------ ------ Incl angle (deg) Azimuth Course angle length (deg) (ft) ------ ------ ------- ------- ------ ------ 31.73 145.52 31.87 145.83 92.66 83.70 31.87 145.83 84.18 [(c)2002 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth (ft) -------- -------- 6898.31 6969.44 7040.93 27-Jun-2002 05:51:49 Page -------- ---------------- ---------------- ---------------- --------------- -------- Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- -------- ---------------- ---------------- --------------- --------------- 3720.73 -3100.87 2056.33 3720.74 146.45 3764.83 -3137.30 2081.20 3764.84 146.44 3809.27 -3174.07 2106.16 3809.28 146.43 ~>-'" 5 of 5 ------ ------ DLS (deg/ 100f) Srvy tool type Tool qual type ------ ----- ------ 0.26 MWD_IFR_MSA 0.26 MWD_IFR_MSA 0.00 Projected .--- ð L-108 Survey Report - Geodetic Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Report Date: 27 -Jun-02 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure I Slot: L-Pad / L-108 Well: L -1 08 Borehole: L -108 UWI/API#: 500292309000 Survey Name I Date: L-1 08/ June 27, 2002 Tort I AHD I DDII ERD ratio: 86,574° 13879,66 ft 15,597/0.551 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location Lat/Long: N 7021 0,828, W 149 1924.488 Location Grid NlE YIX: N 5978135,270 ftUS, E 583328.200 ftUS Grid Convergence Angle: +0.63713719° Grid Scale Factor: 0,99990789 Station ID MD Incl Azim TVD VSec NI-S (ft) n n (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 50.00 0.16 337.62 50.00 -0.07 0.06 100.00 0.38 303.00 100.00 -0.29 0.22 150.00 0.28 280.06 150.00 -0.53 0.33 173.00 0.32 287.17 173.00 -0.61 0.36 265.00 1.01 321.27 264.99 -1.62 1.07 355.00 1.82 318.89 354.96 -3.83 2.76 448.00 2.84 330.16 447.89 -7.59 5.88 540.00 3.10 328.83 539.76 -12.35 9.98 634.00 3.71 334.74 633.60 -17.90 14.91 725.00 3.43 339.81 724.42 -23.46 20.12 820.00 2.29 352.52 819.30 -27.93 24.67 944.31 1.60 25.56 943.54 -31.05 28.70 1037.08 1.90 101.22 1036.28 -30.63 29.57 1128.87 4.14 128.86 1127.94 -26.40 27.19 1223.97 5.29 137.51 1222.72 -18.80 21.81 1317.67 6.47 141.39 1315.92 -9.27 14.50 1410.58 7.29 147.12 1408.17 1.84 5.46 L-108 ASP Final Survey.xls Page 1 of 4 Schlumberger Minimum Curvature I Lubinski 146.430° N 0,000 ft, E 0,000 ft KB 78.400 ft relative to MSL 44,100 ft relative to MSL +25,875° 57499,704 nT 80.775° June 27, 2002 BGGM 2002 True North +25,875° Well Head ._~ Grid Coordinates Geographic Coordinates EI-W I DLS Northing I Easting Latitude I Longitude (ft) (° 11000) (ftUS) (ftUS) 0.00 5978135.27 583328.20 N 70 21 0.828 W 149 1924.488 -0.03 0.32 5978135.33 583328.17 N 70 21 0.829 W 149 1924.489 -0.19 0.53 5978135.49 583328.01 N 70 21 0.831 W 149 1924.493 -0.45 0.33 5978135.60 583327.74 N 70 21 0.832 W 149 1924.501 -0.57 0.24 5978135.62 583327.63 N 70 21 0.832 W 149 1924.504 -1.32 0.83 5978136.32 583326.87 N 70 21 0.839 W 149 1924.526 -2.76 0.90 5978138.00 583325.41 N 70 21 0.856 W 149 1924.568 -4.87 1.20 5978141.09 583323.26 N 70 21 0.886 W 149 19 24.63r -7.30 0.29 5978145.17 583320.79 N 70 21 0.927 W 149 19 24.70"k-- -9.91 0.75 5978150.06 583318.13 N 70 21 0.975 W 149 1924.777 -12.11 0.46 5978155.26 583315.87 N 70 21 1.026 W 149 1924.842 -13.33 1.37 5978159.79 583314.59 N 7021 1.071 W 149 1924.878 -12.91 1.04 5978163.82 583314.98 N 70211.111 W 149 1924.865 -10.84 2.33 5978164.72 583317.03 N 70 21 1.119 W 149 1924.805 -6.77 2.84 5978162.39 583321.13 N 7021 1.096 W 149 1924.686 -1.13 1.42 5978157.06 583326.83 N 7021 1.043 W 1491924.521 5.08 1.33 5978149.82 583333.12 N 7021 0.971 W 149 1924.339 11.55 1.15 5978140.85 583339.68 N 7021 0.882 W 149 1924.150 I Grid Coordinates I Geographic Coordinates I 7/18/2002-8:56 AM Station 10 MO Incl Azim TVO VSec NI-S EI-W OLS Northing Easting Latitude Longitude (ft) (°) (") (ft) (ft) (ft) (ft) (" /1 OOft) (ftUS) (ftUS) 1505.08 8.70 148.58 1501.74 14.98 -5.68 18.53 1.51 5978129.80 583346.79 N 7021 0.773 W 149 1923.946 1599.27 8.96 148.03 1594.82 29.43 -17.98 26.12 0.29 5978117.58 583354.52 N 70 21 0.652 W 149 1923.724 1692.13 10.03 148.90 1686.40 44.73 -31.04 34.13 1.16 5978104.62 583362.67 N 70 21 0.523 W 149 1923.490 1783.36 10.89 150.43 1776.12 61.27 -45.34 42.49 0.99 5978090.41 583371.18 N 70 21 0.382 W 149 1923.246 1877.85 11.94 149.49 1868.74 79.93 -61.52 51.85 1.13 5978074.33 583380.73 N 70 21 0.223 W 149 1922.972 1971.03 13.44 152.13 1959.64 100.34 -79.40 61.81 1.73 5978056.57 583390.88 N 7021 0.047 W 149 1922.681 2064.4 7 15.01 149.01 2050.21 123.23 -99.37 73.12 1.87 5978036.72 583402.41 N 702059.851 W 149 1922.351 2157.29 18.30 147.70 2139.13 149.81 -122.00 87.10 3.57 5978014.26 583416.64 N 702059.629 W 149 19 21 .943 2251.09 22.45 148.23 2227.04 182.45 -149.69 104.40 4.43 5977986.77 583434.25 N 702059.356 W1491921.437 2344.81 26.21 147.15 2312.42 221.05 -182.30 125.06 4.04 5977954.39 583455.27 N 702059.035 W 1491920.832 2438.48 31.23 148.94 2394.54 266.02 -220.50 148.82 5.44 5977916.46 583479.45 N 70 20 58.660 W 14919 20.139~' 2532.26 35.39 151.28 2472.90 317.39 -265.17 174.43 4.64 5977872.08 583505.55 N 70 20 58.220 W 1491919.390 2626.14 38.43 150.52 2547.96 373.59 -314.42 201.86 3.27 5977823.15 583533.52 N 702057.736 W 149 19 18.589 2666.77 37.65 150.01 2579.96 398.57 -336.16 214.27 2.07 5977801.55 583546.18 N 702057.522 W 149 19 18.226 2710.75 37.64 150.02 2614.78 425.38 -359.42 227.70 0.03 5977778.43 583559.86 N 702057.293 W 149 19 17.834 2803.98 37.50 150.04 2688.68 482.12 -408.67 256.09 0.15 5977729.51 583588.80 N 702056.809 W 149 19 17.004 2897.30 37.28 150.12 2762.82 538.67 -457.78 284.36 0.24 5977680.72 583617.61 N 70 20 56.326 W 149 19 16.178 2992.24 37.50 149.43 2838.25 596.22 -507.60 313.38 0.50 5977631.24 583647.18 N 70 20 55.836 W 149 19 15.330 3085.75 37.17 149.76 2912.60 652.84 -556.51 342.08 0.41 5977582.65 583676.42 N 702055.355 W 149 19 14.491 3179.23 36.96 149.48 2987.20 709.10 -605.11 370.58 0.29 5977534.37 583705.45 N 70 20 54.877 W 149 19 13.659 3273.01 37.32 149.03 3061.95 765.65 -653.77 399.52 0.48 5977486.04 583734.93 N 70 20 54.398 W 149 19 12.813 3366.84 37.33 148.82 3136.57 822.49 -702.50 428.89 0.14 5977437.65 583764.83 N 702053.919 W 1491911.955 3458.98 37.99 149.20 3209.51 878.73 -750.76 457.87 0.76 5977389.72 583794.35 N 702053.445 W 149 19 11.1 08 3551.21 39.64 149.28 3281.37 936.47 -800.44 487.44 1.79 5977340.38 583824.46 N 702052.956 W 149 19 10.244 3644.31 39.59 149.68 3353.09 995.74 -851.58 517.59 0.28 5977289.58 583855.17 N 70 20 52.453 W 149 199.363 3737.60 39.03 148.95 3425.27 1054.77 -902.40 547.74 0.78 5977239.1 0 583885.89 N 702051.953 W 149 19 8.48~ 3830.73 38.57 148.66 3497.85 1113.07 -952.32 577.97 0.53 5977189.52 583916.67 N 702051.462 W 149 197.599-" 3923.76 38.54 148.82 3570.60 1171.01 -1001.88 608.06 0.11 5977140.30 583947.30 N 702050.975 W 149 196.720 4016.70 38.42 148.84 3643.36 1228.79 -1051.37 637.99 0.13 5977091.16 583977.78 N 702050.488 W 149 195.846 4110.18 38.88 148.91 3716.36 1287.12 -1101.35 668.17 0.49 5977041 .52 584008.51 N 702049.996 W 149 194.964 4203.70 39.54 150.12 3788.83 1346.15 -1152.29 698.16 1.08 5976990.92 584039.06 N 70 20 49.495 W 149 194.088 4296.41 40.28 149.55 3859.94 1405.53 -1203.72 728.05 0.89 5976939.83 584069.52 N 70 20 48.990 W 149 193.215 4389.66 41.15 149.64 3930.62 1466.26 -1256.18 758.83 0.94 5976887.72 584100.88 N 702048.474 W 149 192.315 4485.11 41.98 149.19 4002.03 1529.50 -1310.69 791.05 0.92 5976833.58 584133.70 N 70 20 47.937 W 149 191.374 4577.44 42.74 148.62 4070.26 1591.65 -1363.96 823.18 0.92 5976780.67 584166.42 N 702047.414 W 149 190.435 I Grid Coordinates I Geographic Coordinates I L-108 ASP Final Survey.xls Page 2 of 4 7/18/2002-8:56 AM Station 10 MO Incl Azim TVO VSec NI-S EI-W OLS Northing Easting Latitude Longitude (tt) n n (ft) (ft) (ft) (ft) C 11 OOft) (ftUS) (ftUS) 4671.74 43.42 148.01 4139.14 1656.03 -1418.77 857.02 0.85 5976726.25 584200.86 N 70 20 46.874 W 1491859.447 4764.12 42.17 147.83 4206.92 1718.77 -1471.95 890.35 1.36 5976673.45 584234.77 N 70 20 46.351 W 149 1858.473 4858.37 41.81 147.19 4276.97 1781.81 -1525.13 924.21 0.59 5976620.65 584269.23 N 70 20 45.828 W 149 1857.484 4951.51 40.86 145.06 4346.91 1843.31 -1576.21 958.49 1.82 5976569.97 584304.06 N 70 20 45.326 W 1491856.482 5044.72 40.89 144.72 4417.39 1904.29 -1626.10 993.57 0.24 5976520.47 584339.70 N 70 20 44.835 W 149 1855.458 5138.63 39.42 144.72 4489.17 1964.82 -1675.54 1028.55 1.57 5976471.43 584375.22 N 70 20 44.349 W 149 1854.436 5231.93 39.07 144.14 4561.42 2023.81 -1723.55 1062.88 0.54 5976423.81 584410.08 N 70 20 43.877 W 149 1853.433 5323.34 37.44 143.68 4633.20 2080.35 -1769.29 1096.22 1.81 5976378.45 584443.92 N 70 20 43.427 W 149 1852.459 5416.98 37.75 143.99 4707.40 2137.42 -1815.41 1129.93 0.39 5976332.71 584478.14 N 70 20 42.973 W 149 18 51 .474 5510.08 38.15 144.30 4780.81 2194.62 -1861.81 1163.46 0.48 5976286.68 584512.18 N 702042.517 W 149 1850.495 5603.10 38.78 143.84 4853.64 2252.44 -1908.66 1197.42 0.74 5976240.22 584546.65 N 70 20 42.056 W 149 18 49.?OS,,-,J 5696.52 39.18 143.87 4926.26 2311.14 -1956.12 1232.08 0.43 5976193.16 584581.83 N 702041.589 W 149 1848.490 5790.64 39.27 144.01 4999.18 2370.61 -2004.23 1267.11 0.13 5976145.44 584617.40 N 70 20 41 .116 W 149 18 47.467 5883.57 38.40 143.10 5071.56 2428.80 -2051.11 1301.72 1.12 5976098.95 584652.53 N 702040.655 W 149 1846.456 5976.83 38.40 142.95 5144.65 2486.63 -2097.39 1336.57 0.10 5976053.07 584687.88 N 70 20 40.200 W 149 1845.438 6071.67 38.50 142.83 5218.93 2545.49 -2144.42 1372.15 0.13 5976006.44 584723.98 N 702039.737 W 149 1844.399 6165.37 38.85 142.59 5292.08 2603.92 -2191.01 1407.62 0.41 5975960.26 584759.97 N 702039.279 W 149 1843.363 6259.29 38.80 142.96 5365.25 2662.68 -2237.89 1443.24 0.25 5975913.78 584796.10 N 702038.818 W 149 1842.322 6350.89 38.76 142.89 5436.65 2719.95 -2283.67 1477.83 0.06 5975868.39 584831.19 N 70 20 38.367 W 1491841.312 6445.52 38.97 142.78 5510.34 2779.21 -2330.98 1513.70 0.23 5975821.48 584867.59 N 70 20 37.902 W 149 1840.264 6537.23 38.18 143.80 5582.03 2836.31 -2376.82 1547.89 1.11 5975776.03 584902.27 N 702037.451 W 149 1839.266 6631.48 37.93 144.43 5656.25 2894.36 -2423.89 1581.94 0.49 5975729.35 584936.85 N 70 20 36.988 W 149 1838.271 6726.36 37.70 144.39 5731.20 2952.49 -2471.20 1615.80 0.24 5975682.42 584971.22 N 702036.523 W 149 1837.283 6818.19 37.77 145.28 5803.83 3008.67 -2517.14 1648.17 0.60 5975636.85 585004.10 N 70 20 36.071 W 1491836.337 6910.88 37.73 145.12 5877.12 3065.40 -2563.74 1680.55 0.11 5975590.62 585037.00 N 702035.612 W 149 1835.391 7004.55 37.48 145.02 5951.33 3122.55 -2610.60 1713.28 0.27 5975544.13 585070.24 N 702035.152 W 149 18 34.43f 7096.75 37.39 144.55 6024.54 3178.57 -2656.39 1745.60 0.32 5975498.70 585103.06 N 702034.701 W 149 18 33.49¿--. 7191.83 36.56 143.19 6100.50 3235.70 -2702.58 1779.31 1.23 5975452.90 585137.28 N 70 20 34.247 W 149 1832.507 7284.49 34.73 143.81 6175.79 3289.62 -2745.98 1811.43 2.01 5975409.86 585169.88 N 702033.820 W 149 1831.569 7377.44 32.40 143.79 6253.24 3340.95 -2787.45 1841.78 2.51 5975368.74 585200.69 N 702033.412 W 149 1830.683 7472.40 29.52 146.48 6334.66 3389.77 -2827.49 1869.74 3.36 5975329.01 585229.08 N 70 20 33.018 W 149 1829.866 7566.08 29.46 146.06 6416.21 3435.89 -2865.84 1895.34 0.23 5975290.95 585255.11 N 702032.641 W 1491829.119 7658.41 29.30 145.60 6496.66 3481.18 -2903.32 1920.78 0.30 5975253.76 585280.97 N 70 20 32.272 W 149 18 28.376 7753.63 30.17 145.35 6579.34 3528.41 -2942.23 1947.55 0.92 5975215.16 585308.16 N 702031.889 W 149 1827.594 7845.83 30.65 145.27 6658.86 3575.07 -2980.60 1974.11 0.52 5975177.08 585335.15 N 702031.512 W 149 1826.818 I Grid Coordinates I Geographic Coordinates I L-108 ASP Final Survey.xls Page 3 of 4 7/18/2002-8:56 AM Station \0 MO Incl Azim TVO VSec NI-S EI-W OlS Northing Easting latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (tt) (" /1 oott) (ftUS) (ftUS) 7940.64 31.26 145.85 6740.17 3623.83 -3020.82 2001.69 0.72 5975137.18 585363.17 N 70 20 31.116 W 149 1826.013 8033.46 31.51 145.69 6819.41 3672.16 -3060.79 2028.88 0.28 5975097.52 585390.80 N 702030.723 W 149 1825.219 8126.12 31.73 145.52 6898.31 3720.74 -3100.87 2056.33 0.26 5975057.74 585418.68 N 702030.329 W 149 1824.418 8209.82 31.87 145.83 6969.45 3764.84 -3137.30 2081.20 0.26 5975021.60 585443.95 N 702029.971 W 149 1823.692 8294.00 31.87 145.83 7040.93 3809.28 -3174.07 2106.16 0.00 5974985.11 585469.32 N 702029.609 W 1491822.963 ~ ~' L-108 ASP Final Survey.xls Page 4 of 4 7/18/2002-8:56 AM Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well ~n/-aOJ 5 L-109 L-109 L-109 L-109 L-109 L-109 ' L-109 V L-108 d()ó- ,oq V-102 ~n~ - o~~ V-102 C V-102 ~ Job# Log Description Date 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 06/06/02 08/03/02 05/21/02 05/21/02 05/21/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: 22303 PEX-AIT -BHC-POROSITY 22303 PEX-AIT 22303 PEX-BHC 22303 PEX-POROSITY 22303 PEX-TRIPLE COMBO 22303 PEX- TRIPLE COMBO SSTVD 22303 PEX-HOLE & CEMENT VOLUME LEAK DETECTION LOG 22258 OH MWD/GR 22258 MD IMPULSE-GR 22258 TVD IMPULSE-GR RECEIVED /-.UG 0 9 2002 ,'1last<a Oil & Gas Cons. Commision AnctJQ 08/07/02 NO. 2300 Company: Alaska Oil & Gas Cons comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD ~ 1 1 1 1 1 1 1 1 1 1 1 - Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Received~ (.~ 7/25/2002 Schlumberger NO. 2261 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color Sepia BL L-110 aOJ- J ~ ~ PRODUCTION PROFILE 07/13/02 1 L-1 08 ~O;:).., 1 t'Î~ 22318 USIT 06/30/02 2 L-109 () J- d (', ) 22304 MWDGR 06/06/02 L-1 09 1 22304 MWD GR MD 06/06/02 1 L-1 09 22304 MWD GR TVD 06/06/02 1 CD ~. 1 ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: Alaska OJ': & Gi-lS Cons. CiJmmi~sion An cÌ1c¡fage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receive~0 ~._~ BP Exploration (Alaska) 1!lS, ~ . ~ \ .- ~ Petrotectnical Data Cent~~C F , ~;.I r U 900 E Benson Blvd. ~ '\ ~ """.......- ,,-- Anchorage AK 99508-4254 Ii II I') (.. ?f:n? vvL L ~J ...vv'- Customer Well No Installation/Rig Data Surveys Received By: ) ) MWD/LWD Log Product Delivery BP Exploration (Alaska) Inc. L-108i Nabors 9ES aOd-IOq ~( .lkp-J LWD Log Delivery V1.1, Dec '97 Dispatched To: Lisa Weepie Date Dispatche O-Jan-OO Dispatched By: Nate Rose No Of Prints No of Floppies 2 RECEIVeD JUL 0 5 20(2 Alaaka Oil & Gas Cons. Ct nUl1~lon Anchorage Please sign and return to: James H, Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd, Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com ") Future L Pad Surtace Hole Logs ') 1 I. Subject: Future L Pad Surface Hole Logs Date: Thu, 6 lun 2002 19:30:36 -0500 From: "Crane, Lowen R" <CraneLR@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Magee, D Neil" <MageeDN@BP.com>, "Paskvan, Frank A" <PaskvaFA@BP.com>, "Bunch, Anthony S" <bunchas@BP.com> Winton, As we have discussed recently, BP is committed to obtaining another set of surface open hole logs on L Pad. We would like the logs to be obtained in a well that is reasonably distant from the current set of logs we have out of the L-106 surface hole. The wells we will be drilling on this visit to L pad are all relatively close to L-106 especially since we failed to get tools down in L-109. To demonstrate to the AOGCC that there will be additional opportunities to get these surface hole logs at some distance from L-106, the Borealis team has agreed to present the team's current view of the future of L Pad drilling sometime in the next few weeks. This view will incorporate the drilling data that has been collected from the Borealis development drilling campaign so far. This meeting should prove useful well beyond the subject of this memo. We will be contacting you soon in order to arrange a meeting time and place. If you have any questions, please call. LRC 564-4089 1 of 1 6/6/20024:49 PM ~ ) ~T!Æu~ ~~ fÆ~!Æ~æ!Æ ) ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L108i BP Exploration (Alaska), Inc. Permit No: 202-109 Surface Location 2412' NSL, 3588' WEL, Sec. 34, T12N, RIlE, UM Bottom hole Location 4497' NSL, 1471' WEL, Sec 03, TI1N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms' and conditions of this permit may result in the revocation or suspension of the permit. The Commission granted diverter waiver requests for previous L-Pad wells, in consideration for which specific well logs were to be obtained in Well L-109i. You were unable to obtain these required well logs. Based upon our current understanding of the likelihood of your drilling future L-Pad wells, the Commission now requires that well logs originally required in Well L-109i be obtained in a future L-Pad well of the Commission's choosing. This required surface hole log suite includes Gamma Ray, SP, Resistivity, Neutron-Density, Borehole Compensated Sonic, and calibrated gas logs. In consideration for obtaining the above specified well logs, the diverter requirement for L-108i is waived. Commission approval of the diverter waiver for PBU L-108i does not guarantee approval of future diverter waiver requests on this or any other drill site. Diverter waiver applications will continue to be carefully considered on a case-by-case basis. ~ .' ') ) Permit No: 202-109 Page 2 of2 , June 6, 2002 The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the. mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, t ~-~ ~eChSli Taylor "'-' Chair BY ORDER OE THE COMMISSION DATED thisiPfL. day of June, 2002 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ALASk STATE OF ALASKA" I )OIL AND GAS CONSERVATION COh,..J\ISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 78.4' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028241 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / L-108i 9. Approximate spud d~ 06/10/02 Amount $200,000.00 / 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8366' MD / 7098' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2lk::J 39 0 Maximum surface 2787 psig, At total depth (TVD)(~~,/Q~ 3468 psig Setting Depth ,-- TOD Bottom Quantitv of Cement MD TVD MD TVD (include staae data) Surface Surface 110' 110' ,260 sx Arctic Set (Approx.) Surface Surface 2664' 2578' 444 sx Articset Lite, 239 sx Class 'G' Surface Surface 8366' 7098' 537 sx Class 'G' LiJ6A c:; / ¿ 1/02- ~- sf-:,( 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2412' NSL, 3588' WEL, SEC. 34, T12N, R11E, UM At top of productive interval 4784' NSL, 1654' SEL, SEC. 03, T11 N, R11 E, UM At total depth 4497' NSL, 1471' WEL, SEC. 03, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028239,783' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 20" 91.5# H-40 Weld 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 30" 12-1/4" 8-3/4" Lenath 80' 2634' 8336' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured -.~l(~:~;)'(E:: ~r,:. true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 MC 25.050 Requirements Contact Engineer Name/Num. ~. r: Jam . Franks, 564-4468 .. ...... .. .. . ... ..... . .. . . , .... .'. Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the for ing is true ~ ~rrect to the best of my ~nowl~~ge . . Signed Lowell Crane ~ /U<-4 _Title Senior Dnlllng Engineer Date S- -¡;z 1- 0;2- ( . . Commission tlseOnly. Permit Number - API Number APP~a Date,'ì /) See cover letter 2ó~ - Þ 'T 50- ð¿? - .2 3d 70 i .v 1\ for other reauirements Conditions of Approval: Samples Required D Yes }I No Mud Log R ui .~ ø Y es ~J No Hydrogen Sulfide Measures 0 Yes :s No Directional Survey Required )StYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T€st- ßoPE to 4-ooor P'k,. Lej,~i.,(J b&.(A..Ut-l"lf c.uul A4:rT t'eZ\Vt'~d. , p€,v ~AAc. lS. o-;~ (k)&ì h\ll-Y."k-.' f'i..Òu.A..e. ~M.-t W..:U "td, by drder of ~. ~MO ') Approved By 1"9'" Ign~ Y Commissioner the commission Date " ~ Form 10-401 Rev. 12-01-85 tallnIlYOed'lsti."r~ ~ "~~J:!\ SU t n -riplicate Lj~\~ it:\)t~\I- ) ) rwell Name: I L-1 UBi Drill and Complete Plan Summary 1'1 ype of Well (service I producer I injector): I Injector ~urface Location: As-Built .1 arget Location: Top Kuparuk tsottom Hole Location: x = b83,328.20' Y = b,9/8,13b.2/' 2412' FSL (2867' FNL), 3588' FEL (1691' FWL), Sec. 34, T12N, R11 E X = b8b,300' Y = b,9/b2bO' 4784' FSL (495' FNL), 1654' FEL (3626' FWL), Sec. 03, T11 N, R11 E X = b8b,486.06' Y = b,9/4,964./1' 4497' FSL (783' FNL), 1471' FEL (3808' FWL), Sec. 03, T11 N, R11 E I Kig: I Nabors 91::~ / I AI-I:: Number: 1 bM4020 Ii::stimated ~tart LJate: 16/10/2002 I / I uperating days to complete: I I MU: 18366' 1'1 VLJ: 1/098' 1 li:sl-/M~: 149.9' I I KKi:s: 1/8.4' I Well LJesign (conventional, slimhole, etc.): I Ultra ~Iimhole (Iongstring) I Ubjective: I ~chrader/Kuparuk I-ormation Mud Program: 12 114" Surface Hole (0-2664'): Density (ppg) " 8.5 - 9.2 / 9.0 - 9.b 9.5 max / Initial I::iase PI- to top ~V ~V to I U Viscosity (seconds) 2bO-300 200-250 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ff) (mls/30min) - 50-/0 15-20 8.5-9.b 30 - 45 < 10 8.5 - 9.5 20 - 40 < 5 8.5 - 9.5 8 3,4" Production Hole (2664' - 8366): LSND Interval uensity lau 0 YI-' I-'V pH AI-'l HIHt' (ppg) Filtrate Filtrate Upper 9.3-9./ 4-/ 25-30 8-12 8.b-9.5 6-10 Interval / lOp of HKL 10.1 4-/ 20-30 8-14 8.b-9.b 4-6 <10 by toTO HRZ Hydraulics: Surface Hole: 12-1/4" Interval I-'ump urill A V GPM Pipe (fpm) 0-1,859 b60 5" 19.5# (0 1,859'-2,664' (00 5" 19.5# 90 I-'ump I-'~I 1500 2100 I::l;U ppg-emw 10.0 10,2 Motor Jet Nozzles ("/32) N/A N/A II-A (in2) 20,20,20,16 1.11/ 20,20,20,16 1.11 ( Production Hole: 8 %" Interval I-'ump Urilll-'ipe GPM 2664' - 8366' 650 5" 19.5# 2800 I::l;U ppg-emw 11.3 Motor Jet Nozzles ("/32) 10 6x1b II-A (in2) 1.112 AV (fpm) 2/0 I-'ump I-'~I L-108i Drilling Program Page 1 Hole Cleaning Criteria: Interval Interval KUI-' 110'-2664' ~urface to SV-1 2664'-~~~3' 10 tsase Schrader b~53' -8366 tsase Schrader toTD Directional: Ver. I Anadrill P5 ~Iot ~R Kul-': 300' Maximum Hole Angle: l,;lose Approach Wells: Logging Program: ~urface 25b 34b 220 2/0 360 22b 280 3/5 250 300 330 285 360 400 2bO 350 2bO 300 400 Intermediate/l-'roduction Hole L-108i Drilling Program Urill Pipe Rotation 60 60 80 80 80 100 100 100 60 60 60 80 80 80 60 60 80 80 80 pump GPM 600 100 bOO 600 100 500 600 100 600 600 600 600 600 600 600 600 600 600 600 Mud Weight 9.b 9.b 9.b 9.b 9.b 9.b 9.b 9.b 9./ 9./ 9./ 9./ 9./ 9./ 10.1 10.1 10.1 10.1 10.1 ) Hole (,;Ieaning (,;ondition ~uperior hole cleaning practices at connections will greatly enhance cuttings transport in the sliding mode Acceptable Acceptable Acceptable Acceptable Acceptable Acceptable Acceptable Acceptable RUP's greater than 3bO'/hr require a GPM of 600 and 80 rpm along with sweeps and fully reamed connections to maintain minimum hole cleaning requirements Acceptable Acceptable Marginal Acceptable Acceptable Marginal RUP's greater than 350'/hr must be accompanied by 600 gpm and> 80 rpm with sweeps and fully reamed connections to maintain minimum hole cleaning requirements Acceptable Marginal Acceptable Acceptable Acceptable 39U at 2634' MU All wells pass major risk criteria. Closest Approach is: L-106 17.7' allowable deviation @ 700' MD / IFR-MS corrected surveys will be used for survey validation. GyroData will be needed for surface hole close approaches. Urilling: Open Hole: Cased Hole: Urilling: Open Hole: Cased Hole: MWU / GR / Res None MWU / GK / PWU PEX/ SHC Sonic USIT cement evaluation Page 2 ) Formation Markers: "'ormation 'lOpS MUbkb ~V~ ~V4 i:Sase ~ermafrost ~V3 ~V2 ~V1 Uü4A Uü3 Uü1 Ma W~2 Na W~1 ua Ubf tsase t;M2 (t;olville) IHt<£ tsHt<£ (Kalubik) K-1 IKU~ Kuparuk (; LGU (Kuparuk ts) Kuparuk A 1 ML V (Miluveach) 1 U Criteria 8366' 1 VUss V-101 1 VU actuals 146b 1539' 1610' 1663' 1/15' 168b' 19bO' 204/' 2120' 2213' 2440' 2530' 2825' 2846' 31/5' 3183' 3618' 3639' 3925' 3955' 4200' 4201' 4325' 4353' 41bO' 4119' 5031' 5028' 621/' 615t' 6386' 6361' 6435' 6402' 6490' 64/ b' 6498' 6669' 680b' 6890' 6884' ) I::stimated pore pressure, ~~ü 8./ ppg cMW !Jotential Hydrocarbon 8./ ppg cMW !Jotential Hydrocarbon 8./ ppg I::MW /. !Jotential Hydrocarbon 8.8 ppg I::MW 9.8 ppg I::MW /" 150' MU below Miluveach top Casing/Tubing Program: Hole (;sgl Wtlt-t ürade Gonn Length lOp i:ltm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.b# H-40 WLU 80' GL 110/110 12 ~" 9 b/8" 40# L-80 HIt; 2634' GL 2664'/2b/8' 8%" {" 26# L-80 HIC-m 8336' GL 8366'11098' lubing 3 %" 9.2# L-80 IC-II 3310' 4293' 1603'/6434' lubing 4 %" 12.6# L-80 I C-II 4263' GL 4293'/38b3' Integrity Testing: . est Point LJepth I est I ype i:MW Surface Casing Shoe 20' min from LOT 12.5 ppg EMWTarget /' surface shoe Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Gasing ~ize I 9-b/8" Surface I tsasis: Lead: based on 18~9' of annulus in the permafrost cæ 22~% excess and 20~' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface / I ail: ~ased on 600' MU open hole volume + 300/0 excess + 80' shoe track volume. Tail TOC: At -2064' MD ,/ .. otal éement Volume: Lead 3b2 bbl/19f 4ft'~ / 444 sks of Uowel Ak IICS~ I Lite at 10.7 ppg and 4.44 cf/sk. ~ I ail bO bbl/ 280 fe / 239 sks of Uowell Premium '(3' at 1 b.B ppg and 1.17 cf/sk. / L-108i Drilling Program Page 3 ) ) The 7" production casing will be cemented via an ES cementer in two stages. c.;asing ~ize I I" Production Longstring I tsasis: ~tage 1: 8ased on IOC bOO' I VU (629' MU) above top of Kuparuk + 300/0 + 80' shoe Cement Placement: From shoe to 7124' MD Stage 2: Based on TOC 500' MD above top of Schrader +30%) excess volume Cement Placement: From 200' MD below Schrader (5753' MD) to 3993' MD .. otal cement Volume: Stage 1 bO bbls / 280,b ft3 / 240 sks of Uowell Premium "(.;" at 15.8 ppg and 1.17cf/sk. Stage 2 62 bbls /349 ft3 / 291 sks of Uowell Premium "G" at 1 b.8 ppg and 1. 17 cf/sk (" /.. Well Control: / Surface hole will be drilled without diverter, The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surfays pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3468 psi @ 6805' TVDss - Kuparuk A Sands . Maximum surface pressure: 2787 psi @ surface (' (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi as -" required for MI service,) . Planned completion fluid: 9.1 ppg filtered brine /6,8 ppg diesel /' L-Pad wells have proven kick tolerances in the 25-55 bbl range. A heightened awareness of kick detection and pre-job planning will be essential while drilling/tripping in the productive intervals. Disposal: . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor was installed in Dec 2001. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: // 1. MIRU Nabors 9ES on Slot SR. 2. Nipple up diverter spool and riser. A diverter waiver has been applied for. PU 5" DP as required and stand back in derrick. L-108i Drilling Program Page 4 ) ) 3. MU 12 X" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2664' MD / 2578' TVD. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8",40# surface casing back to surface. - 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. / 6. MU 8-3/4" drilling assembly with MWD/GR/PWD and RIH to float collar. Test the 9-5/8" casing to .~soo~ psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.3 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mud weight to 9.7 ppg prior to first wiper trip. ~ 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 1 0, Drill ahead to TD at -8366'. 11, Rig up Schlumberger and run PEX/BHC sonic. Two attempts on wireline will be made after which TLC will be utilized. 12. Condition hole for running 7" 26# long-string casing. ~. 13, Run and cement the 7" production casing in two stages utilizing a ES cementer. Freeze protect the 7" x 9-5/8" annulus as reqUir~d~ecord formation breakdown pressure on the Morning Report. ,,/ 14. PU drill out assembly ríd d ill out E9rcementer. RIH to FC and test casing to 4000 psi. for 30 minutes. Displace well t~~~ 1 g brine and spot perf pill across the Schrader perforation interval. 15. RU Schlumb~r~and r'&òjj IT log on e-line from the 7" float collar to TOC. /' 16. Perforate S~der interval on e-line. *' 17. Make scraper run and POOH laying down excess drill-pipe. 18. Run the combination 3-1/2" 9.3#, L-80 TC-II / 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes.""'Shear RP valve and install TWC. Test below to 2800 psi. 19, Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 20. RU hot oil truck and freeze protect well to lower GLM. 21. Rig down and move off. F$tirnatedSP9d Date: /' 6-1 0-2002 L-108i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. None of the current producers on L-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. þ;> Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a l' double flange adapter spool on bottom (13-5/8" x11") Reference RPs .:. ItDrillingl Work over Close Proximity Surface and Subsurface Wells Procedure" ,¡,~-*¡,¡,;,:""¡~-",,--»¡';':'¡;"":-"'-':«Ioi'»»-¡-.;«...._-~»¡x.¡.-,¡;yxo,'~:"X';'¡'-¡--¡';'¡'»;O»¡,,,¡¡»>¡¡*-¡>¡-»»»¡'¡~¡-»*"-~:.;-I<>.'?>;':-m:-X'i'»X~_m¡»»X'_¡m¡¡';'¡__W¡X""¡»;O¡"'¡X"o'O'Þ:-m¡¡:-»-"""¡:-w.'¡';'Õ'I'1'r.*,,"'¡;"-¡¡~->_¡¡;';'»'M:-x-;.:._x«v»¡:-»»m;.¡_mx_~_¡¡ Job 2: Drilling Surface Hole þ;> No faults are expected to be penetrated by L-108i in the surface interval. þ;> All wells pass major risk criteria. þ;> Gas hydrates have been observed on all wells drilled <?n L-Pad. These were en?ountered ~ear the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropnate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation )0- Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. L-108i Drilling Program Page 5 ) ) Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations ~-_%------~\:':<<<~""""'>:I~«~:«::<~:~~:X::-":-I\:~~.:':N.x<.~...XX.:+'<'I«<;,:<.~:-,,"'V~J,\,,---~t<:-/:.w(....'>:.!n:~:-'<:));'::<':(.T,o,:.¡::<:_--,*~~:<x~:~~):-.':-::~):.m~:.>....,............_-- )--'-~~_:«>*»»I.:_:>I#w..~"",)~»»,-,-)»:«o_--~»>>- Job 3: Install surface Casina Hazards and Contingencies'" ~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at:t1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Dowell Cement Program" .:. "Surface Casing Port Collar Procedure" ;«M«>.-~':"_"'~_6.'«#:M»:«"":~~'«o:Mo:')-~~««-:«>"_'-:~'>:~"":-:~«<O:«~_«<I.««~<.:«_I«(.,~«,**---,~-~~-~,,«o:.:«_«-:«<':«-"":««~~'-:~""~«««~'<<<":-:<<-_%:-:~ot<<_~....):*:<<~,<<,"0:0.I.:(«~'«'«ot««-,_......,-:«.:-:(«-(«-:(.:~:-:.:-.,«,,-:.»...,««.:«-«<<(Mo:~(""-(<<,'!o:-:(~<<>'<<-:~:«o:.:....~:.:«o,:.......',(~«o»:.:'-«~'-:.;.,:-:,:-:,:-/((<(>.... Job 7: Drilling Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.5 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01), 15.4ppg (L-116), 15.6 ppg (L-114), 13.7ppg (L-11 0) , 13.8ppg (L-107), 15.2 ppg (L 106), 13.2 ppg (L-115), 13.8 ppg (L-120) and 13.1 ppg on L-104 have been recorded in offset L-Pad wells. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.5 ppg. ~ l-Pad development wells have "kick tolerances" in the 25-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ~ There are no "close approach" issues with the production hole interval of L-1 08i. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HrZ" -""""......_..._.--"''''''''._--_....._-'-~-_.---..._............................'''''''''''''''-,--.__.......''''''-"......."..-.........---_..~-_,,,,,,,,,,,,,--,,,,,,,,,,,,,,:_,,,,,,,,,,,,,,,,,,,,,"--.wn"""''''''''-~--''''''''''-'-''''''''''MI;.,,,,,,,,:,_.................--""",,,,,,,,,,<,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,w,,,,,,,,,",,,,,,,,,,,,,,,,,.....w,,,,,,---,,,,,""',,,""No,"",,,,,""",',,,,,,,'>'....'.,,~-,.'. Job 8: Loa Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. L-108i Drilling Program Page 6 ) ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" ~~M'.rI:K~'¡o;,~~;:;.-::"~~~~~<::,t'l::('ð:~""~~~~~..,,,~~,,,,,v;..,~~,...,,,,;o;~~,,~«¡~o;:;,;.~~,~,,'W:r.~I<(;::¡,~',~""'~~I"'~~~,"'I'~"O;:::W;N;.tff;.\~~¡.'((.:~""~"""~~"''''~('.:;,'''''''''''''''~'~::s.~1"t~~'~~~"''''''''''''::''''''''''''<¡''''~~~~~'..,(;I;'';:~~~''I''';,\:'''''''''''''''''''',,''ffl''''''''\,<~~~::;'''''W(./MW;:;:'',.."''..,;S:Iô.~'ð''<6:<>:.:ISI",....,,,,::w,~~..m~,'''~~~:M'''' Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 7" casing is expected to be cemented to 500' above the top Schrader productive sand in a two stage job. The first stage will cover from TD to 500' above the Kuparuk and the second stage will cover from 200' below the Schrader to 500' above the Schrader.. ~ Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of dead crude (2000'), the hydrostatic pressure will be 10.1 ppg vs the 9.8 ppg EMW of the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psi overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ A cement bond log (USIT) will be run to confirm the TOC. This will be done with the rig prior to perforating and running the completion. );;> Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnu to help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Dowell Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" :«__«I,*:I~,:,,,,:>,_~~----"'''_»:':~:«~''('_«N«.:«o»~''(«-»~'''''''«-:,,*,-'--(':<<<<<,_(««<':&"':"'~~',-«"'-,"o!«-:~:.»:«~'.W,o,:,W."<"'!o,..._w....~,,,,:...~,,~,,-,,~.(,.".»,.»""»'~ðI~(ðI'_o'«'«O:'«,,*,'.:-):->Io»,,~-~,,*,,«,,««««...:<n>:,«<,(-':.!<~««'<~'""'-<<<'__:<<O~"''<<6:.!_<<'''_:<<__:<<<<<<>'~:<<<<<':<'':<< Job 1 0: Peñorate Well Hazards and Contingencies ~ The Schrader interval of the well will be TCP perforated prior to running the completion. After placing a brine perf pill weighted to 9.1 ppg the well will be perforated across a 8.7 ppg EMW reservoir for an overbalance of 85 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. ~ A USIT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. Notify Bruce Smith immediately upon obtaining results of USIT log for review of possible remedial cement work. Reference RPs .:. See attached Initial Perforating Procedures ..---,--....,----,-",_........._...._w..._,..._.""",--_......~~_..........,.~....,,,,,,-,~,,,,,,,,..__....,,,,",,,,,,,,,,,,,,,,,,,,,,,~,,,,,---<-,,,,,,,,,,,,,,,,,,,,,,,,,"-,,,,-,,,,,-,,,,,,,,,,,,,,-,"'--"'--",-'''''''''''''''-_W''',",''''''''"""""",,,,,,,,,,,,,,,-,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,',,,,,,,,,,,,-,-,,,,,,,,,,,,-,,,",,,,,,,,,,,,,,--,,<,.~,,,,,,,..'...oo.>o<..",..........._",_w.....',.,.,... L-108i Drilling Program Page 7 ) ) Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. ~ Take care while passing through ES cementer with packer and completion string. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus .»X««««-»»X«~~»»:«';':'.........."".................w",.,::.,,>.,:,..«..~.»:«-:#:'..»w.~-:-»»:>_:-»~:O:«*Iw..........,........,,,,,.....,.,,.,....:..,,.,,.."':.,,,,,.,,:,~»»X~'««'mOOX~@»I~W_W~~,_:«<)~:-m;.;.»,..:w......,......""","""..................,....."..............,.;.;.,~-~~:-,...,.,y...,.......,.,.,,,,.:....,,......;-:«-»:-:-;-:.;.:.w,.:N Job 13: ND/NU/Release Rig Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus L-108i Drilling Program Page 8 0-- 1000 --- ) ) VERTICAL SECTION VIEW BP Exploration Alaska L-108 (P5) Prudhoe Bay Unit - WOA Structure: L-Pad Section At: 146.30 deg May 14, 2002 Client: Well: Field: Schlumbøruør Date: ~~-¡;":",~;:~- 1 0 departure . ~_.-"""_....'--."."_..,"""."...."..... ------- Ndll Drp 1/100 700 MD 700 TVD 0 4.00' 345, JO' az -13 departu'e l End Bid 1835 MD 1830 TVD = = = = = =~= = = - =1~;~~:4~a~4;:;~ = 11,00' 144,41' ez 53daparture aid 4/100 1984 MD 1976 TVD - - - - - ~ 13"]"0'144:41' ãZ 74depÏÜture 2000 -e--.::::.. - - 0>- Q)...J ""00 g ~ 3000 -=- - - - - - - - - 0 Q) ~ > II .8 c CtJ :;:= _0 .c~ ë.~ ~ ã) 4000-. -~ ~~ :e~ () > > ()~ :::::JW ~ I- ----- '$\i51545M0-154-nVrr - - -- mt4169'IMoï68ãìVLJ -------- ------ 1rasel'ermafroSf 11059 fIm 1'g5, 1\7D - ----- . ...:::."" ::.::. --~. -=" "-SV3'i"03fMÖ~Ò2nvLf"" ~ End Bid 2632 MD 2554 TVD - - ¿- -,-- ãã,85"149:25'ãz355d'ëpartiireSV22218M0219BTVO - - - - - - - - - - - 9.7/8" CIII Pt2664 MD 2578 TVD "'\,' ~-=8.8~ ~9,2~az~74~ap~u~ - - - - - - - - - - - - - - - - I> SV1 2587 MO 2518 TVO Hold Angle 38.85° . ... '"~ .. . --....""., . .,~.." . . w., - - - - - - - - ----- ------ - - -- - - - - .--..-., - .__....,..,_.._..,..!:!,G~A .~9~~. ~[)_. 2.~03'!Y.D. Cry 2/1ßO 3839 MD 3493 TVD 38.85' 149,25' az 1110 departure ..".".".,,~. -... ''''.''''''''''.,-' . - - - - -U~3530~3T53WO- - - - - ------- -U~4009~3696NO- - - -------- ---------- -Ma4493MD4003i'iiõ . - -WS2 41J217MD 4278n10- - - - - -WS1 5007 MD 41103 nlO- ---~- -------------- -------------- Hold Angle 38.86° - - - - - - - - - CM3 M76 MD 117681'110- - - - - - - OIJtBaæ =3 MO 48281"\10- - - CM2 5914 ~ 5109 WO- ----- 5000 - . 6000 _. - - - - - - - - - - - - 7000 --- -=-- -::- -------- ------- - - - - - - - - - Drp 2/100 7237 MO 6140 TVO 38,86. 145.27' az 3242 departure --------...--.---- lopHRZì4:>7MiJ62~1\7D - - - - - - ::fJa¡iiã;~~~.,@~ lILD = :: = = = -i~p--Ruparí '-'iìš.r'MO-'t561fìVtJ End Drp / Target Z 7685 MD 6508 TVO - - - 00.00. 147.52' az ~---=--3~):: :: I ~95~ep~ure =~ -) Jr-~-_~~_~~ìVD '"7_h -=-~~ 30.00. 147,52' az I 3836 depart... I 4000 = = = = =j= =1= I I I I - - - - - - _I - - - - - - _1- - - - - -~-- l' - u --- . ---- --TMtV'-6?'F-M8-696&-We--.. . --- - -1- --- .--- T . --. ...-- I I 3000 I 0 I 1000 I 2000 Vertical Section Departure at 146,30 deg from (0.0, 0.0). (1 in = 1000 feet) 0-.." -500 _.. ^ ~ -1000- J: l- e:: 0 z -1500-. J: I- -2000 -"" ::> 0 (J) V V V -2500 - -3000 - ) ) PLAN VIEW Client: BP Exploration Alaska Well: L-l08 (P5) Field: Prudhoe Bay Unit - WOA Structure: L-pad Scale: 1 in = 500 ft Date: 14-May-2002 0 500 1000 I , , I Ndg Bid 1/100300 ~D 300 ìVD i _:~§~~~;~~Ol~- , o,oq' 0.00' 82 27 N 7 W I :, ~~ndBldI835MD 18301VD : , 11.00' 144,41' 82 30 S 34 E : Bid 2/100 1884 MD 1878 TVD ~ I j 11.000 144,41'82388 39E 9.::: þ: , Bid 4/1001984 MD 1978 ìVD .J~%-~~~¡'S:~~L ~ ? ¡ 38,85' 149.25' az 110 S 210 E ~ .~ I ó'o i CIV 2/100 :\s39 MD 3493 ìVD / 38,85' 14è~25' 82 943 S 587 E / End C~ 3963 MD 3591 ìVD 38.86' 1145,27' 82 1009 S 629 E "....!....... ..". .. i I.. I '1' .. ..(. . ~ ..-,,,".~ I ¡ '."1" I I i ."I"~".'." I%' ~ ~. ~ % ~ ö' ...~~~., I 0 I 500 «< WEST I 1000 Schlumbepgep 1500 2000 , ! I ¡ I True North Mag Dee ( E 26.00° ) -0 I i I I ......1... I I i ~ ..........., ."""'"''"1''' ! i I . ....j.......... ,. I I ! i I I .....,... ........... ..¡.. ....., . .....,.,................. - -500 ". .....j.........................,... - -1 000 i I I I . '1""" ..... I I ! I I I I i I I ""'r' ¡ . .........,...... ."1'" . ! Drp 2/100 7237 MD 6140 ìVD 38.86' 145,27. 8Z 2897 S 1799 E ,,"\ .,w'" .,.J""'\/' " :i(' .' \ -"\').~) TD/rC8gPt ,y,/ ~~ 8366 MD 7098 ìVD 30.00. 147.52.8Z 3195 S 2123 E End Drp 1 Tgt .. J§8~j,4P_,~Q§..TY[L 30.00. 147.52" az 2907 S 1940 E I 1500 EAST »> I 2000 ..- -1500 .. - -2000 .---2500 ....-- -3000 õ I KBE Ndg Bid 1/100 Ndg Orp 1/100 KOP Bid 1.5/100 SV5 SV4 Report Date: Client: Field: Structure / Slot: Well: Borehole: UWUAPI#: Survey Name / Date: Tort / AHD / DDI/ ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid HIE YlX: Grid Convergence Angle: Grid Scale Factor: L-108 Proposed Well Profile - Geodetic Report May 14, 2002 Survey J DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) dy Vertical Section Origin: L-Pad/L-108 81-ty stu TVD Reference Datum: L-108. TVD Reference Elevation: L-108 Fe.51 bl I Sea Bed I Ground Level Elevation: Magnetic Declination: L-108 (P5) I May 14, 2002 Total Field Strength: 58.361 ° 13891.55 ft 15.4281 O.54e Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70 21 0,828, W 149 19 24.48e Magnetic Declination Model: N 5978135.270 ftUS, E 583328.200 ftUS North Reference: -+0.63713719° Total Corr Mag North -> True North: 0.99990789 Local Coordinates Referenced To: Schlumberuer Minimum Curvature I Lubinski 146.300° N 0.000 ft, E 0.000 ft KB 78.4 ft relative to MSL 44.100 ft relative to MSL 26.002° 57475.428 nT 80.766° June 10, 2002 BGGM 2001 True North +26.002° Well Head - Grid Coordinates Geographic Coordinates MD I Incl Azlm I TVD I vSec I N/-S EI-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 5978135.27 583328.20 N 7021 0.828 W 149 1924.488 300.00 0.00 345.00 300.00 0.00 0.00 0.00 0.00 5978135.27 583328.20 N 7021 0.828 W 149 1924.488 400.00 1.00 345.00 399.99 -0.83 0.84 -0.23 1.00 5978136.11 583327.96 N 7021 0.837 W 149 1924.495 500.00 2.00 345.00 499.96 -3.31 3.37 -0.90 1.00 5978138.63 583327.26 N 7021 0.862 W 149 1924.514 600.00 3.00 345.00 599.86 -7.44 7.58 -2.03 1.00 5978142.83 583326.09 N 7021 0.903 W 149 1924.547 700.00 4.00 345.00 699.68 -13.22 13.48 -3.61 1.00 5978148.71 583324.44 N 70210.961 W 1491924.593 800.00 3.00 345.00 799.49 -19.00 19.38 -5.19 1.00 5978154.59 583322.80 N 7021 1.019 W 1491924.640 900.00 2.00 345.00 899.39 -23.13 23.59 -6.32 1.00 5978158.79 583321.62 N 7021 1.060 W 149 1924.673 1000.00 1.00 345.00 999.36 -25.61 26.12 -7.00 1.00 5978161.31 583320.91 N 70 21 1.085 W 149 1924.692 -' 1100.00 0.00 0.00 1099.35 -26.44 26.96 -7.22 1.00 5978162.15 583320.68 N 70 211.094 W 149 1924.699 1200.00 1.50 144.41 1199.34 -25.14 25.90 -6.46 1.50 5978161.09 583321.45 N 70211.083 W 1491924.677 1300.00 2.99 144.41 1299.26 -21.22 22.72 -4.19 1.50 5978157.94 583323.76 N 7021 1.052 W 149 1924.610 1400.00 4.49 144.41 1399.04 -14.70 17.41 -0.39 1.50 5978152.67 583327.62 N 70 211.000 W 1491924.499 1500.00 5.99 144.41 1498.62 -5.57 9.99 4.93 1.50 5978145.31 583333.02 N 70 21 0.927 W 149 1924.344 1545.05 6.66 144.41 1543.40 -0.61 5.95 7.81 1.50 5978141.31 583335.94 N 70 21 0.887 W 149 1924.260 1600.00 7.48 144.41 1597.93 6.15 0.45 11.75 1.50 5978135.85 583339.94 N 7021 0.833 W 149 1924.144 1691.40 8.85 144.41 1688.40 19.12 -10.11 19.31 1.50 5978125.38 583347.62 N 7021 0.729 W 149 1923.924 1700.00 8.98 144.41 1696.90 20.45 -11.19 20.08 1.50 5978124.31 583348.40 N 70 21 0.718 W 149 1923.901 StatIon ID L-108 (P5) report.xls Page 1 of 3 5/14/2002-10:19 AM Grid Coordinates Geographic Coordinates StatIon ID MD I Incl I Azim TVD VSec NI-S I EI-W I DlS Northing I Easting latitude I longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 1800.00 10.48 144.41 1795.46 37.34 -24.93 29.92 1.50 5978110.68 583358.39 N 70 21 0.583 W 149 1923.613 End Bid 1835.00 11.00 144.41 1829.84 43.86 -30.24 33.71 1.50 5978105.41 583362.24 N 70 21 0.531 W 1491923.503 Base Permafrost 1859.00 11.00 144.41 1853.40 48.44 -33.96 36.38 0.00 5978101.72 583364.95 N 70 210.494 W 149 1923.425 Bid 2/100 1884.47 11.00 144.41 1878.40 53.29 -37.91 39.20 0.00 5978097.80 583367.82 N 70210.456 W 1491923.342 1900.00 11.31 144.41 1893.64 56.30 -40.36 40.95 2.00 5978095.37 583369.59 N 70 21 0.431 W 1491923.291 Bid 4/100 1984.47 13.00 144.41 1976.21 74.07 -54.82 51.30 2.00 5978081.03 583380.10 N 7021 0.289 W 149 1922.989 2000.00 13.62 144.73 1991.33 77.65 -57.73 53.38 4.00 - 5978078.14 583382.21 N 70 21 0.261 W 1491922.928 SV3 2038.27 15.14 145.41 2028.40 87.15 -65.53 58.82 4.00 5978070.40 583387.74 N 70210.184 W 149 1922.769 2100.00 17.60 146.26 2087.62 104.54 -79.92 68.58 4.00 5978056.12 583397.66 N 70 21 0.042 W 1491922.484 ~-' 2200.00 21.58 147.24 2181.81 138.06 -107.97 86.93 4.00 5978028.28 583416.32 N 702059.767 W 1491921.947 SV2 2217.88 22.30 147.38 2198.40 144.74 -113.59 90.54 4.00 5978022.70 583419.99 N 70 20 59.711 W 149 1921.842 2300.00 25.57 147.92 2273.45 178.04 -141.74 108.35 4.00 5977994.76 583438.11 N 702059.434 W 149 1921.321 2400.00 29.57 148.44 2362.07 224.29 -181.06 132.74 4.00 5977955.71 583462.93 N 702059.048 W 1491920.609 2500.00 33.56 148.83 2447.26 276.58 -225.76 159.97 4.00 5977911.32 583490.66 N 702058.608 W 149 19 19.813 SV1 2587.18 37.04 149.12 2518.40 326.89 -268.93 185.93 4.00 5977868.45 583517.09 N 702058.183 W 149 19 19.054 2600.00 37.56 149.16 2528.60 334.65 -275.59 189.91 4.00 5977861.83 583521.14 N 702058.118 W 149 19 18.938 End BId 2632.33 38.85 149.25 2554.01 354.62 -292.77 200.15 4.00 5977844.77 583531.57 N 702057.949 W 1491918.639 9-7/8" Csg Pt 2663.65 38.85 149.25 2578.40 374.25 -309.66 210.20 0.00 5977828.00 583541.81 N 702057.783 W 149 19 18.345 UG4A 3080.96 38.85 149.25 2903.40 635.66 -534.61 344.03 0.00 5977604.57 583678.12 N 702055.570 W 149 19 14.434 UG3 3530.37 38.85 149.25 3253.40 917.18 -776.88 488.17 0.00 5977363.94 583824.93 N 702053.188 W 149 19 10.223 Crv 2/100 3838.53 38.85 149.25 3493.40 1110.23 -943.00 587.00 0.00 5977198.94 583925.59 N 70 20 51.554 W 149 197.335 3900.00 38.84 147.29 3541.28 1148.75 -975.79 607.27 2.00 5977166.38 583946.22 N 702051.231 W 149196.743 End Crv 3963.20 38.86 145.27 3590.50 1188.40 -1008.76 629.28 2.00 5977133.66 583968.60 N 70 20 50.907 W 149 196.100 UG1 4099.21 38.86 145.27 3696.40 1273.72 -1078.90 677.89 0.00 5977064.08 584017.98 N 70 20 50.217 W 149 194.680 Ma 4493.48 38.86 145.27 4003.40 1521.07 -1282.23 818.82 0.00 5976862.34 584161.15 N 70 20 48.217 W 149 190.562 -,- WS2 4846.66 38.86 145.27 4278.40 1742.65 -1464.37 945.05 0.00 5976681.64 584289.38 N 70 20 46.426 W 149 18 56.875 WS1 5007.19 38.86 145.27 4403.40 1843.36 -1547.16 1002.43 0.00 5976599.50 584347.68 N 70 20 45.612 W 1491855.198 CM3 5475.96 38.86 145.27 4768.40 2137.44 -1788.90 1169.98 0.00 5976359.66 584517.89 N 70 20 43.234 W 149 18 50.304 Obf Base 5553.01 38.86 145.27 4828.40 2185.79 -1828.64 1197.53 0.00 5976320.23 584545.88 N 702042.843 W 149 1849.499 CM2 5913.90 38.86 145.27 5109.40 2412.19 -2014.75 1326.52 0.00 5976135.58 584676.91 N 702041.012 W 1491845.731 Drp 2/100 7236.91 38.86 145.27 6139.55 3242.20 -2697.04 1799.40 0.00 5975458.66 585157.31 N 702034.301 W 1491831.920 7300.00 37.61 145.54 6189.11 3281.25 -2729.18 1821.57 2.00 5975426.77 585179.83 N 702033.985 W 1491831.273 7400.00 35.63 145.98 6269.37 3340.89 -2778.49 1855.14 2.00 5975377.84 585213.94 N 702033.500 W 1491830.293 Top HRZ -'~Â31.90 35.00 146.13 6295.40 3359.33 -2793.79 1865.44 2.00 5975362.66 585224.41 N 702033.350 W 1491829.992 7 vJO.OO 33.65 146.47 6351.64 3397.73 -2825.73 1886.74 2.00 5975330.96 585246.06 N 702033.035 W 149 1829.370 L-108 (P5) report.xls Page 2 of3 5/14/2002-10:19 AM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim TVD VSec I NI-S I EJ-W I DLS Northing I Easting Latitude I Longitude (It) (°) (°) (ft) (It) (ft) (It) (0/10Oft) (ftUS) (ftUS) 7600.00 31.67 147.01 6435.82 3451.69 -2870.85 1916.35 2.00 5975286.18 585276.17 N 702032.592 W 149 1828.505 Base HRZ 7633.46 31.01 147.21 6464.40 3469.09 -2885.46 1925.80 2.00 5975271.67 585285.78 N 702032.448 W 1491828.229 End Orp I Tgt 7684.53 30.00 147.52 6508.40 3495.01 -2907.29 1939.78 2.00 5975250.00 585300.00 N 70 20 32.233 W 149 1827.821 K-1 7690.30 30.00 147.52 6513.40 3497.89 -2909.73 1941.33 0.00 5975247.58 585301.58 N 702032.209 W 149 1827.776 Top Kuparuk 7753.81 30.00 147.52 6568.40 3529.64 -2936.51 1958.38 0.00 5975220.99 585318.93 N 70 20 31.946 W 1491827.278 TMLV 8215.68 30.00 147.52 6968.39 3760.52 -3131.33 2082.39 0.00 5975027.58 585445.08 N 70 20 30.029 W 1491823.657 TO I 7" Csg Pt 8365.69 30.00 147.52 7098.30 3835.51 -3194.60 2122.67 0.00 5974964.77 585486.06 N 702029.407 W 149 1822.480 --- Leaal Description: Surface: 2412 FSL 3588 FEL S34 T12N R11E UM Crv 2/100: 1469 FSL 3003 FEL S34 T12N R11E UM End OrpI Tgt : 4784 FSL 1654 FEL S3 T11N R11E UM BHL: 4497 FSL 1471 FEL S3 T11N R11E UM Northina (Y) rftUSl Eastina (X) rftUSl 5978135.27 583328.20 5977198.94 583925.59 5975250.00 585300.00 5974964.77 585486.06 - L-108 (P5) report.xls Page 3 of 3 5/14/2002-10:19 AM . IBI 7" x 4-1/2" Baker "Premium" ~ Production Packer with anchor 200' above Schrader productive interval with 6' pup below and full 30' joint below. 3-1/2" MMGW Water Flood GLM with Injection Valve with New Vam BxP TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 9-5/8",40 #/ft, L-80, BTC j 2664' 4-1/2" 'X' Landing Nipple with 3.813" seal bore approx 10' above packer Plug Back Depth 8286' 7", 26 #Ift, L-80, BTC-Mod 8366' Date OS/20102 Rev By jdf ) .) - Proposed L-108i Completion Cellar Elevation = 49.9' RKB-MSL = 78.4' I . 4-1/2" 'X' Landing Nipple with 3.813" seal bore, I 2218' I ~ Gas Lift Mandrels with handling pups installed. , ._....~-_._....~..~..._,_._...__._------_._----_.--_._..-.- -_.__._------~_."_.__._,_._._....._._.,---_..._--_..~.-_.. L GAS LIFT MANDRELS . '-'--'---'-"~-""'.'" "-""--"U_-.-." '_.-. '"-......-.". ---_._-----_._-,,-_._---~._.__.- MD Type Valve # 1 2 3 4 3-1/2" MMGW 3-1/2" MMGW 4-1/2" KBG-2 4-1/2" KBG-2 Dummy Dummy RP Dummy L ~.- ...,,-, -.,., ,-,..w.., ""-''''-''_.'-'-''-'''-'''~'.._-,--_...-._.. -"-..- "--"'._""'.-._._-~,-- .. -... -.... -,--,-_.~,_...~-,..- h -... -.""...- -,-- ..-...., ._~.. ,.-----" ""'.--- " ~ -ø 4-1/2" 12.6# L-80, TC-II Tubing 3-1/2" TC-1I9.3 # L-80 Tubing below top packer ---- ---'= Schrader Perforations: ??? ~- L ir 3-1/2" 'X' Landing Nipple with 2.813" seal bore 7" x 4-1/2" Baker "5-3" Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" WireLine Entry Guide set at 150' above Kuparuk Comments Borealis WELL: L-108i API NO: 50-?? Proposed Completion (P5) BP Drilling & Wells , ,- ) ) L-108i Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates have been observed in offset wells. These are expected to be encountered near the base of the Permafrost at 1859' and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid stuck pipe situations. Production Hole Section: . The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure adequate overbalance in the Kuparuk formation and shale stability in the HRZ shale. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. The two short trips in the production hole has proved problematic if hole cleaning practices are not in place. Back reaming at connections and monitoring excessive annular ECD via the PWD will contribute to favorable hole conditions. . FAULTS: The well trajectory is not expected to intersect any faults. If losses are unexpected losses are encountered, consult the Lost Circulation Decision Tree for recommended LCM treatments. / . KICK TOLERANCE: With 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.5 ppg at the surface casing shoe, and 10.1 ppg mud in the hole, the kick tolerance is 25 bbls. . L-Pad development wells have "kick tolerances" in the 25-50 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 L-I08i Permit ') ) Subject: L-108i Permit Date: Tue, 28 May 2002 19:06:59 -0500 From: "Franks, James D" <FranksJD@BP.com> To: "'winton - aubert@admin.state.ak.us'" <winton - aubert@admin.state.ak.us> > Winton, > > > > > > > > > > > > > What would you recommend we place in the permit to clarify this on future > wells? or would a note such as this attached to the permit be sufficient? > > Thanks for your time. > > j ames > > > > > > As I mentioned on the phone this afternoon, there were some questions on the permit from Bob Crandall on the reservoir sections. I hope that this short paragraph helps to clarify. "* The L-108i and the L-109i wells are designed topreproduce from the Kuparuk formation and then turn around and inject into the same formation. We are completing the well in such a way that in the future we can isolate the Kuparuk and then inject into the Schrader Bluff through GLM's in the completion string. There would be no co-mingling of fluids in the wellbore. James Franks BP GPB Rotary Drilling - 9ES office: 907-564-4468 cell: 907-440-0187 11: 1- ~~~~ ¡" &, ~ ~, Þf~~.ti\~ ~ ~ ~ ~ '5~ "'-:J (- c,ui:J . (Jd k 1'1 '=' \ 1( 1 of 1 5/29/2002 8:08 AM " . " ' ) ,"'~. bp ........~"'T"'~....~ ~..- ~~-- ....~ -F~'" ."'4'- ) To: Tom MaunderlWinton Aubert, AOGCC Date: May 21,2002 From: J ames Franks Subject: Dispensation for 20 AAC 25.035 (c) on L-I08i BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 1 0 Borealis/Kuparuk wells at L-pad, nor the two NWE wells 1-01 , and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the ./ surface casing depth, apart from minor and inconsequential hydrate shows. All ten of the surface holes for the Borealis Development (L-116, L-II0, L-114, L-115, L-106, L-I04, L-I07, L-120, L-I02, and L-119) and the first Ivishak well (L-Ol) were drilled to the shale underlying the SV-l sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is :t300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-I08i is planned to reach a 9.5 ppg mud weight before TD at 2,585' TVDss. This request is being made based on L-Pad data submitted regarding mud weight, gas monitoring, recent open hole surface logging of L-l 06 (PEX/Dipole sonic) and meeting / between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. ,/.," ~/¿ es Franks GPB Rotary Drilling Engineer 564-4468 ¡..'~ ;,:: ;\ /' 1~ .,;....~ . . ; . ,I :; ;"'~;r-I.I; _.~ ~ _. .' ,"- Þ.J2.s1\8. ~~ :-.: :~~2 :w~,~~" ~,'~", \..: ~~~ i'i'~ C:,"¡ ~SS'~!_':: Þt::ChOf2J_ç::e Borealis Suñace Hole Mud Weight MW (ppg) 9 ) 8 0 8.5 500 1000 ..-. .Q ~ 1500 c ¡:: '"'-" .s:: Q. 2000 CI) c 2500 3000 3500 '-L-01 . L-116 ):( Pore Pressure . L-107 - -- .L-104 --'-_.'..---- L-120 ) 9.5 10 x '-L-110 --L-106 L-102 ~L-114 . L-115 L-119 Borealis Mud Plots 2/4/02 H 206705 DATE INVOICE / CREDIT MEMO DESCRIPTION 040902 CK040902G PYMT COMMENTS: HANDL:NG INST: GROSS iOO. 00 PERMIT TO DRILL FEE S/H - TERRIE HUBBLE X4628 "-.. THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 L~/08I' ":.;~:',,-. .:1 lOa. 00 DATE 04/111'02 CHECK NO. 00206 70~, VENDOR ÄLÄSKÄOILÄ NET iOO. 00 DISCOUNT .. " .'. 100, 00 No. H 208705 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 """"412 CONSOLIDATED COMMERCIAL ACCOUNT 00206705 PAY ONE HUNDRED & 00/100************************************* US DOLLAR To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 DATE 041 11/02 III 20 b 70 Sill 1:0 ~ . 2038 I:i 5.: OOB ~ ~ .11118 AMOUNT $100.00 NOT VALID AFTER 120 DAYS Ç( i' .-~ -"1 ~ of k- ~- - ;. f? /1f,~' ~~ i~,,, ~mØ ~~_. " '~ 00 H ~ ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER , WELL NAME /~b( !.-/dY'J CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLlES ADD-ONS (OPTlONS) MULTI LATERAL (If APl number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION INJECTI<?N ~WEJ;I- INJECTlO~LL RED RILL "CL UE" The permit is for a new wellbore segment of existing well ---' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-> SPACING EXCEPTION Rev: 5/6/02 C\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ¡::'.Æ> ?1 WELL PERMIT CHECKLIST COMPANY .ß ~X WELL NAME L..- / d ~/ PROGRAM: Exp - Dev - Redrll- Se~ X- Well bore seg - Ann. disposal para req - FIELD & POOL b ¥Ó / S' "" INIT CLASS /-..... J(I ~ iT I GEOL AREA K'!t'1 UNIT# / ) ~ 5" ~ ON/OFF SHORE r)/t.J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N /J! J L / I II ' ) J 3. Unique well name and number. .. . . . . . . . . . . . . . . . ' ~-tt rt:*l /,,¿"'/.fII' -~ ~ éJ;4I'- -~~<::=f ~~V1 þ-J'h '(v'oI/ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y av / L'L/ .. /, I II / ,. "7 / 5. Well located proper distance from drilling unit boundary. ... N ""'d'o~- ~""'-¿e../Þfll~ /t 'Ir~d",(Qr:f/. ~~ /l""r~~~4 6. Well located proper distance from other wells.. . . . . . . . . N ... / J/ !" t.I /, / /I LJ:? 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N ¡.t ~ru':~ ð.¡""' ""'U.J/q _5'~~ - ~ JtldiØ- 1'-7.u I~-II f¡oItJ'. /v/ G 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N ~R '0TE ~ 12. Permit ca~ be issued without administrativ~ approval.. . . . . N EN:;NE~I:: .o>¿::: ~:~::~:~ :;n~::::::efore .15-da.y ~~'~.: .. : : : : : : : . ~~ to I (@l\O. 15. Surface casing protects all known USDWs. . . . . . . . . . . AM tr 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N '~6' ~ f/lJp ç c:. ' 17. CMT vol adequate to tie-in long string to surf csg. . . N 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N ~~: ~~:~~a~:~~~~~;~~i~:~~~~ ~¡t:: ~ ~ ~~r~~fr.o~t.. : : : : : : ~ ~ Ai q £ S 21. If a re-drill, has a 10-403 for abandonment been approved. . . h N. Ai/Æ- 22. Adequate wellbore separation proposed.. . . . . . . . . ,-. . (J( N 23. If diverter required, does it meet regulations. . . . . . . . . . ~ D I \l o~-y- l.,I-J GU \(.1Jy . 24. Drilling fluid program schematic & equip list adequate. . . . . j~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N, l: L. APPR, DATE? 26. BOPE press rating appropriate; test to 4-000 psig. N rUS P ::: l,l ~ 7 V:Js:.( ; y1/l.fJ....1{ ðSc} ~s l' = 4-0()O ¡;.J( / , vJ6A- t;{ zq () L- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . , . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . , . , . . . . . . , . Y ~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . . @ N 31. Data presented on potential overpressure zones. . . . . .. ){N /J /. /7.. . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y 1(/. ~ A~ D~TE 33. Seabed condition survey (if off-shore). . . . , . . . . . . . . N ~ ø;~2- 34. Contact namelphone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal" Y N (D) will not damage producing formation or impair recovery from Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: ( GEOLOGY ( APPR DATE ,/Ik .0Ø¿ /l~. /1, Commentsllnstructions: RPC- JDH WGA r¡,rJG~ ~ff- COT DTS Ob 106/0:<", G:\geology\permits\checklist.doc